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Glossary · Energy industry & energy transition

ADMS, Advanced Distribution Management System

ADMS Advanced Distribution Management System distribution grid grid operation SCADA DERMS Digitalisation

ADMS stands for Advanced Distribution Management System and denotes an integrated control and operations platform for electrical distribution networks. It supports the control centre in assessing network states, preparing switching operations, localising faults and organising the restoration of supply. An ADMS is not a single asset in the power grid but a software-based operational layer. Which functions are actually integrated and automated depends on the product, the network and the scope of the respective implementation.

Why distribution networks need more comprehensive operational management

Photovoltaic systems, battery storage, heat pumps and charging equipment change the requirements for network operation. In addition to power consumption, reverse power flow occurs at times; consumption and generation can become strongly concentrated locally. What matters is therefore not only how much energy is transported over a year. The control centre must be able to assess when and where lines or transformers are heavily loaded and which operational options are available.

To illustrate: two residential areas can have the same annual electricity consumption and yet cause very different network problems. If many vehicles charge at the same time in the evening in the first area, a pronounced consumption peak arises. If numerous solar systems feed in at midday in the second area, the voltage there may rise. An annual figure in kilowatt hours describes neither these differences over time nor their local effect. For decisions, the control centre needs an electrical picture of the respective network area.

Network model, measurement data and calculations

The foundation is a maintained network model. It describes lines, transformers, switches and their electrical connections as well as relevant equipment data. Together with current switching states, it yields the operational network topology: which sections are connected, disconnected or supplied via another path? Geographical proximity alone is not sufficient; what matters is the electrical connection.

The ADMS normally does not itself measure voltage, current or active and reactive power. It takes over data from telecontrol systems, sensors and other IT systems; depending on the setup, meter data may also be added. However, not every data source delivers equally often or equally fast. A measured value suitable for billing is therefore not automatically suitable for a time-critical operational decision.

A load flow calculation can be used to calculate loads and voltages for an assumed network state. State estimation is intended to derive a consistent picture of the state from available information. The distinction between measured, estimated and forecast quantities remains important: a calculated value is not an additional measurement. Missing information does not automatically become reliable knowledge through software.

A simple thought experiment illustrates the importance of the model: if a switch that has been opened on site is still recorded as closed in the system, the calculated supply may run via a path that is in fact interrupted. Even very accurate measured values elsewhere do not necessarily correct this model error. Feedback on switching operations that have been carried out is therefore just as important as computing speed.

Typical functions in the control centre

  • Monitoring and analysis: displaying operating states, detecting limit violations and assessing possible developments with the help of forecasts.

  • Switching planning: examining alternative supply paths and calculating the consequences of planned switching operations before they are carried out.

  • Fault handling: localising fault locations, isolating faulty sections and restoring supply to unaffected sections. This group of functions is often called FLISR: Fault Location, Isolation and Service Restoration.

  • Voltage and reactive power optimisation: using suitable control options in a coordinated way, for example controllable transformers or correspondingly integrated inverters. The abbreviation VVO stands for Volt/VAR Optimization.

After a cable fault, for example, the ADMS might propose supplying via a neighbouring line. The decisive question is then not only whether a connection exists: can this line take on the additional load? Do the voltages remain permissible? Can the switching sequence be carried out safely? Successful restoration of supply must not merely shift the bottleneck to another network section.

Such functions can work as a recommendation, after approval by the control centre, or automatically for clearly limited use cases. The term ADMS therefore does not mean that the entire network is operated autonomously. Automatic decisions require defined operating limits. Furthermore, the ADMS replaces neither the switching devices that carry out the operations nor all local protection and control functions.

Distinction from SCADA, OMS, EMS and DERMS

SCADA stands for Supervisory Control and Data Acquisition and covers in particular monitoring, data acquisition and remote control. ADMS supplements this layer with more extensive network analyses and coordinated operational functions. SCADA can be part of the same platform or connected via interfaces. An Outage Management System, OMS for short, concentrates on supply interruptions, affected customers and the organisation of restoration.

EMS is ambiguous: in network control centre technology, Energy Management System often denotes a system for tasks in the transmission network. In buildings or industrial plants, by contrast, the same abbreviation stands for local energy management. ADMS is geared towards distribution network operation; medium and low voltage are important fields of application. However, the voltage levels actually covered and the depth of modelling must be defined on a project-specific basis.

A DERMS coordinates distributed energy resources and their available control options. ADMS and DERMS can be separate systems or closely integrated functions. The short formula “ADMS looks at the network, DERMS at the assets” helps as an introduction but does not describe a rigid boundary: a DERMS can also take network restrictions into account. What matters are responsibilities, data and the coordinated execution of measures.

Flexibility and legal limits

Flexibility is helpful for network operation only if its change acts in the right direction at the required location. As an example: additional battery charging can provide relief during local solar reverse feed-in, but may add load during an evening consumption peak behind the same transformer. An operating mode that is attractive in price terms is therefore not automatically beneficial to the network. The network view must be coordinated with asset control and, where applicable, market processes.

For Germany, § 14a EnWG (German Energy Industry Act) is an important framework of application, but not a general permission for an ADMS to intervene. According to the regulatory status researched, the requirements introduced on 1 January 2024 apply in particular to new controllable consumption devices in low voltage with a grid connection capacity of more than 4.2 kW: non-public charging points, heat pumps, space cooling and electricity storage with regard to their grid consumption. Special rules apply to existing installations and to the aggregation of certain installations.

The network-oriented control concerns power consumption, not photovoltaic feed-in or ordinary household consumption. In principle, 4.2 kW remains available in the case of direct control; different calculations apply to larger heat pumps or cooling systems and to control via an EMS. An ADMS can support state assessment and measures, but replaces neither the legal basis required in each case nor the technical control chain.

Implementation, cost-effectiveness and limits

An ADMS project is more than a software procurement. Data maintenance, interfaces, training, organisational responsibilities and ongoing operation are part of it. Added to this are requirements for access protection, availability and fallback procedures. Network planning, control centre, field service and IT must be able to pass on changes consistently. The possible benefit lies, among other things, in better fault handling and better-founded operational decisions; a blanket cost reduction cannot be derived from this.

For assessment, a concrete test question is preferable to a general promise of digitalisation: which decision is demonstrably improved by the platform? In the event of a fault, this could be faster, safe switching planning. In normal operation, it could be a more reliable assessment of a local overload. Such evidence also includes making uncertainties and the manual work that remains necessary visible.

Network expansion also does not become superfluous through a more accurate picture of the state. Software can recognise a physical limit and, where appropriate, support a suitable operational measure; however, it does not enlarge a conductor cross-section. Where more power must be transported permanently and operational options are not sufficient, network reinforcement remains necessary. Digitalisation and structural measures should therefore be assessed as complements, not as fundamental opposites.

Finally, ADMS is not a synonym for artificial intelligence. Forecasts or learning methods can support individual functions; the designation does not presuppose them. For the technical assessment, it is more important whether data, assumptions and recommended actions are comprehensible. The practical yardstick remains a safe operational decision: what is known, what is only estimated, which measure is permissible and what happens if data or communication fail?

Sources

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Edited by eCMS on 11.11.2026 13:58

© 2026 Erik Schmidt. All rights reserved. Quotations with a link to the source are welcome.