The Cybersecurity Problem With Europe’s Distributed Energy Grid

Europe’s electricity system doesn’t look the way it used to. Power generation was once concentrated around relatively small numbers of large facilities. Today, more of it comes from wind farms, solar parks and smaller installations spread across the continent. 

In the second quarter of 2026, renewable sources generated 54.1 per cent of EU electricity, with solar and wind providing the largest shares of that renewable power. Physically, that distribution can be an advantage. There’s no single solar park or wind farm responsible for keeping Europe running. 

But the same infrastructure increasingly relies on digital systems for monitoring, maintenance and remote control. And from a cybersecurity perspective, physical distance doesn’t necessarily create digital distance. 

Research published by Modat and the Dutch National Cyber Security Centre (NCSC-NL) in October 2026 found 8,547 internet-exposed systems it could confidently connect to wind and solar installations across 35 European countries. Some were management interfaces for individual assets. Others were connected to several turbines or entire farms. 

An internet-facing system isn’t automatically compromised. Nor does finding one mean an attacker can control the infrastructure behind it. But it does raise a more important question for distributed energy grid cybersecurity. What happens when electricity generation becomes increasingly decentralised, while the systems used to manage it remain digitally connected?

Distributed Energy Changes The Cybersecurity Model

At first glance, this looks like a familiar operational technology (OT) security problem. There are connected devices controlling physical equipment, so organisations need to secure those devices and the networks around them. But distributed generation changes the shape of that problem. 

A traditional power facility gives security teams a relatively defined environment to protect. Distributed energy resources can involve wind turbines, solar panels, inverters, substations and control systems spread across many locations. Those assets may also come from different manufacturers and be maintained by different suppliers. 

More importantly, their geographical distribution creates a practical need for remote access. Polish government guidance on renewable energy cybersecurity explains that wind and solar installations rely on industrial automation systems for monitoring and control. 

Because the equipment is geographically dispersed, remote management supports everything from diagnostics and maintenance planning to responding when something goes wrong. That access may come from a central control room or an external maintenance provider. So simply disconnecting everything isn't a realistic security strategy. 

The connectivity exists because the infrastructure needs it. Modern inverters show how blurred the line between energy equipment and connected technology has become. An inverter converts the direct current generated by solar panels into the alternating current used by the grid. 

But today's inverters can also monitor performance, manage power flows and support grid stability, while network connectivity allows them to be monitored or controlled remotely. The individual components may be distributed. The ability to see, manage or change what they're doing can still converge elsewhere. 

And that's where renewable energy cybersecurity starts looking different from simply securing a larger collection of OT devices.

Remote Control Creates Concentrated Cyber Risk

The 8,547 systems identified by Modat are useful because they show the scale of publicly reachable renewable infrastructure. But the number alone doesn't tell us how serious the risk is. A login page and a control interface aren't the same thing. 

Neither is an exposed monitoring dashboard and a system capable of changing how physical equipment operates. For security leaders, the more useful question is what sits behind each point of access. Modat found systems ranging from interfaces associated with individual turbines to systems managing multiple turbines or an entire wind farm. 

That means the cyber risk attached to one interface can extend well beyond the device hosting it. This changes how organisations need to think about remote access security. Counting exposed assets is useful for finding weaknesses, but it doesn't show the potential consequence of exploiting them. 

Two externally reachable systems may look similar in an asset inventory while giving an attacker very different levels of authority. The same applies to legitimate access. A maintenance provider that can read diagnostic data presents a different risk from one that can change operating parameters across multiple installations. 

So the security significance of a connection depends on three things: what it can reach, what it can do and how much physical infrastructure sits behind it. That distinction becomes much less theoretical once someone actually tries to use those connections against the energy system.

Poland Shows What Happens When Access Becomes Action

On 29 December 2025, coordinated cyber attacks targeted more than 30 wind and photovoltaic farms in Poland, alongside other energy and industrial targets. The attacks disrupted communications between renewable-energy facilities and their distribution system operators. 

They didn't stop electricity generation or destabilise Poland's power system. But CERT Polska found that the level of access obtained by the attacker created the potential to disrupt generation at the affected facilities. That difference is important. The incident wasn't evidence that compromising a handful of renewable installations can bring down a national grid. 

In fact, CERT Polska found that even the combined loss of capacity across all 30 affected facilities wouldn't have destabilised Poland's electricity system under the conditions at the time. What it demonstrated was something quieter, but more useful for security teams. Distributed renewable infrastructure can be deliberately targeted through its digital control environment. 

And when attackers gain sufficient access, the potential consequence isn't limited to stolen data or unavailable IT services. It can reach the physical process underneath. A small generation asset may pose limited risk on its own. But that calculation can change when the same access path, supplier or management system connects many of them. 

Which means securing the distributed grid starts with understanding those relationships.

Securing The Grid Means Securing Its Control Paths

Most security teams already know they need an accurate asset inventory. They know remote access should be protected, systems should be patched and operational networks shouldn't be unnecessarily exposed to the public internet. The harder question is whether those controls reflect how authority actually moves through a distributed energy environment. 

For every remotely managed asset, security teams need to understand who can connect to it, what level of access they receive and what they can change once they're inside. That includes internal operators, equipment manufacturers, maintenance companies and other service providers. Then there's the other side of the relationship: how much infrastructure can each account, interface or management platform control? 

This creates a different way of looking at energy grid cybersecurity. The security boundary isn't simply the solar installation, wind turbine or inverter. It extends along the chain of access connecting that equipment to operators, suppliers and the wider electricity system. That gives security leaders a more useful set of questions to work with:

• Does this asset genuinely need remote connectivity?
• Does remote management require the interface to be publicly reachable?
• Who can access it, and what actions are they authorised to perform?
• Can one account or management system control multiple physical assets?
• Can third-party access be revoked without preventing the asset from operating safely?
• What happens if the organisation no longer trusts the remote-management layer?

Those questions also help separate necessary connectivity from unnecessary exposure. This is already becoming part of Europe's approach to the problem. In September 2026, the European Commission published recommendations specifically addressing cybersecurity risks in internet-connected photovoltaic installations and their potential effect on the resilience of the EU electricity system. 

The work considers different categories of PV installation, possible threat scenarios and the measures needed to reduce those risks. But some of the most important control decisions are made long before an asset ever connects to the grid.

Procurement Becomes Part Of Grid Security

Buying connected energy equipment isn't necessarily a one-time transaction. Software needs updating. Equipment needs servicing. Manufacturers may provide remote support. Management platforms can remain connected throughout the asset's working life. That means procurement decisions can establish digital relationships that last for years. 

The inverter market provides a useful example. According to the International Energy Agency (IEA), China accounted for around 80 per cent of global manufacturing capacity for solar PV and battery inverters in 2025. Europe accounted for around eight per cent. The concentration itself doesn't make equipment insecure. 

But the IEA identifies several potential cyber risks around connected inverters, including weaknesses in passwords and internet connections, remote-control systems, software updates and the possibility of unauthorised access introduced through supply-chain components. 

For CISOs and security architects, this pushes supplier cybersecurity further into the procurement process. It's no longer enough to ask whether a device meets today's technical security requirements. 

Organisations also need to understand who can access it after deployment, how software and firmware will be updated, what information leaves the environment and whether external access can be independently removed. Those decisions determine part of the future control path before the infrastructure is even switched on. 

And European policymakers are starting to approach connected energy technology in much the same way.

Europe’s Cybersecurity Rules Are Catching Up

Europe isn't starting from scratch when it comes to protecting electricity infrastructure. ENISA's 2026 NIS360 assessment found cybersecurity maturity improving across EU critical sectors, while electricity remained among the sectors considered most critical. The wider regulatory foundation includes NIS2 alongside rules designed specifically for electricity infrastructure. 

The EU's Cybersecurity Network Code for electricity came into force in June 2024. It recognises several characteristics that make energy security different from ordinary enterprise cybersecurity, including real-time operational requirements, the possibility of cascading effects across interconnected grids and the need to integrate newer technology with legacy infrastructure. 

What's changing now is the attention being paid to distributed and connected generation. The European Commission's June 2026 roadmap for digitalisation and AI in energy identifies solar and wind generation infrastructure as a priority cybersecurity concern. 

Among the risks it highlights are manipulation of electricity production, unauthorised access to operational data, supply-chain compromise and the possibility of remotely triggered outages. That same roadmap also makes the other side of the problem clear. Europe wants greater digitalisation across its energy system, including smarter grid management, digital technologies and better use of energy data. 

So the direction of travel isn't towards less connectivity. Nor should it be. The challenge is making sure the cybersecurity model develops alongside the infrastructure it protects. Regulation can establish minimum requirements and common expectations, but it can't tell an individual operator where authority concentrates inside its own environment. 

Security teams still need to know which connections exist, who controls them and what happens if one of those trusted paths stops being trustworthy.

Final Thoughts: A Distributed Grid Needs Security Built Around Control

Europe's renewable transition is changing more than where electricity comes from. It's changing where the systems responsible for producing and managing that electricity sit, who interacts with them and how those interactions happen. There are good reasons for much of that connectivity. 

A geographically distributed energy system needs remote monitoring, maintenance and control if it's going to operate efficiently. Removing those capabilities would solve one security problem by creating several operational ones. But necessary connectivity doesn't have to mean unnecessary exposure. 

The bigger task for security leaders is understanding where digital control converges across infrastructure that looks physically decentralised. That means following the relationships between assets, management platforms, operators and suppliers, then asking how much authority each connection actually carries. 

Because the future grid may be spread across thousands of locations. Its cyber risk won't always be. As critical infrastructure continues to change, EM360Tech will keep examining the security decisions behind that shift and what they mean for the leaders responsible for protecting it.