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Glossary · Energy industry & energy transition

Front-of-the-Meter

front-of-the-meter storage grid connection electricity market grid operation generation Behind-the-meter balancing energy

Front-of-the-Meter refers to power generators, storage systems or controllable consuming devices that, from the perspective of a customer connection, are located on the grid side of the meter. They have their own connection to the public electricity grid. The term does not describe a particular technology but classifies an asset by its connection and metering. It is not part of the internal installation of a household, a commercial business or an industrial site. Instead, it participates in the grid and market system via its own grid connection point. The expression comes from English-language industry jargon and is not a legal term in German energy law. Legally, what matters in Germany are concepts such as grid connection, customer installation (Kundenanlage), distribution grid, final consumer and energy storage facility.

Typical front-of-the-meter assets are wind farms, solar parks, large battery storage systems, electrolysers with their own grid connection and conventional power plants. An example: a battery storage system stands next to a substation and has its own connection. It draws electricity from the grid and feeds it back in, so it is front-of-the-meter. The same battery technology would be behind-the-meter if it were located behind the meter of a building or a business. It would then mainly affect on-site consumption, self-consumption or the load peaks at the connection.

The distinction therefore does not depend on the device, but on how the asset is connected and how it is metered. The meter at the transfer point is more than a measuring device. It marks the boundary for billing, market communication, grid charges, balancing and responsibilities. On one side are the customer's installations with their internal consumption and, where applicable, their own generation. On the other side is the public grid. There, feed-in and withdrawal are handled according to the rules of the electricity market, the grid connection conditions and the balancing group system.

Distinction from behind-the-meter

Behind-the-meter assets act first of all within a customer site. A photovoltaic system on a commercial roof reduces electricity drawn from the grid there. A battery behind the meter can shave load peaks, increase self-consumption or, with dynamic tariffs, shift grid consumption in time. The meter at the grid connection point then records only the remaining exchange with the public grid.

Front-of-the-meter assets, by contrast, appear entirely as separate market and grid assets. Feed-in and withdrawal do not run through the meter of an individual end customer. They are metered separately, assigned to a balancing group and settled. A large battery storage system, for example, buys electricity on the wholesale market, charges it from the grid and feeds it back in later. In addition, it can offer balancing energy or other system services. Its business model does not consist in reducing an individual electricity bill. It is based on price differences (arbitrage), flexibility and balancing energy markets, and contracts with grid operators or direct marketers.

In short, one speaks of assets "in front of the meter" and "behind the meter". This is useful as long as it remains clear which meter is meant. Larger sites often have several metering levels: sub-meters, transfer metering and generation meters. An asset can be located behind an internal sub-meter and still belong to the customer installation. What is decisive is the transfer point to the public grid, not the location on the property. Classification is difficult in mixed concepts, for example a battery storage system at the grid connection point of a solar park. There it depends on the specific metering and marketing concept.

For Germany, one further point should be noted: whether an area may be regarded internally as a customer installation has to be viewed much more narrowly since a judgment of the Court of Justice of the European Union of 28 November 2024 (C-293/23). The Federal Court of Justice followed this on 13 May 2025 (EnVR 83/20). Accordingly, an energy installation can only be a customer installation if it is not a distribution grid within the meaning of the EU Internal Electricity Market Directive. If electricity is passed on to third parties and sold, this regularly points to a distribution grid. The boundary between "behind the meter" and "grid" can therefore shift in the case of neighbourhoods and area networks.

Why the classification matters in practice

The classification helps determine which rules apply to an asset. These include:

  • technical connection conditions and the grid connection procedure,

  • the metering concept and assignment to a balancing group,

  • remote controllability and marketing obligations,

  • grid charges and integration into redispatch,

  • prequalification for balancing energy.

An asset with a direct grid connection is also examined as to how it affects voltage, short-circuit power, reactive power balance, protection technology and grid congestion. It is thus part of grid operation and not merely a private optimisation unit.

For large storage systems, the classification is particularly important. A front-of-the-meter battery storage system can charge when electricity is cheap and feed in when it is more expensive. It can support frequency maintenance, offset short-term forecast errors or complement the marketing of wind and solar power. At the same time, it burdens the grid like a consumer when charging and like a generator when discharging. The grid connection must cover both directions. This raises questions about connection capacity, grid compatibility and controllability over time.

On the electricity market, front-of-the-meter assets make price signals effective. A battery in wholesale trading responds to price differences in hourly or quarter-hourly intervals. An electrolyser with its own grid connection can orient its operation to electricity prices, hydrogen offtake and grid restrictions. Such assets help integrate wind and solar power when their operation matches the scarcities in the system. However, they can also place additional strain on the grid if they respond only to wholesale prices. Local congestion is often only inadequately reflected in these prices.

Here technical possibilities, market rules and responsibilities diverge. A storage system can react technically very quickly, and the wholesale market rewards certain charging and discharging times. For local grid security, however, the distribution system operator or transmission system operator is responsible. If the market rewards a mode of operation that aggravates congestion at a grid node, technical flexibility alone is not enough. Then connection conditions, congestion management, redispatch and grid-serving agreements become important.

Storage and grid operators: ownership and unbundling

A front-of-the-meter asset does not automatically belong to a grid operator. A battery storage system can belong to a project developer, energy supplier, fund or industrial company and still be connected directly to the grid. In the EU this is in fact the rule. The Internal Electricity Market Directive (EU) 2019/944 in principle prohibits distribution system operators from owning, developing, managing or operating energy storage facilities (Article 36). A corresponding prohibition applies to transmission system operators under Article 54. Exceptions are possible, for example for fully integrated network components with the approval of the regulatory authority. A further exception applies if a regulated tender procedure finds no suitable third party, the storage system is necessary for the secure operation of the grid and it is not used for purchases or sales on the electricity market.

In Germany, sections 11a and 11b of the Energy Industry Act (EnWG) implement these rules. A grid operator may put out to tender the construction and operation of a storage facility owned by third parties in an open, transparent and non-discriminatory procedure if it needs it for its grid obligations. The third party may build a more powerful facility than required. Capacity and energy that the grid operator does not need may be sold by the third party on the electricity markets. According to the Federal Network Agency (Bundesnetzagentur), a grid operator may in principle not hold its own storage systems. This is possible only in the exceptional cases of section 11b EnWG with approval. This separation protects competition. However, it complicates simple solutions where storage is needed primarily to stabilise the grid.

Grid connection, grid charges and costs

The grid connection is often the bottleneck for front-of-the-meter assets. Wind farms, solar parks, large storage systems and new large consumers compete for connection capacity at suitable locations. If several assets want to use the same grid area, reviews, waiting times, grid reinforcements or limits on feed-in or withdrawal capacity follow. It is then not only a question of whether an asset makes sense in terms of the economy as a whole. It is also a question of whether it fits into the grid at this location and with this capacity profile. A storage system at a heavily loaded grid node can be valuable if it relieves congestion. The same storage system elsewhere may merely exploit price differences without solving local grid problems.

Costs are also not trivial. Front-of-the-meter assets need grid connections, metering technology, communication and protection technology and often grid reinforcements. Part of this is borne directly by the connection user, another part is spread across all grid users via grid charges. For grid-connected electricity storage in Germany, a special rule applies (section 118(6) EnWG): facilities that go into operation by 4 August 2029 are exempt from grid charges on the electricity drawn for 20 years. This applies insofar as the electricity is fed back into the same grid with a time offset.

The Federal Network Agency is currently reorganising the grid charge system ("AgNes" procedure). According to specialist reports, the existing exemption is to be retained for storage systems that meet the statutory requirements. A draft determination of August 2026 ties grandfathering, among other things, to an investment decision before the determination. A capacity-based charge is being discussed for later storage systems. The details had not yet been finally determined at the time of processing.

This shows a distribution problem. If an asset earns revenues privately on the markets while grid-related follow-up costs are partly spread across everyone, an imbalance arises. If, on the other hand, it demonstrably avoids grid expansion or provides system services more cheaply than alternatives, it can lower system costs. This depends on concrete operating rules, not on the front-of-the-meter label.

Common misunderstandings

  • "Front-of-the-meter means large." Size often plays a role in practice but is not a defining feature. A small asset with its own grid connection is front-of-the-meter. A large battery behind the transfer meter of an industrial company is behind-the-meter.

  • "Front-of-the-meter is automatically grid-serving." A storage system engaged in arbitrage does not by itself stabilise the local grid. It contributes to frequency maintenance only if it is prequalified and deployed accordingly. It avoids congestion only if location, control and remuneration fit.

  • "Behind-the-meter is worthless for the system." Many small assets can be pooled via virtual power plants, dynamic tariffs or controllable consuming devices and used for the grid and the market. For this, however, they usually need additional models for aggregation, metering and control. Front-of-the-meter assets can be addressed more directly because they act as separate market participants or connection users.

  • "Grid side means grid operator ownership." Because of the unbundling rules, it is usually precisely the opposite: grid-connected storage systems generally belong to market participants. Grid operators may own or operate them only exceptionally.

Assessment

The term is important for the energy transition because more renewable generation, more electrification and more flexible assets meet on the same grids. Front-of-the-meter projects can move large quantities of electricity and react quickly to price signals. They are thus important building blocks for flexibility, security of supply and market integration. However, the term does not say whether an asset is renewable, flexible, grid-serving or cost-efficient. It shows which rules apply, who is responsible, which markets are accessible and which grid effects have to be examined. Therein lies its practical value for classifying storage systems, generation assets and new large consumers.

Sources

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Edited by eCMS on 12.11.2026 05:05

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