Section 14a EnWG · Glossary

Section 14a of the Energy Industry Act (Energiewirtschaftsgesetz) is the statutory basis in Germany for agreements on the grid-oriented control of certain electrical consumption devices in return for reduced grid fees. The details are not set out fully in the Act itself, but in particular in determinations of the Federal Network Agency (Bundesnetzagentur). A distinction must therefore be made between the statutory authorisation, the binding implementing rules and their technical implementation on site. This entry describes the researched state of the rules as of 11 November 2026.

The underlying idea is this: new electrical applications are to be connectable despite local grid bottlenecks. To achieve this, certain controllable consumption devices must be able to temporarily limit their power draw. The rule is therefore neither a general power to disconnect households nor a mere voluntary savings tariff. It combines connection options, technical obligations and financial compensation.

Which installations are affected?

The determination applicable since 1 January 2024 in principle covers newly commissioned installations with an electrical grid connection capacity of more than 4.2 kilowatts that are connected directly or indirectly to the low-voltage grid. These include non-publicly accessible charging points, heat pump heating systems including auxiliary heaters, room cooling systems and electricity storage systems when charging. Several heat pumps or room cooling systems are, under certain conditions, aggregated per category.

What matters is the electrical power draw, not the heat output delivered or the storage capacity. A heat pump with, for example, 10 kilowatts of thermal output is therefore not covered merely because of that figure. Likewise, a storage capacity of 10 kilowatt-hours says nothing about whether the relevant power threshold is exceeded. Confusing electrical power, thermal power and stored energy quickly leads to incorrect classifications here.

The rule is not limited to single-family homes or private owners. However, there are exceptions, in particular for certain operationally necessary heating and cooling applications and for charging points of institutions with special entitlements. Normal household consumption is not subject to this control.

Why local grid bottlenecks are not the same as an electricity shortage

The local distribution system operator is responsible for the intervention. The rule addresses a spatially limited load on its grid. Several vehicles charging at the same time or many heat pumps running at the same time can become problematic locally, even if sufficient generation is available in the electricity system as a whole. The Bundesnetzagentur justifies the rule precisely on the basis of the growing and partly simultaneous power draw of such installations.

This can be illustrated by comparison with an access road: the fact that there are enough roads across the country does not prevent congestion at a single narrow access road. Applied to the electricity grid, the question is therefore not only how much energy is available overall, but also where and when it is to be transported. A local power limitation therefore does not allow any conclusion about a nationwide electricity shortage.

What is controlled is power, not directly a daily quantity of energy. A calculation example: a wallbox charging at a constant 11 kilowatts could draw 22 kilowatt-hours in two hours. At 4.2 kilowatts, it would be 8.4 kilowatt-hours in the same period, in each case before charging losses. The limitation thus initially lengthens the charging time. Whether enough energy has been charged by departure additionally depends on arrival time, state of charge and the desired driving distance.

What the grid operator may limit

In the case of direct control, the minimum power to be provided in principle is 4.2 kilowatts per covered device. For heat pumps and room cooling systems above 11 kilowatts, scaled values apply, in principle 40 percent of the connection capacity. Via an energy management system, a shared power budget is instead specified, taking simultaneity factors into account. A system that cannot be technically modulated to fit must, where applicable, reduce to the next lower possible level.

The statement "Every device always keeps running at at least 4.2 kilowatts" would therefore be too sweeping. The minimum power describes a power draw option to be granted on the grid side, not a guaranteed operating mode of each device. In the case of joint control, one application may also temporarily yield to another. For planning, what matters is therefore the interplay of device technology and control concept, not just a single threshold figure.

The regular grid-oriented limitation may only take place to the extent necessary and for as long as the risk exists. There is no general two-hour limit for it. That limit applies to the time-limited preventive transitional control: at most two hours per day, a maximum of 24 months per grid area and no later than the end of 2028.

The new regime thus differs from older, contractually fixed blocking times. Its guiding principle is a limitation based on the grid state rather than a flat daily interruption. For the assessment of a specific case, it must nevertheless first be clarified whether the new control is already being applied or whether a permissible existing-installation or transitional rule still applies.

Battery storage and self-generated electricity

For storage systems, the technical possibility of charging from the grid is decisive. A mere software setting to charge exclusively with solar power does not necessarily remove the participation obligation. Section 14a concerns the grid-relevant power draw, not an obligation to feed in. An energy management system can make own generation or storage discharge usable for consumers in addition to the permissible grid power.

As a simplified example: if 4.2 kilowatts of grid power and, at the same time, 3 kilowatts of own solar power are available for a wallbox, 7.2 kilowatts of charging power would be possible arithmetically. A prerequisite is a control concept that takes the actual energy flows into account. A limitation of grid draw is therefore not automatically an equally large limitation of total consumption within the building.

How the financial consideration works

Determination BK8-22/010-A classifies the reduced grid fees into three modules. Modules 1 and 2 serve as compensation for controllability; Module 3 additionally creates incentives to shift power draw to times of lower grid utilisation. It is not a remuneration per control intervention actually carried out.

Module 1: flat-rate fee reduction per billing market location; several devices do not automatically multiply the flat rate.
Module 2: The grid fee energy price falls to 40 percent, that is, by 60 percent. A separate consumption metering is required for this. The total electricity price does not fall by this percentage.
Module 3: time-variable grid fees with three tariff levels, supplementary to Module 1 and not combinable with Module 2. The offer has been mandatory since 1 April 2025.

For an economic comparison, the maximum relief alone is not sufficient. Metering and control costs, contract terms and the consumption that can actually be shifted must also be considered. An additional meter may be assessed differently in the case of high consumption than for a rarely used charging device. Likewise, a favourable time window helps little if the application in question is then regularly unavailable.

Legal entitlement and practical implementation must not be confused. On 28 May 2026, the Bundesnetzagentur reported on enforcement proceedings due to inadequate implementation, particularly for Module 3. It follows neither that the module is voluntary nor that its billing already works smoothly at every grid operator.

Existing installations, connection and responsibilities

For installations operated before 2024 with the old Section 14a benefit, transitional rules apply in principle until the end of 2028, and thereafter the new regime. Legacy installations without a corresponding agreement in principle remain exempt; a voluntary switch is possible. Special continuation rules exist for night storage heaters. Replacement or substantial changes can end the grandfathering protection.

Participation prevents a refusal of connection solely due to insufficient grid capacity. However, it replaces neither a technically suitable house connection nor registration and safe installation. As soon as the statutory requirements are met, control via the smart meter gateway is envisaged; the Act contains exceptions and transitional provisions in this regard.

In practice, operators should therefore clarify three questions separately: Which installation is being registered? How is the control command implemented technically? How is the fee reduction billed? This separation avoids, for example, the false expectation that choosing an electricity tariff already establishes technical controllability. Conversely, an existing control interface does not yet answer the question of the appropriate billing model.

Distinction from market incentives and significance for grid expansion

A dynamic electricity tariff and Section 14a pursue different purposes: the tariff makes shifting consumption financially attractive; grid-oriented control sets a binding limit in response to a local problem. Flexibility can thus be used in a market-based and grid-related way. The two are not automatically congruent: a charging time that is attractive to many customers at once can create new local load peaks.

Redispatch is also not simply another name for Section 14a. What matters is the respective instrument with its own legal bases and processes; the sweeping contrast of "transmission grid versus distribution grid" would be too coarse as a distinction. For this glossary term, the focus is on the regulated limitation of certain power draws in the low-voltage grid.

Finally, control does not replace needs-based grid expansion. The expansion obligation remains; recurring interventions must feed into planning and the examination of remedies. The sensible yardstick is therefore neither "Control must never take place" nor "The more frequent the control, the more expansion is saved". What matters is whether connections are enabled, local loads are managed and lasting bottlenecks are eliminated.

Sources

Energiewirtschaftsgesetz, § 14a: Netzorientierte Steuerung von steuerbaren Verbrauchseinrichtungen und steuerbaren Netzanschlüssen; Festlegungskompetenzen — Bundesministerium der Justiz und Bundesamt für Justiz; unbekannt. Absätze 1, 3 und 4
Anlage 1 zum Beschluss BK6-22-300: Festlegung zur Durchführung der netzorientierten Steuerung — Bundesnetzagentur, Beschlusskammer 6; 2023-11-27. Ziffern 2.4, 3.1, 4.1–4.6, 5, 6 und 10.5
Integration von steuerbaren Verbrauchseinrichtungen — Bundesnetzagentur; unbekannt. Abschnitte „Betroffene Anlagen und Dimm-Regelungen“, „Reduzierung des Netzentgelts“ und „Regelungen Bestandsanlagen“
Verfahren wegen mangelnder Umsetzung der Netzentgeltreduzierungen für Elektrofahrzeuge und Wärmepumpen — Bundesnetzagentur; 2026-05-28. Abschnitte „Einleitung von Verwaltungsvollstreckungsverfahren“ und „Hintergrund“
BK8-22/010-A: Festlegung von Netzentgelten für steuerbare Anschlüsse und Verbrauchseinrichtungen — Bundesnetzagentur, Beschlusskammer 8; unbekannt. Verfahrensübersicht, einleitende Erläuterung der am 23. November 2023 abgeschlossenen Festlegung

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Edited by eCMS on 11.11.2026 13:58