AgNes Network Charges 2029: Capacity Price, Dynamization & Industry Models — Interim Report May 2026

AgNes stands for General Network Charges System Electricity. The Federal Network Agency (BNetzA) initiated the regulatory procedure on May 12, 2025, under reference number GBK-25-01-1#3. It is intended to replace the expiring Electricity Grid Fee Ordinance (StromNEV), which will cease to be in force on December 31, 2028.

We have summarized a detailed basic article on the AgNes reform here: Reform of Electricity Network Charges — Background and Overview

Why reform—and why now?

The still-valid grid fee system originates from a time when electricity mainly came from large coal, gas, and nuclear power plants. Industrial customers pay their demand charge based on their annual peak load: a single peak value — often only a few minutes a year — determines a large part of the grid costs. This system provides hardly any incentives for grid-friendly behavior.

At the same time, the grid is fundamentally changing: decentralized feed-in from Photovoltaics and wind, growing number of prosumers, Battery storage, heat pumps and e-mobility. Feed-back loops create new grid loads that the old tariff system does not reflect. The reform aims to change that.

Additional pressure is generated by a European Court of Justice ruling on the independence of the regulatory authority, which legally sealed the repeal of the StromNEV in 2028. There is no turning back – the new system is coming.

A basic model in the discussion: Capacity price & 2 energy prices

At the center of the current discussion is a model with three remuneration components that could replace the previous performance-based price. To this end, the Federal Network Agency published “orientation points” at the end of April 2026 for the upcoming expert exchange. These provide for the following system:

• Capacity Price (CP) The grid user selects their capacity in kW themselves. This freely chosen capacity forms the basis for grid financing.
• Working Price 1 (WP1) Standard rate for consumption within the self-selected capacity.
• Work price 2 (AP2): Increased rate upon exceeding elected capacity — with a direct incentive for compliance.

The crucial difference from the current system: capacity is no longer determined retrospectively from the annual peak load, but is proactively defined by the grid user themselves. This creates planning certainty and provides a direct incentive to specifically optimize one's own load profile.

Dynamic Incentive Component: Discounts for Flexibility

In addition to the basic model, the BNetzA is planning dynamic remuneration components that systematically reward grid-friendly behavior. Those who react to grid or market signals and adjust their load will pay less for grid access. The amount of the relief depends on three criteria:

• Extent of flexibility: Noticeable changes in load starting at approximately 3 % are detected—the greater the response, the greater the load reduction.
• Availability duration: Those who can offer flexibility permanently, reliably, and for a longer duration will benefit more than from sporadic and shorter participation.
• Reaction rate: Short-term activatable flexibility – as made possible by battery storage – is particularly highly valued.

Specifically planned are several time windows with three price levels (peak, normal, and off-peak tariffs), which will be set once a year and billed monthly or at least quarterly. This makes flexibility a measurable, plannable factor for return.

Special tariffs for industry and commerce: 2 models in pilot projects

In parallel to the general remuneration model, the BNetzA has been piloting two approaches for industrial customers since the beginning of 2026. The originally separate procedure for industrial network charges (BK4-24-027) was integrated into the AgNes process in July 2025 to ensure a consistent overall system.

• Model A — Spot Market-Oriented Flexibility: Performance prices are guided by market stress. High spot prices and system load create few, but intense high-price windows – multiple times daily, short-term. High savings potential, but high demands on forecasting systems and dispatch quality.

• Model B — Grid-Relevant Flexibility: Performance prices are based on actual grid load (peak load time windows, PLTW). Plannable, stable time windows with a more moderate surcharge. A more conservative approach - and the most plausible entry point from 2029.

An initial exchange between participating companies, BNetzA, BDI, and DIHK took place on February 19, 2026. The discounting is intended to be based on the percentage reductions in network charges from previous years, so that participation in the pilot does not create an unjustified competitive advantage.

The Two Battery Storage Scenarios in Detail

Based on the ongoing BNetzA consultations, CUBE CONCEPTS' technology department has derived two probable implementation variants for the new performance price windows. Both are based on the same fundamental model but differ in dynamics, price levels, and time structure. They illuminate the future savings potential of battery storage systems in classic behind-the-meter (BTM) operation. Should the previously planned high-price time windows come into effect from 2029 onwards, companies should significantly reduce their peak loads during these times. The central starting points for both scenarios are as follows:

Important noticeA reform is coming—but its exact form is not yet decided. The two scenarios are not certainties, but rather variations based on current consultations (as of February 2026). The first draft of the final decision will follow in mid-2026.

Simulation Results: What does that mean specifically?

A location simulation for a 1 MW/2 MWh battery storage system (investment: €520,000) shows the range of the business case under different regulatory frameworks. Here, it is possible to Peak load capping, Load shifting and Self-consumption optimization reduce the procurement costs as follows:

The decisive leverage is the cost-of-service price saving: it increases from a good €10,000 today to up to €250,000 in scenario A. The new system thus clearly shifts the value of a battery storage system towards grid charge optimization.

Controversial Topics: What the Energy Industry Rejects

These three points in the overall AgNes process of the BNetzA are particularly controversial in the energy sector:

• Feed-in tariffs The BNetzA intends to also involve feed-in providers (PV, wind) in grid costs in the future. In March 2026, all major associations — BDEW, VKU, BEE, BDI, and bne — unanimously rejected this approach in their statements.

• Mandatory construction cost contributions: The BNetzA is leaning towards an expansion and mandatory requirement for construction cost subsidies (BKZ). There is also considerable resistance to this.

• Complexity of dynamization: The BEE welcomes the principle of dynamic tariffs but urges that the technical requirements not be set too high and that transitional models with binding deadlines be anchored — so that the implementation pressure is maintained.

Schedule: Where does the procedure stand today?

Following the initiation of the procedure and the first publication of the discussion paper in May 2025, various kick-off workshops took place in the summer of 2025. The evaluation of these workshops stretched until December, when the first expert workshop on the “Basic Model of Grid Financing & Low Voltage” began. Around the same time in winter, the working group “Dynamic Grid Fees & Storage Fees” commenced internal discussions. At the conferences in February and March 2026 on the topic of “Feed-in Tariffs & Cost Allocation,” experts encountered significant resistance from all associations, meaning no results are to be expected in this area yet.

The “Industrial Network Charges” workshop and expert exchange presented here took place on April 30, 2026, and the first pilot projects have been running since February 2026. Participating companies and network operators have 6 or 12 months to test new individual network charge systems.

Next Milestones:

• Mid-2026 – First formal definitive draft with consultation (planned)
• End of 2026 - Final Decision - Committee of the States deliberation
• 2027–2028 – Implementation in marketing communication and technical systems
• January 2029 – Entry into force of the new grid fee system

Conclusion: Flexibility becomes a return driver

The AgNes procedure is taking concrete shape. With the capacity price model and the planned dynamic incentive components, a systematic approach is emerging that not only rewards flexibility but also requires it. The value of a battery storage system is clearly shifting towards grid fee optimization: while arbitrage revenues remain comparatively stable, savings from performance-based charges could rise to several times today's level from 2029 onwards.

For companies: A reform has been decided, the details will follow in mid-2026. At the end of May 2026, the BNetzA confirmed the model described here and a AgNes Interim Report published. A first draft of the regulation is expected soon. Those who now analyze which performance peaks they can cap in future high-price windows — and which investments are worthwhile for this — have a clear advantage. The pilot projects already show that the business case for battery storage is becoming significantly more attractive under the new framework conditions.

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