Why the Smart Grid Needs Smarter Private Networks

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The electricity grid is going through one of the biggest transformations in its history. For much of the last century, the model was relatively simple. Large power stations generated electricity, transmission networks carried it over long distances, distribution networks delivered it to homes and businesses, and customers consumed it. The flow of power was largely one-way, the number of active control points was manageable, and the communications requirements were relatively predictable.

That model is changing quickly. Today’s grid has to support renewable generation, distributed energy resources, rooftop solar, battery storage, electric vehicle charging, heat pumps, smart meters and more active demand response. Power can now flow in both directions. Customers can also be producers. Generation can be intermittent. Loads can move rapidly. Faults need to be detected faster, and restoration needs to be more intelligent.

This is what people often mean when they talk about the smart grid. It is not just about adding more sensors or installing smart meters. A smart grid is a more dynamic electricity system where generation, transmission, distribution and consumption are monitored, coordinated and optimised in near real time. That requires communications networks that are more reliable, secure, scalable and responsive than many traditional utility networks were designed to be.

In the past, many utility communications systems were built around relatively narrow operational requirements. SCADA systems, protection systems, private radio, microwave links, fibre and field communications each served specific purposes. These systems remain important, and in many cases they are extremely reliable. The challenge is that the smart grid introduces a much wider set of connected assets and applications. Utilities now need to connect fixed assets, mobile workers, sensors, cameras, drones, substations, edge computing platforms and distributed energy resources across very different environments.

This is where Druid Software’s whitepaper, Private 5G: The smart network for the smart grid, becomes relevant. The paper makes the case that private 5G should not be viewed simply as another wireless connectivity option, but as a mission-critical communications layer for modern utility operations. Druid’s supporting page describes utilities as becoming more connected, dynamic and reliant on data, with devices such as reclosers, sensors, AR headsets and smart meters needing secure, low-latency communications across generation, transmission and distribution.

The important point is that not every utility application needs 5G. Fibre remains essential for fixed infrastructure and backhaul. Wi-Fi can be useful indoors or in localised environments. Public LTE and 5G networks can support many field and enterprise use cases. Existing SCADA and protection networks will continue to play a central role. The real question is where private 5G adds capabilities that are difficult to achieve with other technologies.

Druid’s paper positions private 5G around control, resilience and operational continuity. For utilities, this matters because communications cannot be treated as best-effort connectivity. During a storm, outage or substation fault, the network must continue to support field coordination, telemetry, fault detection and operational decision-making. Public networks may become congested or unavailable precisely when emergency response is needed most. A private network gives the utility more direct control over coverage, capacity, quality of service, security and data handling.

From a technical perspective, the smart grid creates very different traffic profiles. A smart meter may only need low-data-rate connectivity. A drone inspecting a wind turbine may require uplink capacity for high-resolution video and thermal imagery. A field engineer using augmented reality may need low latency and reliable downlink performance. SCADA and telemetry applications need predictable availability. Push-to-talk and emergency alerts need priority. A private 5G network can support these different requirements using SIM-based authentication, quality of service policies, local breakout, edge computing and, where appropriate, network slicing.

In generation, the whitepaper highlights how private 5G can support remote and distributed sites such as wind, solar and thermal plants. These sites increasingly rely on real-time monitoring, predictive maintenance and automated inspection. A private 5G network can connect sensors, controllers, cameras and drones across the site, while edge applications analyse data locally. For example, drone video or thermal feeds from wind turbine inspections can be processed at the edge to identify potential defects, ice build-up or abnormal conditions before they become serious failures. The value comes not just from wireless coverage, but from combining reliable connectivity with local intelligence.

Transmission networks have a different set of demands. Faults in transmission systems can have wide-area consequences, so awareness and response time matter. Druid’s whitepaper discusses real-time SCADA and fault isolation, augmented reality support for field crews, and grid balancing at the edge. This is where private 5G can complement existing operational technology by adding secure, mobile and high-bandwidth connectivity around substations, transmission corridors and remote assets. It can support more sensors, richer diagnostics and faster field response without depending entirely on public networks or distant cloud platforms.

The edge computing aspect is particularly important. A smart grid cannot depend on sending every item of data to a central cloud before action is taken. Some decisions need to be made close to the asset, especially where latency, resilience or backhaul availability is a concern. Druid’s architecture discusses centralised network intelligence combined with distributed, self-contained 5G cores at critical remote locations. This allows sites to continue supporting local SCADA or telemetry, worker communications, location tracking, local policy enforcement and edge-based fault detection even if backhaul connectivity is disrupted.

Distribution is where the smart grid becomes most visible to customers. Rooftop solar, EV charging, batteries, heat pumps, smart meters and local generation all create more active and unpredictable conditions at the edge of the network. Utilities need better visibility into voltage, consumption, faults and local load flows. They also need scalable connectivity for large numbers of devices. Private 5G can help support this by providing wide-area coverage, secure device authentication, prioritised traffic and the ability to connect both high-performance and lower-complexity devices.

One useful technical point in the whitepaper is the role of 5G RedCap, or Reduced Capability. Not every utility device needs full 5G performance. Many sensors, meters and control points need reliable connectivity, good coverage, lower cost and better battery life rather than gigabit throughput. RedCap can help bridge the gap between high-performance 5G devices and massive low-power IoT, making it relevant for utility deployments where scale and cost matter.

The paper also highlights 5GLAN, which is important because utilities have a large base of legacy Ethernet-based systems, relays, PLCs and SCADA controllers. A key barrier to modernisation is not the lack of new technology, but the difficulty of integrating new networks with existing operational systems. 5GLAN can help Ethernet-based applications operate across a 5G network, allowing utilities to modernise connectivity without replacing every legacy device or protocol at once.

Another interesting capability is 5G multicast and broadcast services (5GMBS). In emergency situations, utilities may need to send the same alert, video feed or operational update to many users or sites at the same time. Doing this using individual unicast sessions can be inefficient. Multicast and broadcast can make large-scale communication more efficient, which is useful for safety alerts, outage response, drone video distribution and coordinated field operations.

The reference architecture is perhaps the most important part of the whitepaper. Druid describes a central 5G core for orchestration, policy, provisioning, subscriber management and analytics, supported by distributed independent 5G cores at remote sites. This is a strong architectural fit for utilities because it recognises that centralised visibility and local autonomy are both required. A utility needs common policy, security and management across the network, but a critical substation or generation site must also continue operating if the wider network is disrupted.

This architecture also aligns with the growing focus on resilience and cyber security in critical infrastructure. Local data processing can reduce unnecessary exposure of sensitive operational data. SIM-based authentication improves device identity management. Local policy enforcement can ensure that critical applications retain priority. Distributed cores can reduce dependence on a single centralised system. For utilities working under stricter regulatory expectations, these design choices matter.

The practical challenge is that private 5G is not a plug-and-play answer to every grid communications problem. Utilities need to consider spectrum availability, radio planning, device ecosystem maturity, integration with OT systems, cyber security approval, operational skills and lifecycle management. They also need to be clear about the use cases. A private 5G project built around vague digital transformation goals will be harder to justify than one tied to specific outcomes such as faster fault isolation, safer field operations, more reliable substation connectivity, improved drone inspection or better DER visibility.

A realistic approach may be to start with high-value operational zones. These could include a wind farm, a major substation, a distribution automation area, a port or industrial energy hub, or a storm-prone rural network. The initial deployment could support cameras, sensors, worker devices, push-to-talk, drones and local edge applications. Over time, the network could expand to support RedCap devices, more telemetry, wider field operations and deeper integration with grid management systems.

Druid’s whitepaper is useful because it connects private 5G to real utility operations rather than presenting it as generic enterprise wireless. The smart grid needs more than connectivity. It needs secure, resilient and intelligent communications that can support fixed and mobile assets, operational technology, edge analytics and field teams. Private 5G will not replace fibre, SCADA, public networks or every existing radio system, but it can fill an important gap in the utility communications toolbox.

As electricity networks become more decentralised, automated and data-driven, the communications layer becomes a strategic part of the grid itself. The smarter the grid becomes, the more important it is to have a network that can provide control, resilience and scalability. That is the central message from Druid’s paper, and it is why private 5G is likely to become an increasingly important part of the utility modernisation conversation.

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