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Integrate medium-voltage (MV) switchgear as part of an engineered power-system protection and control design—not as a standalone equipment or communications project. Start with the site’s one-line diagram, sources and operating modes; complete the applicable electrical studies before setting relays; then define what protection IEDs do locally and what status, measurements, alarms and authorized commands they exchange with data-center systems. The utility interface, relay settings, network design and acceptance criteria must be established for the specific site.
What does integration need to accomplish?
The design has to make the electrical system’s behavior and the control system’s view of it consistent. MV switchgear may connect utility feeds, transformers, bus sections and ties, onsite generation, and other sources that support data-center loads. The arrangement and operating modes determine which protection zones, transfer sequences, signals and control permissions are appropriate.
Keep three responsibilities explicit:
- Protection: Detect specified electrical faults and initiate the approved trip or other protective action through the responsible protection devices and associated circuit breakers.
- Automation and local control: Carry out approved switching, interlocking and operating sequences at the appropriate control devices.
- Supervision: Provide operators and data-center systems with defined measurements, status, alarms and events, and permit only explicitly authorized supervisory commands.
These functions can exchange information, but that does not make them interchangeable. The project must specify where each function resides, which device is authoritative, and what happens when a device or communications path is unavailable.
Which standards and guidance are relevant?
The references below cover different parts of the problem. IEEE P4134 and IEEE P4200 are active standards projects, not completed published guides; their stated scopes can inform planning, but they should not be cited as finalized requirements.
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| Reference | Status and relevant scope |
|---|---|
| IEEE 2030.100-2017 | Active recommended practice, published June 19, 2017. Covers implementing IEC 61850 substation communications, protection, monitoring and control, including single- and multi-vendor environments and IED specification, procurement, configuration and documentation. |
| IEEE P4134 | Active project as of October 4, 2026; its approval date is May 14, 2026. Its stated scope includes substations serving data centers and other large loads, reliability and redundancy, onsite generation and storage, studies, telemetry, expansion and resilience. |
| IEEE P4200 | Active project as of October 4, 2026; its approval date is June 4, 2026. Its stated scope includes data-center transmission and distribution interconnection topics such as ride-through, protection coordination, fault recovery, power quality, backup-power interactions, commissioning and operations. |
| IEC TR 61850-90-4:2020 | Second edition, published May 25, 2020. Provides network-engineering guidance for IEC 61850 substation LANs, including topology, redundancy, clock synchronization, GOOSE trip messaging and sampled values. It excludes network-based security and wide-area network engineering. |
| IEC TR 61850-90-6:2018 | Published September 20, 2018, with a January 2020 corrigendum noted by IEC. Covers information exchange for distribution automation, including MV network use cases, component models, communications architecture and IED configuration; the scope of distribution automation varies by country, region and utility. |
| IEEE C37.234-2021 | Publication date listed as February 7, 2022. Discusses bus protection and how bus arrangement, breakers, current sensors, disconnect switches, bus switching and breaker-failure protection affect scheme selection. |
Use the current applicable editions and local requirements for the project. These references provide implementation or planning guidance; they do not supply this site’s equipment ratings, protection settings, utility rules or complete acceptance test.
How should the integration be engineered?
1. Establish the electrical boundary and operating cases
Produce or confirm the one-line diagram and identify the utility point of interconnection, MV incomers, transformers, buses and ties, generators, UPS or other backup sources, and relevant load groups. Map normal operation as well as the transfer, maintenance, islanded or recovery modes that the project actually supports. Record who owns and operates each boundary, what the utility requires, and which jurisdictional standards apply.
Include compute-load characteristics and planned growth in the engineering inputs: IEEE P4134’s stated scope specifically recognizes that compute load can affect equipment ratings and operation. Do not infer a rating, topology or operating rule from that scope; establish it through the project’s design and studies.
2. Complete studies before selecting relay settings
Model the source and load combinations relevant to the defined operating cases, including backup-source interactions and applicable short-circuit conditions. Use the results, breaker and bus arrangement, and utility interface to develop and coordinate the protection scheme. Evaluate bus protection and breaker-failure protection where the arrangement and study require them; IEEE C37.234-2021 explains why those choices depend on bus configuration and associated devices.
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3. Assign device, automation and supervisory responsibilities
Specify which IEDs perform protection functions and any required trip logic. Separately define the points exchanged with station or substation control and with the data-center supervisory layer. A point list should identify, as applicable, measurements, breaker and switch status, alarms, events, commands, their source of truth, and the authority allowed to issue each command. Define behavior for invalid data, loss of communications and conflicting control requests in the project design.
For IEC 61850 implementation, govern device names, data models, configuration files, versions and documentation across procurement, configuration and acceptance. IEEE 2030.100-2017 is a practical implementation reference for this work; IEC TR 61850-90-6 adds distribution-automation and MV use cases.
4. Engineer the communications network for its actual application
Choose LAN topology and redundancy based on the exchanges the design actually uses, their performance needs and credible failure cases. Decide whether GOOSE messaging, sampled values or process-bus functions are part of the application rather than assuming every IEC 61850 installation uses them. Provide clock synchronization where event chronology, sampled values or other application requirements make it necessary.
IEC TR 61850-90-4:2020 addresses substation LAN engineering, but explicitly excludes network-based security and wide-area network engineering. Therefore, use separate project requirements and responsible expertise to define the security boundary and any connections beyond the substation LAN. It also calls for analysis of the actual application configuration by the responsible integrator; a topology label alone does not establish suitability.
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5. Document the data-center interface
Show the intended path from protection and control IEDs through station control, any gateway or SCADA layer, and the data-center power-monitoring or supervisory systems. Specify protocol conversion if needed, which system receives each point, command authorization, and the response to interface or gateway failure. IEEE P4134’s stated scope includes telemetry between substation equipment and compute loads, but it does not mandate a universal SCADA layout or northbound protocol.
6. Commission the configured application
Write acceptance criteria and test procedures against the approved design. Commissioning should verify more than connectivity: check IED configuration and signal mapping, communications behavior, trip and interlock logic, timestamps, alarms and events, redundancy behavior, operating-mode transitions, and backup-power interactions that are in scope. Test failure cases and recovery behavior that matter to the design, including loss of a communications path or supervisory interface where applicable.
IEEE P4200’s stated project scope emphasizes study models, protection and reclosing behavior, backup-power interaction, monitoring, commissioning and operations. It does not provide a complete test script for every site, so the responsible project team must define the tests and evidence needed for acceptance.
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How can you compare design proposals?
Compare proposals against the same operating cases and failure scenarios, rather than treating a brand, protocol or redundancy label as proof of performance. Ask each designer or integrator to show how its proposed design addresses:
- Protection, automation and supervisory responsibility boundaries, including local behavior when communications fail.
- Bus and source redundancy, transfer behavior and the consequences of relevant equipment or path failures.
- IED functions, configuration governance and interoperability across vendors.
- Network topology, timing needs and redundancy for the specified protection and supervisory exchanges.
- Integration with generators, UPS and other backup sources across the operating modes in scope.
- Telemetry, command authority and interface responsibilities between the substation and data-center systems.
- Expansion, maintainability, commissioning criteria and retained evidence.
IEEE P4134, IEEE 2030.100-2017 and IEC TR 61850-90-4 support these as useful comparison areas; they do not identify a universally superior architecture. Final selection depends on the site’s studies, utility interface, operating requirements and responsible engineering decisions.
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