The existing Electricity Grid Charge Ordinance (StromNEV) dates back to 2005. It will expire due to a judgment by the European Court of Justice on December 31, 2028, expires. As of January 1, 2029, the new AgNes rules must be practically applicable – a very tight schedule for a reform of this magnitude.
The Federal Network Agency's internal timetable plans for this summer to first draft of the stipulation to be published for formal consultation. The AgNes framework decision is to be adopted by the end of 2026. From 2027 onwards, implementation preparations and the first subsequent decisions will begin – including those on industrial network charges, dynamic network charges for storage, and the further development of the § 14a regulations.
The dimension of the reform is considerable: the annual grid costs currently amount to around 37 billion euros and, according to estimates by the Federal Network Agency, are expected to rise to approximately 67 billion euros by 2035 and to around 79 billion euros by 2045. They already account for more than 30% of the industrial electricity price—a cost factor that can hardly be ignored.
The new basic model for large consumers: capacity price instead of performance price
In our Report from May 2026 We have already outlined the new price model for performance-metered consumers. The current status confirms this assessment. For consumers with an annual consumption of over 100,000 kWh — meaning commercial and industrial customers — the following will apply from 2029:
Order capacity (kW) × Capacity price (€/kW/year) + Energy price AP1 (ct/kWh) + Energy price AP2 (ct/kWh)
The previous Performance premium, which is based on the measured annual peak load, is omitted. It is replaced by a Capacity price for a pre-ordered service. This is a fundamental conceptual shift: no longer the actual measured peak load, but the capacity pre-ordered by the consumer, will determine the cost burden.
How does order capacity work?
Each year, industrial customers can, after their grid operators publish the price sheets, Order capacity in kW determine — up to a maximum of the contractually agreed grid connection capacity, and at least 10% of the previous year’s individual annual peak load. If no order has been received by January 1, the grid operator will determine the capacity based on the available load profile data.
For sets within the lower one applies to the ordered capacity AP1. For sets above the ordered capacity, the significantly higher AP2 — at least double, maximum 3.5 times that of AP1. This is the actual flexibility signal: those who consume more than ordered at short notice will pay a noticeable surcharge, but can still react — without, as before, being permanently charged for the capacity price due to a new peak load.
The grid operators are given leeway: Between 30 % and 60 % They can achieve their revenues through work prices. This range explains why regional grid tariff differences will continue to exist in the future.
What specifically is changing for energy managers?
The shift from a performance-based price to a capacity-based price significantly alters the optimization logic. Previously, the rule was: avoid peak load at all costs. In the future, the rule will be: intelligently select order capacity and specifically leverage favorable spot prices. This creates new opportunities for action for companies with flexible loads – charging infrastructure, electric furnaces, compressed air, cooling, and electrolysis.
The new cost allocation shifts existing structures.
Anyone who listened carefully at the event knows: In addition to the new base model, the Reform of cost allocation between network operators another system-changing turning point. This is where the decisive redistribution takes place — and it will have a greater impact on network charges for industrial customers than the basic model alone.
The problem of the status quo
Today, cost allocation is based exclusively on the actual withdrawals measured from a downstream grid from the upstream grid level. The logic is simple: those who draw little electricity from the higher-level grid pay low upstream grid costs.
This principle leads to an imbalance. Distribution grids with high decentralized feed-in—primarily from PV and wind—often have only low physical residual loads compared to the upstream level. Their rolled electricity costs fall accordingly. At the same time, they continue to use the overall system intensively: with Dark doldrums, for the Redispatch, for system services, for loss energy, and for the transport of high renewable energy feed-ins.
The Federal Network Agency has clearly named the result of this systematic approach: Rate anomalies. Network charges in downstream grid levels are often lower than in upstream levels today – a false incentive also when choosing the grid connection point.
The new key: Network-related final consumption
In the future, cost allocation will no longer be based on measured withdrawals from the upstream level, but on the so-called „grid-related final consumption”. This includes all final consumer withdrawals within its own network level as well as the withdrawals of all downstream network levels down to low voltage.
This fundamentally changes the logic: It is no longer the local residual load compared to the upstream level that decides, but the entire consumption behind the grid. Decentralized generation thus loses considerable importance for cost allocation. A distribution network operator with a lot of PV feed-in will in the future be charged for upstream system costs in the same way as one without.
Technically, the circulation key is based on actual values from the previous year and is adjusted annually. A hardship clause is provided for very significant changes.
The consequence: Higher grid fees in medium and low voltage
The Federal Network Agency's presentation contains model calculations on the effects of this system change. The result is clear:
In the High voltage and the High-voltage/Extra-high-voltage transformation the costs borne by end consumers decrease by around 48 % to 53 % compared to the status quo. Industrial customers directly connected to high-voltage grids and traditionally having high withdrawals from the upstream level today benefit from the reform.
In contrast, the cost shares are increasing, primarily in Medium and low voltage networks — partly significantly. Rural distribution grids with high renewable energy penetration are particularly affected. These higher costs at the distribution system operator level are ultimately passed on through their price sheets — as higher capacity and/or energy prices. For industrial customers in the medium-voltage grid in regions with strong renewable energy penetration, this means: The grid fee reform will be more expensive, than the new base model alone would suggest.
The Federal Network Agency is consciously accepting this shift. It considers the previous favor shown to grids strong in renewable energies to be technically and economically unreasonable.
Feed-in tariffs: Producers also pay for the first time
Starting from January 1, 2029 General feed-in tariffs should be introduced for the first time. Previously, generation facilities were exempt from paying general grid fees — even though they contribute significantly to grid costs.
The feed-in tariff is capacity-based, nationally uniform and does not include a work price component. Systems with an installed gross capacity of more than 30 kW. The transmission system operators determine the amount annually based on a rolling 5-year average. The Federal Network Agency indicates an order of magnitude of 4 to 7 €/kW/year — their own sample calculation shows rolling values between €5.38 and €5.65/kW/year for the years 2020 to 2026.
The revenue will be passed on in full to the TSOs and will be used to reduce costs and be factored into the nationwide transmission grid fees — thus indirectly relieving all consumers. The Federal Network Agency expects up to 2 billion euros per year.
Existing plants as well as plants for which a final investment decision (FID) was made before the AgNes regulation came into force and which, by **[date]** at the latest August 4, 2029 go into operation, receive a 20-year grandfather clause.
Storage: Protection of trust remains — new fees are coming
BNetzA President Klaus Müller summarized the central message: „We weigh the protection of legitimate expectations higher than in our previous proposals.” The statutory grid fee exemption according to § 118 para. 6 EnWG for Battery storage remains, if the FID before the AgNes regulation takes effect was hit and the memory by \[at the latest] August 4, 2029 goes online.
For new grid-connected storage systems, effective from the FID after the decision comes into force: Moderate capacity price - analogous to the feed-in tariff, i.e., in the order of 4 to 7 €/kW/year. This applies once for both directions, and there are no variable charges for storage. The Federal Network Agency argues that this annual charge is very low in relation to the annualized investment costs of a BESS.
Dynamic grid charges for storage will come at the earliest 2030, as soon as possible by 2033. With proper design, the BNetzA sees this as an income opportunity rather than a burden for storage operators - with grid-friendly use, fees of up to 10 euro cents/kWh could be incurred.
Industrial network charges: grace period until the end of 2031
The network load privilege (§ 19 para. 2 StromNEV) — a discount for high-load time consumers that has been debated for decades — will be extended for existing customers until December 31, 2031 will be extended. The future design of industrial network charges is to be decided in early 2027 in order to incorporate findings from pilot projects running until the end of 2026. Atypical network usage will also remain in place for large consumers on a transitional basis.
For industrial companies that are still through high discounts Belt load or the atypical network use benefiting, means that: The transition period is secured, but now it's time to prepare for 2031.
The BEE assesses this extension as „major setback” and „Lifesaving measure for a relic of the last century”. The criticism is understandable: In a system that increasingly relies on flexibility, clinging to a uniform load privilege sends the wrong signal.
Our assessment of the AgNes interim report
The interim report from the Federal Network Agency is clearer than expected on many points—and it confirms the direction we outlined in ours. The new basic model with a booking capacity and a two-part variable price is coming. The exemption for existing storage facilities remains. The feed-in tariff is coming, more moderate than initially feared.
But the underestimated lever is passing on costs. It changes the basis on which all network charges are calculated. Industrial customers connected to a medium-voltage grid in an area with strong renewable energy generation will feel the effects in the price sheets, regardless of the specific details of the basic model. The relief of the transmission grid level is the flip side of the increased burden on the distribution grid levels.
The formal consultation on the full decision proposal is expected to begin Summer 2026. The AgNes framework decision is to be adopted by the end of 2026. Implementation preparations will begin in 2027, along with concrete price list changes.
FAQ on the AgNes Interim Report
When does the new capacity price for industrial customers take effect?
The new capacity price for large consumers (> 100,000 kWh/year) applies from January 1, 2029. The framework will be decided by the end of 2026, with concrete price lists from the grid operators to follow from 2027/2028.
What replaces the current performance price?
The capacity charge (€/kW, based on the measured annual peak load) is determined by a Capacity price for a pre-ordered service replaced. Quantities within the order are charged at AP1, quantities above that at AP2 (minimum 200 %, maximum 350 % at AP1).
Why can grid fees in medium-voltage grids increase despite feed-in from renewable energy sources in one's own grid?
Because the new cost allocation no longer looks at the physical residual load compared to the upstream level, but at the entire Electricity consumer in the own and all downstream grids. Local renewable energy feed-in no longer reduces this cycling rate.
Do industrial customers with their own BESS or generation facility now have to pay grid feed-in tariffs?
Yes. For PV systems > 30 kW installed gross capacity — provided no FID exists before the AgNes decision comes into effect (earliest January 1, 2027). For existing systems, a 20-year grandfathering period applies from initial commissioning. For BESS, trust protection and FID apply until August 4, 2029.
Does the retention privilege remain in effect?
For existing customers until December 31, 2031. The new regulation for the period after that will be decided in early 2027.