The Hidden Risk in Every Digital Substation Project 

The Gap Between Technology and Talent

The grid is in the middle of a significant digital build-out. The global digital substation market is on a trajectory to reach $13.5 billion by 2033, fueled by renewable integration, grid modernization mandates and the rising complexity of managing distributed energy at scale. In North America alone, 15 to 20 percent of substations are already digital or hybrid and 50 percent of new substation builds are planned to adopt IEC 61850. In 2023, the first fully digital substation in the U.S. went live in California. The capital commitments are real. The programs are moving. And so is the clock, since the workforce needed to deliver is under serious pressure.

The reality utilities face is complex and fast moving and the organizations that get ahead of it will execute better, faster and with less risk than those that don’t.

The Gap Between Infrastructure and Capability

A digital substation operates in a fundamentally different environment. Traditional substations run on hardwired, analog systems. Protective relays are physically connected to instrument transformers and breakers. A technician can trace a circuit. They can see the logic on drawings and in the wiring.

In a digital substation, that physical clarity disappears and IEC 61850 is only part of the picture. Protection and control functions now run on Ethernet-based communication protocols, with Intelligent Electronic Devices (IEDs) publishing and subscribing to each other across a network. A breaker failure scheme that once lived in hardwired logic now lives in a GOOSE message. Distance relay coordination that once ran on analog inputs now runs on digitized, sampled-value streams. Add in SCADA, IoT devices, time synchronization, cybersecurity, and analytics, and the system becomes far more capable, but also far more complex. The system is faster, more flexible and more capable. It also requires an updated knowledge base to commission, test and troubleshoot. Currently, that knowledge base is not being widely adopted in the current workforce.

Two Workforce Problems Running at the Same Time

In 2023, over half of the utility workforce had less than 10 years of experience. At the same time, the Department of Labor estimates that nearly half of the current power industry workforce will retire over the next five to ten years. This industry bell curve creates two distinct workforce problems that run simultaneously, both landing on digital substation execution.

Newer engineers and technicians bring energy and capacity, but they’re entering an environment that’s shifting faster than traditional training programs can track. Understanding IEC 61850 protection logic, configuring substation files and troubleshooting IED communication requires hands-on experience that most have not yet had the opportunity to build. The learning curve is steep and live projects aren’t the right classroom.

Experienced technicians carry the institutional knowledge utilities depend on, but the job is changing around them. Professionals who have spent careers tracing copper and testing analog relay logic now need to operate in virtual protection and control environments, validate GOOSE subscriptions and interpret configuration files such as ICD, SSD, CID and SCD documents. For many, it registers as a significant change and without structured pathways to build new competency, capable professionals can get left behind.

Both problems land in the same place: a commissioning team in the field that isn’t fully prepared for what a digital substation demands.

True Cost of Underperformance

The impact from these gaps do not show up in the design. It shows up during the execution, especially commissioning. When a workforce gap meets a new technically complex system, the risk of failure on the upgrade grows exponentially.

Field implementation of substation modernization, digitalization and IEC 61850-enabled systems involves multiple sequential layers of testing: IED-level testing, interconnection testing between publishing and subscribing devices and full-system testing across multiple IEDs working in coordination. Each layer requires the team to understand not just what the system should do, but how to verify the communication relationships that make it work.

Configuration errors in substation configuration files, misconfigured GOOSE subscriptions or gaps in logic diagram interpretation don’t always surface as obvious failures. Instead, they surface as reliability questions that are harder to trace and more expensive to resolve after commissioning is complete, often on a timeline that affects the broader capital program.

Add cybersecurity infrastructure requirements, time synchronization dependencies and vendor-specific implementation nuances across IED manufacturers, and the complexity compounds quickly. The organizations that underinvest in workforce preparation may inadvertently defer risk to commissioning, operations and ultimately to reliability.

The Investment Case for Getting Ahead of It

Load growth, renewable integration and grid reliability demands are driving the modernization timeline. The U.S. is expected to spend around $302 billion on transmission upgrades between 2024 and 2030. The question is whether the workforce is ready to execute against it.

The utilities that will get there on time, on budget and with confidence are the ones treating workforce development as part of the capital program, not a line item to be deferred.

The biggest risk is an unprepared workforce. That means structured training on IEC 61850 protocols and the full digital substation technology stack before crews hit the field. It means hands-on exposure to the configuration of intelligent electronic devices (IEDs) substation configuration files and interconnection testing in a controlled environment.

It also means building a capability that compounds. A team fluent in digital substation systems today is an asset that pays forward across every subsequent project in the capital plan, making training a longer-term performance investment.

The Bottom Line

The digital transition in the substation world is not optional, and the pace isn’t slowing. What’s optional is how well-prepared your organization is when those projects hit the field.

Seventy-six percent of energy and utility employers are already experiencing a talent and skills gap within their existing workforce. The utilities that close that gap on digital systems now will be the ones that execute their modernization programs with less rework, fewer delays and stronger outcomes.