Global Digital Substations Market Outlook, 2031

Digital substations replace much of the copper wiring and analogue signalling used in conventional substations with digital communication based mainly on the IEC 61850 standard. In a fully digital design, merging units or process interface units in the switchyard convert current and voltage signals into Sampled Values and exchange breaker status and trip commands as GOOSE messages over fibre-optic Ethernet, forming a process bus that links primary equipment to protection, control and monitoring devices. A station bus connects intelligent electronic devices, the substation automation system, gateways and human-machine interfaces. Non-conventional instrument transformers, such as optical and Rogowski coil sensors, can replace bulky conventional current and voltage transformers. Benefits include up to 80 percent less copper cabling in some designs, smaller control buildings, faster engineering through standard configuration files, improved safety by removing high-energy current transformer circuits and richer data for monitoring. Leading suppliers include Hitachi Energy, Siemens, GE Vernova, ABB, Schneider Electric, Schweitzer Engineering Laboratories, NR Electric, Toshiba, Mitsubishi Electric, Efacec and Arteche, together with network and cybersecurity vendors. Engineering tools and interoperability determine competitiveness.

Demand is driven by the need to build and extend substations faster, integrate renewables and large loads, manage ageing assets with better data and reduce lifecycle costs. Between 2024 and 2026, suppliers released new generations of process interface units and merging units with redundant communications, built-in security and support for the latest editions of IEC 61850, and relay makers promoted distributed protection schemes that use Sampled Values. Regulators introduced stronger cybersecurity requirements for electricity systems, including network security monitoring inside protected control networks and risk assessments for critical digital processes, which affects how digital substations are designed and operated. Regulators also began funding network digitalisation more explicitly in price controls. At the same time, a shortage of protection and communication engineers, concerns about multi-vendor interoperability and conservative utility practices slowed full process bus adoption. Through 2031, the key variables are standardisation of designs, engineering tools, cybersecurity compliance, workforce skills, testing practices and the pace of new substation construction. Suppliers that deliver interoperable, cyber-secure systems with simple engineering are expected to hold an advantage.

Drivers •Faster Construction, Lower Lifecycle Cost and Smaller Footprints Digital substations reduce copper cabling, cable trenches and control building size, which cuts civil works and installation time, and standard configuration files speed engineering and testing. Pre-tested modular bays and factory acceptance testing reduce on-site work. Utilities facing large construction programmes for renewables, interconnectors and data centres value faster delivery. Lower maintenance and easier extension reduce lifecycle cost. Space-constrained urban sites benefit from compact designs. Demand is strong.

•Data for Asset Management, Monitoring and Grid Operations Digital substations provide continuous data on currents, voltages, equipment status and device health, supporting condition monitoring, predictive maintenance and faster fault analysis. Integration with asset management and control centre systems improves situational awareness. Utilities need more data to manage two-way power flows, inverter-based resources and ageing equipment. Regulators increasingly expect data-driven asset management. Remote diagnostics reduce site visits. Growth is solid.

Challenges •Interoperability, Testing and Engineering Skills Although IEC 61850 is an international standard, implementations differ between vendors, and multi-vendor process bus systems can require significant integration and testing effort. Protection engineers and technicians need new skills in networking, time synchronisation and configuration tools, and many utilities lack this expertise. Testing and maintenance practices must change from wiring checks to network and data checks. Early projects take longer. Training is required. Adoption is cautious.



•Cybersecurity and Network Reliability Requirements Replacing hardwired signals with Ethernet networks increases exposure to cyber threats and requires secure architectures, access control, monitoring and patch management. Protection functions depend on reliable networks and precise time synchronisation, so redundancy protocols and careful design are needed. Compliance with cybersecurity regulations adds cost and documentation. Legacy devices may not support modern security features. Utilities must manage risk carefully. Costs rise.

Trends •Process Bus Adoption and Process Interface Units Utilities are moving from station bus-only automation toward full process bus designs using merging units and process interface units that combine Sampled Values publishing and switchgear control in one device, reducing hardware and wiring. Redundant communication protocols such as PRP and HSR, and precision time protocol synchronisation, are becoming standard. Distributed busbar and line protection schemes based on Sampled Values are spreading. Standard bay designs are being shared between utilities. Adoption is rising.

•Centralised Protection, Virtualisation and Cyber-Secure Architectures Centralised protection and control platforms, where one high-performance computer runs protection functions for many bays, and virtualised protection running on standard servers are being piloted to reduce hardware further. Secure-by-design devices with secure boot, role-based access and encrypted communications are being introduced. Network security monitoring is being added to meet new regulations. Software-defined substations could allow easier upgrades. Pilots are increasing. Interest is growing.

Hardware leads because merging units, intelligent electronic devices and network equipment form the core of digital substations, while software and services grow fastest as engineering and cybersecurity needs increase. Hardware is the largest component segment because digital substations require intelligent electronic devices for protection and control, merging units and process interface units, non-conventional instrument transformers, Ethernet switches, time synchronisation clocks, gateways and human-machine interface computers, and every new bay adds devices. Prices per device are falling, but the number of devices and the move to redundant architectures keep hardware spending high. Software, including substation automation platforms, IEC 61850 configuration and engineering tools, monitoring and analytics applications, and cybersecurity software, is the fastest growing component because the value of digital substations increasingly depends on data, engineering productivity and secure operation. Utilities increasingly want engineering tools that generate configuration files automatically, simulate systems before installation and monitor device and network health continuously. Services, including design, engineering, integration, factory and site acceptance testing, training and lifecycle support, are a large share of project value because many utilities lack in-house experience with process bus systems and rely on experienced suppliers and system integrators. Through the forecast period, software and services are expected to grow faster than hardware as utilities standardise designs, adopt centralised protection and invest in cybersecurity monitoring, while hardware remains the largest share of initial project budgets for most new substations.

Transmission substations lead because they offer the greatest benefit from digital protection and monitoring, while distribution substations grow fastest as utilities digitise large numbers of smaller sites. Transmission substations are the largest segment because they contain the most critical and expensive equipment, have many bays and complex protection schemes and offer the greatest savings from reduced copper cabling, smaller control buildings and faster engineering. Transmission operators have been the main pioneers of process bus and distributed protection, and new substations for renewable connections, interconnectors and HVDC converter stations increasingly use digital designs from the outset. Tender specifications increasingly reflect this. Distribution substations are the fastest growing segment because utilities operate large numbers of primary and secondary substations that need better monitoring, remote control and automation to manage distributed generation, electric vehicles and heat pumps. Digital designs for distribution use simpler station bus automation, compact intelligent electronic devices and integrated monitoring, and many secondary substations are being replaced with smart units that include communication and sensing. Industrial, renewable and data centre substations also adopt digital designs, especially where owners want detailed energy and condition data and remote operation. Through the forecast period, transmission will remain the largest segment by value, while distribution grows faster in the number of sites as utilities roll out standard digital designs across their networks and as falling device prices make full digitalisation affordable.

New installations lead because greenfield substations can adopt fully digital designs, while retrofit projects grow strongly as utilities modernise ageing substations bay by bay. New installations are the largest segment because greenfield substations allow utilities to adopt digital architecture from the start, including process bus, non-conventional instrument transformers and compact control buildings, without the constraints of existing wiring and equipment. Large construction programmes for renewable connections, interconnectors, data centres and network reinforcement provide many opportunities for digital designs, and standard digital bay designs make it easier to repeat projects. Retrofit and upgrade projects are a large and fast-growing segment because most substations in mature networks were built decades ago and are reaching the end of life of their protection, control and communication systems. Utilities often digitise substations in stages, first replacing station bus automation and relays, then adding merging units and process interface units in the switchyard as primary equipment is replaced. Stand-alone merging units allow conventional instrument transformers to be connected to digital systems, enabling gradual migration. Detailed migration roadmaps help utilities manage this transition. Retrofits must be carried out with minimal outages, which requires careful planning and testing. Through the forecast period, new installations will remain the largest segment in fast-growing regions, while retrofits grow fastest in mature markets as utilities modernise ageing assets and integrate them into wider digital grid strategies.

Utilities lead because they own most substations and set digital standards, while renewable, industrial and data centre owners grow fastest as private substations expand. Utilities, including transmission system operators and distribution network operators, are the largest end-user group because they own and operate most substations and are responsible for adopting standards, defining digital substation architectures and running large construction and replacement programmes. Their requirements for interoperability, cybersecurity, redundancy and testing shape supplier offerings, and many utilities have published standard digital bay designs. Industrial users, such as oil and gas, mining, metals, chemicals and manufacturing, use digital substations to improve reliability, reduce maintenance and integrate electrical data with plant control systems. Renewable energy developers and owners of wind, solar and battery storage plants build collector and grid connection substations that increasingly use digital designs to speed construction and enable remote operation. Data centre operators are building large private high voltage substations and value digital monitoring, fast protection and detailed power quality data. Railways, ports and airports also adopt digital substations. Private adoption is supported by vendors offering standard packaged substation designs. Through the forecast period, renewable developers and data centre operators are expected to grow fastest as private substations multiply, while utilities remain the largest buyers and continue to lead standardisation, pilot programmes for centralised protection and the development of skills across the wider industry.

Europe leads digital substations through early process bus adoption and strong regulatory focus on digitalisation, Asia-Pacific grows fastest through very large substation construction in China and India, and North America accelerates with cybersecurity rules and data centre-driven expansion. North America is a major region where utilities have used station bus automation widely and are now piloting and deploying process bus and Sampled Values designs. Data centre load growth, renewable connections and transmission expansion are driving new substations. Reliability standards require robust cybersecurity, and the approval of internal network security monitoring requirements in June 2025 affects how substation networks are designed and monitored. Federal cybersecurity advisories in February 2024 warned that state-sponsored actors had targeted energy sector networks, including substation remote access. Relay makers such as Schweitzer Engineering Laboratories, GE Vernova, Siemens and Hitachi Energy offer digital substation portfolios. By 2031, growth is expected from new substations, retrofit programmes and cybersecurity-driven upgrades.

Europe is the leading region, with system operators in the United Kingdom, Germany, France, the Netherlands, Spain and the Nordic countries deploying full digital substations with process bus. Great Britain's RIIO-3 price control, published in December 2025, includes 876.7 million pounds of baseline digitalisation funding across network sectors and a new digitalisation licence condition. The electricity network code on cybersecurity, adopted in March 2024, and the NIS2 Directive, with a transposition deadline of October 2024, raise cybersecurity requirements. The Iberian blackout of April 2025 and the March 2026 expert report highlighted the need for better monitoring. By 2031, growth is expected from grid expansion, replacement programmes and centralised protection pilots.

Asia-Pacific is the largest and fastest growing region. China's grid companies have built large numbers of smart and digital substations and are standardising designs, supported by domestic suppliers. India's rapid transmission expansion includes digital substations for 400 and 765 kilovolt projects. Japan and South Korea are digitising ageing substations, and Australia's network businesses are deploying IEC 61850 designs. Southeast Asian utilities are adopting digital substations in new projects. By 2031, the region is expected to account for most new digital substations.

Latin America is a growing region where transmission auctions and concession contracts in Brazil, Chile, Colombia and Peru encourage modern substation designs that reduce construction time and improve availability. Mexico is investing in grid reinforcement. Utilities are adopting IEC 61850 station bus automation and starting process bus pilots. Barriers include budgets, skills and conservative specifications. By 2031, growth is expected from new transmission substations and renewable collector stations.

The Middle East and Africa are adopting digital substations rapidly in the Gulf, where utilities in Saudi Arabia, the United Arab Emirates and Qatar specify IEC 61850 designs for new substations serving giga-projects, data centres and renewables, and some have deployed process bus. Egypt is building new substations for urban development. South Africa and other African utilities are adopting digital automation in new projects with development finance. By 2031, growth is expected from Gulf programmes and African grid expansion.

December 2025 – Ofgem publishes RIIO-3 final determinations with digitalisation funding: The price control includes 876.7 million pounds of baseline digitalisation funding across network sectors, a new licence condition and a re-opener, supporting investment in digital substations and data.

June 2025 – FERC approves internal network security monitoring standard: The Federal Energy Regulatory Commission approved CIP-015-1, requiring internal network security monitoring for high- and medium-impact systems with routable connectivity, affecting substation network design.

June 2025 – Schweitzer Engineering Laboratories promotes Sampled Values busbar protection: The company highlighted distributed, phase-segregated busbar protection using IEC 61850 Sampled Values, showing growing use of process bus for critical protection.

March 2024 – European Commission adopts electricity network code on cybersecurity: The delegated regulation sets recurring cybersecurity risk assessments and governance for entities with digitalised processes affecting cross-border electricity flows.

January 2024 – Hitachi Energy launches SAM600 3.0 process interface unit: The modular unit combines merging unit and switchgear control functions, supports IEC 61850 Edition 2.1, and adds redundant communications and security features for digital substations.


Considered in this report
• Historic Year: 2020
• Base Year: 2025
• Estimated Year: 2026
• Forecast Year: 2031

Aspects covered in this report
• Global Digital Substations Market with its segments and regional outlook
• Various drivers and challenges
• Ongoing trends and developments
• Key developments and regulatory milestones

By Component
• •Hardware
• •Software
• •Services

By Substation Type
• •Transmission substations
• •Distribution substations
• •Industrial and renewable substations

By Installation Type
• •New installations
• •Retrofit and upgrade

By End User
• •Utilities
• •Industrial users
• •Renewable energy developers
• •Data centres and infrastructure