After Distributech: Why Capacity Has Become the Currency of the US Grid

After three days at Distributech in San Diego, one thing stood out clearly: The US power system is entering a phase where proven capacity, not concepts, determines relevance in the ecosystem.

Across sessions, side conversations, and closed-door discussions, the same themes surfaced repeatedly. The grid is under pressure, timelines are compressed, so what matters now is what can be delivered, measured, and relied upon to increase grid capacity.

Below are three observations that help explain why this shift is happening and what it means for utilities, technology providers, and the broader energy ecosystem.

1. Capacity is No Longer a Long-Term Conversation

Few topics at DTECH generated as much alignment as the need for flexibility. The grid needs more of it, across voltage levels, and sooner than previously planned.

Utilities are already contending with:

• Transformer aging and substation congestion
• Rising system peak loads
• Long lead times for traditional grid reinforcements

At the same time, large new sources of demand, from data centers to electrification, are accelerating the urgency. In that context, the implicit question being asked is no longer whether flexibility is needed, but:

How much capacity can be made available today, and how confident are we in it?

This is reshaping how solutions are evaluated. Small programs, pilots, or theoretical models will struggle to compete with approaches that demonstrate real, deployed capacity and stand up to regulatory and operational scrutiny.

2. Utility IT into the Limelight

Another notable shift was the maturity of internal utility technology and product teams. Advances in data platforms and AI tooling are enabling utilities to extract far more value from the grid and meter data they already own.

Several presentations illustrated how utilities are now focusing on high ROI vs effort initiatives:

• Developing forecasting and asset intelligence internally
• Building analytics closer to operations and planning teams
• Using data as a core input into decision-making rather than as a reporting layer

This evolution changes the traditional dynamics between utilities and software vendors. The build-versus-buy decision is shifting towards build, especially at larger utilities with strong internal product capabilities and for applications that leverage the massive utility data.

For technology vendors, this raises the bar. Clear use cases, speed to value, and measurable outcomes matter more than ever. At the same time, mission-critical functions such as grid reliability and operational control continue to demand accountability, transparency, and trust that should bias procurement decisions towards buy for now.

3. The Magic Happens at the SW-HW Interface

A recurring theme was the growing convergence of software, hardware, and controls. In many US market structures, software-only approaches are increasingly constrained by the realities of the barriers put up by OEMs or third-party owners like installers. The US is different from Europe in that OEMs’ data ownership gives them substantially more power in the ecosystem.

This does not imply that software is becoming less important. Quite the opposite. But it does suggest that value creation is moving closer to the physical system, where connectivity, control, and assets intersect.

As a result, the ecosystem will see:

• More vertically integrated one-stop-shop solutions for end-customers (“installers 2.0”)
• Deeper integration of grid software providers in OEM products (“OEMs 2.0”)
• Greater focus on solutions that work within, rather than around, utility processes (“grid embedded solutions”) 

The challenge ahead is not technical. It is around customer proposition and regulatory alignment. Scaling solutions without excessive capital intensity or unmanageable operational complexity will be a defining test for many players.

What Comes Next

Distributed energy resources, customer flexibility, and advanced analytics all have a role to play, but only if they translate into dependable capacity that can be trusted by grid planners and operators at utilities and regulators alike. The conversations in San Diego reflected a system in transition, moving from exploration to implementation. For those working in this space, the question is no longer what could work, but what works at scale. 

If there is one takeaway, it is this: the US grid transition is now all about execution models and clear-headed prioritization of where the value is in the near future. We hope that regulators and policymakers are equally clear-headed and actionable on where that value lies in front of them.