Global Substation Control Systems Market Outlook, 2031

Substation control systems, also called substation automation systems, are the hardware and software used to monitor, control and protect equipment inside a substation and to connect it to remote control centres. They include bay control units and protection relays, station computers and human-machine interfaces, remote terminal units and gateways, communication networks, time synchronisation, interlocking logic, event recording and engineering tools. Modern systems are based on the IEC 61850 standard for communication inside substations and use protocols such as IEC 60870-5-104 and DNP3 to communicate with control centres. They allow operators to open and close breakers, change transformer taps, monitor alarms, collect measurements and record events, either locally or remotely, and they perform automatic functions such as load shedding, transfer schemes and voltage control. A typical transmission substation may have dozens of intelligent electronic devices exchanging data every few milliseconds. Leading suppliers include Siemens, Hitachi Energy, ABB, GE Vernova, Schneider Electric, Schweitzer Engineering Laboratories, NR Electric, Toshiba, Mitsubishi Electric, Efacec, Hitachi and Eaton, with cybersecurity vendors adding protection. Reliability, interoperability and security determine competitiveness.

Demand is driven by new substations, replacement of obsolete control systems, integration of renewables and storage, the shift to digital substations and stricter cybersecurity requirements. Between 2024 and 2026, cybersecurity became a central concern: security agencies warned in February 2024 that state-sponsored actors had compromised energy sector networks and could reach operational technology and substation remote access; new electricity sector cybersecurity rules adopted in March 2024 required recurring risk assessments for critical digital processes; a wider cybersecurity directive for essential services had to be applied into law by October 2024; and regulators approved internal network security monitoring requirements in June 2025. At the same time, suppliers introduced new process interface units and controllers with secure boot, role-based access and redundant communications. Through 2031, key variables are substation construction rates, replacement of legacy remote terminal units, digital substation adoption, cybersecurity compliance costs, engineering skills and virtualisation of control functions. Suppliers with secure, interoperable and easy-to-engineer systems are expected to hold an advantage.

Drivers •Grid Expansion, Renewables and Replacement of Obsolete Systems New substations for renewable connections, storage, interconnectors, data centres and network reinforcement each need modern control systems, and many existing substations still use legacy remote terminal units and hardwired control that are no longer supported. Utilities are replacing these with IEC 61850 automation systems that offer better data, remote control and easier maintenance. Integration of inverter-based resources requires faster and more flexible control. Replacement cycles are accelerating. Demand is strong.

•Cybersecurity Regulation and Remote Operation Needs Regulators are requiring stronger cybersecurity for substation control systems, including network segmentation, access control, monitoring and incident reporting, which drives upgrades of older systems that cannot meet these requirements. Utilities also want more remote operation and diagnostics to reduce site visits and manage larger networks with fewer staff. Secure remote access solutions are needed. Compliance deadlines create investment cycles. Growth is solid.

Challenges •Cybersecurity Complexity and Compliance Costs Connecting substation control systems to wider networks increases exposure to cyber attacks, and securing many devices from different generations and vendors is complex. Compliance with new regulations requires risk assessments, monitoring, documentation, patch management and staff training, which add cost and may require replacing legacy devices. Threat actors target remote access and default credentials. Security must not compromise reliability. Resources are stretched. Costs rise.



•Interoperability, Engineering Effort and Skills Shortages Despite IEC 61850, multi-vendor integration still requires significant engineering and testing, and configuration tools differ between suppliers. Utilities face shortages of protection, automation and network engineers who understand both power systems and IT. Migrating from legacy systems without long outages requires careful planning. Testing practices must adapt to digital designs. Documentation must be maintained. Projects take time.

Trends •Process Bus, Digital Substations and Secure-by-Design Devices Control systems are evolving toward full digital substations with process bus, merging units and process interface units that combine measurement and switchgear control, reducing wiring. New devices include secure boot, encrypted communications, role-based access control and built-in logging to meet cybersecurity requirements. Redundant network protocols and precision time synchronisation are becoming standard. Standard bay designs speed engineering. Adoption is rising.

•Centralised and Virtualised Protection and Control Utilities and suppliers are piloting centralised protection and control, where one high-performance platform runs control and protection functions for many bays, and virtualised systems running on standard servers. These approaches could reduce hardware, simplify upgrades and allow software updates without replacing devices. Network security monitoring and secure remote access are being integrated. Standards bodies are developing guidance. Pilots are expanding. Interest is growing.

Hardware leads because control units, relays, gateways and network equipment are required in every substation, while software and services grow fastest with engineering tools and cybersecurity. Hardware is the largest component segment because substation control systems require bay control units, protection and control intelligent electronic devices, remote terminal units, gateways, station computers, Ethernet switches, routers, firewalls, time synchronisation clocks and human-machine interface equipment, and every new or upgraded substation adds these devices. Replacement of legacy remote terminal units and electromechanical control panels sustains hardware demand in mature networks. Redundant architectures further increase device counts. Software, including substation automation platforms, human-machine interface software, IEC 61850 configuration and engineering tools, gateway and protocol software, and cybersecurity applications, is the fastest growing component because utilities want faster engineering, better data and secure operation, and because control functions are increasingly implemented in software. Centralised and virtualised protection and control would shift more value from dedicated devices to software running on standard hardware. Services, including design, engineering, integration, testing, commissioning, training, maintenance and cybersecurity assessments, form a large share of project value because many utilities lack in-house capacity for complex digital projects. Through the forecast period, software and services are expected to grow faster than hardware, while hardware remains the largest share of initial investment for most new and upgraded substations built by utilities and private owners over the coming years.

Transmission substations lead because they need advanced automation and protection integration, while distribution substations grow fastest as utilities automate large numbers of sites. Transmission substations are the largest segment because they are critical to system stability, contain many bays and complex protection schemes, and require advanced automation, redundancy and secure communication with control centres. Transmission operators have been early adopters of IEC 61850 automation and digital substations, and new substations for renewable connections, interconnectors and HVDC converter stations require sophisticated and highly reliable control systems. Distribution substations are the fastest growing segment because utilities operate thousands of primary and secondary substations and are adding automation, remote control and monitoring to manage distributed generation, electric vehicles, heat pumps and reliability targets. Compact modern remote terminal units, smart secondary substation controllers and integrated automation in new switchgear are making distribution automation more affordable. Industrial substations in oil and gas, mining, metals, chemicals and manufacturing use control systems integrated with plant automation. Renewable and storage collector substations require control systems that coordinate inverters, reactive power and grid code compliance. Through the forecast period, transmission substations will remain the largest segment by value, while distribution and renewable substations grow fastest in number as utilities and developers extend automation across networks and connect large volumes of new generation, storage and demand at many new connection points every year.

Utilities lead because they own most substations and must meet reliability and cybersecurity rules, while renewable developers and industrial users 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, run large construction and replacement programmes and must comply with reliability and cybersecurity regulations. Their standard designs and specifications shape the market, and many have multi-year framework agreements with suppliers. Industrial users, such as oil and gas, petrochemicals, mining, metals, pulp and paper and large manufacturing, operate private substations where control systems are integrated with plant automation and energy management, and reliability directly affects production. Renewable energy and storage developers are among the fastest growing users because every wind, solar and battery plant needs a substation control system that manages the grid connection, coordinates inverters and meets grid code requirements for voltage and frequency control. Data centre operators are building large private substations and need reliable, secure automation integrated with facility management systems. Railways, airports and ports also operate substations with control systems. Each group has distinct requirements. Through the forecast period, renewable developers, storage operators and data centres are expected to grow fastest, while utilities remain the largest buyers and continue to drive standardisation, cybersecurity practices and the move toward fully digital substations across their networks and partners.

New installations lead in fast-growing grids, while retrofit and upgrade projects grow strongly in mature networks as legacy systems reach end of life and fail cybersecurity requirements. New installations are the largest segment overall because grid expansion for renewables, interconnectors, data centres and urban growth adds many new substations each year, especially in fast-growing regions, and new substations are built with modern IEC 61850 control systems from the start. New projects also allow utilities to adopt digital designs, process bus and secure architectures without legacy constraints. Retrofit and upgrade projects form a large and growing segment in mature networks, where many substations still use control systems installed decades ago, including legacy remote terminal units, proprietary protocols and hardwired panels that are no longer supported by manufacturers and cannot meet current cybersecurity requirements. Utilities are replacing these systems in stages, often bay by bay, to avoid long outages, and are adding secure gateways, network monitoring and remote access controls. Cybersecurity regulations are creating deadlines that accelerate retrofit programmes. Retrofits require careful planning, testing and migration of data and settings. Experienced integrators are often hired for this. Through the forecast period, new installations will remain the largest segment globally, while retrofits grow fastest in mature markets as utilities modernise ageing control systems, address cybersecurity gaps and prepare existing substations for digital operation and wider data integration in the future.

North America leads substation control systems through cybersecurity regulation and replacement of legacy automation, Europe follows with digital substation adoption and new cybersecurity rules, and Asia-Pacific grows fastest through large-scale substation construction. North America is the leading region, driven by replacement of legacy remote terminal units and control systems, new substations for data centres and renewables and strict cybersecurity regulation. The February 2024 advisory on Volt Typhoon showed that energy sector networks were being targeted, and in June 2025 regulators approved CIP-015-1 internal network security monitoring requirements, which took effect in September 2025. Utilities are investing in secure gateways, network monitoring and digital automation. Suppliers such as Schweitzer Engineering Laboratories, GE Vernova, Siemens, Hitachi Energy and Schneider Electric are strong in the region. By 2031, growth is expected from replacement, cybersecurity upgrades and new substations.

Europe is a major region with early adoption of IEC 61850 and digital substations by system operators in the United Kingdom, Germany, France, the Netherlands, Spain and the Nordic countries. The electricity network code on cybersecurity, adopted in March 2024, and the NIS2 Directive, with an October 2024 transposition deadline, raise cybersecurity requirements for substation control systems. Great Britain's RIIO-3 price control includes digitalisation funding. The Iberian blackout of April 2025 and the March 2026 expert report focused attention on monitoring and control. By 2031, growth is expected from digital substations, cybersecurity compliance and grid expansion.

Asia-Pacific is the largest and fastest growing region. China builds large numbers of intelligent substations each year with domestic suppliers such as NR Electric and NARI. India's transmission and distribution expansion adds many substations with automation systems. Japan, South Korea and Australia are replacing ageing control systems and adopting digital designs. Southeast Asian utilities are automating new substations. By 2031, the region is expected to account for most new installations.

Latin America is a growing region where transmission auctions and concession contracts in Brazil, Chile, Colombia and Peru add new substations with modern control systems, and Mexico is reinforcing its grid. Utilities are replacing legacy systems and improving cybersecurity. Barriers include budgets and skills. By 2031, growth is expected from new substations and retrofit programmes.

The Middle East and Africa are adopting modern substation control systems in the Gulf, where utilities specify IEC 61850 digital designs for new substations serving giga-projects, data centres and renewables. African utilities are automating substations with development finance. By 2031, growth is expected from Gulf programmes and African grid expansion.

June 2025 – FERC approves internal network security monitoring standard: The Federal Energy Regulatory Commission approved CIP-015-1, requiring monitoring of network traffic inside electronic security perimeters for high- and medium-impact systems, effective September 2025.

October 2024 – NIS2 Directive transposition deadline passes: EU member states were required to transpose the NIS2 Directive, extending cybersecurity obligations for operators of essential services including electricity networks.

March 2024 – European Commission adopts electricity network code on cybersecurity: The delegated regulation sets recurring cybersecurity risk assessments for entities with digitalised processes that have critical or high impact on cross-border electricity flows.

February 2024 – Agencies warn of Volt Typhoon activity in energy networks: A joint advisory said state-sponsored actors had compromised critical infrastructure networks including energy, tested access to operational technology and could reach substation remote access profiles.

January 2024 – Hitachi Energy launches SAM600 3.0 process interface unit: The unit combines merging unit and switchgear control functions with IEC 61850 Edition 2.1 support, redundant communications and security features such as secure boot and role-based access.


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

Aspects covered in this report
• Global Substation Control Systems 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 substations
• •Renewable and storage collector substations

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

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