AgNes Electricity Reform 2026 — What PV Investors Need to Do Now
Excerpt
With AgNes, the Federal Network Agency is overhauling the entire electricity transmission tariff system—starting in 2029, PV feed-in operators will also be required to contribute to grid costs for the first time. What this means in practice, which deadlines are critical for investors, and why battery storage is now becoming a key regulatory component.
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Starting in 2029, the Federal Network Agency will replace the entire electricity grid tariff system with the new AgNes procedure. The grid tariff reform affects PV investors in Germany on three levels: For the first time, feed-in providers will be required to pay grid tariffs; the exemption for battery storage systems is under serious review; and dynamic grid tariffs will become a key factor in investment returns within the energy transition. Added to this are regulations already in effect: As of February 25, 2025, feed-in tariffs will no longer apply when exchange prices are negative for systems with smart metering—a clear signal that self-consumption and storage are structurally favored over pure grid feed-in. Those who invest and integrate storage by the end of 2028 secure regulatory grandfathering—those who wait will be investing under a fundamentally different cost framework. Companies planning their own PV system for their operations can find the right starting point under “Your Own PV System for Your Business.”
Table of Contents
What is the AgNes process—and why is it the biggest reform of grid fees in 20 years?
Dynamic Grid Tariffs for Solar PV and Battery Storage: How Flexibility Drives Returns
The 2026 Grid Package: What the Bill Means for PV Connections
Grid Tariff Reform for PV Investors: Three Scenarios Depending on the Timing of the Investment
1. What is the AgNes procedure—and why is it the biggest reform of grid fees in 20 years?
AgNes — the General Electricity Grid Tariff System — is the Federal Network Agency’s tariff-setting procedure that fully replaces the previous Electricity Grid Tariff Ordinance (StromNEV). The StromNEV expires on December 31, 2028. Starting January 1, 2029, a new system will take effect, which, for the first time, will also require feed-in operators to contribute to grid costs.
This development stems from a European Court of Justice ruling dated September 2, 2021 (C-718/18), which found that the previous regulation by government ordinance was contrary to EU law. The 2023 amendment to the Energy Industry Act (EnWG) subsequently transferred comprehensive regulatory powers to the Federal Network Agency (BNetzA)—the federal government lost its regulatory authority under Section 24 of the EnWG. Since then, the agency has been working on the successor framework under file number GBK-25-01-1#3 and redefining the regulatory framework for the entire German energy system.
The grid tariff reform affects all grid users—from residential customers and prosumers to commercial PV investors. The new framework is particularly relevant to the energy transition because it is designed to create incentives for grid-friendly behavior and to finance the massive expansion of the German power grid over the coming decades. The new system, which takes effect in 2029, will directly impact the economic viability of photovoltaic investments—through new grid connection costs, a revised exemption framework for battery storage, and price incentives for grid-friendly operation.
You can learn more about the AgNes reform here.
The General Electricity Transmission Tariff System — Specific Changes Starting in 2029
On May 12, 2025, the BNetzA officially launched a discussion paper on the general electricity transmission tariff system. Since then, developments have unfolded at a rapid pace:
| Date and time | Milestone |
|---|---|
| May 12, 2025 | Publication of a Discussion Paper on the General Electricity Transmission Tariff System |
| December 2025 | Workshops on grid tariff components and low voltage |
| January 2026 | Workshop on Dynamization and Storage Network Fees |
| February 2026 | Guidelines on Feed-in Tariffs and Construction Cost Subsidies |
| March 2026 | Comment period has expired — unanimous rejection by BDEW, VKU, BEE, BDI, and bne |
| Mid-2026 ⟶ | First draft decision with formal consultation (planned) |
| End of 2026 ⟶ | Final draft (planned) |
| January 1, 2029 | New grid fee structure takes effect — StromNEV expires |
December 2025: Workshops on grid tariff components and low voltage
January 2026: Workshop on Dynamization and Storage Network Fees
February 2026: Guidelines for Feed-in Tariffs and Construction Cost Subsidies
March 2026: Comment period on feed-in tariffs has ended — Result: unanimous rejection by all major associations (BDEW, VKU, BEE, BDI, bne)
Mid-2026 (planned): First draft text with formal consultation
Late 2026 (planned): Final draft
The timeline is considered ambitious within the industry. Several legal experts warn of potential delays in implementing the new regulatory framework. One thing is certain: Starting January 1, 2029, new rules will apply to the use of the power grid—and investors who begin operations by that date will be covered under the old system.
⚠️ All information regarding ongoing procedures is current as of April 2026. The AgNes procedure has not yet been finalized. Details are subject to change. As of April 2026.
2. Grid Fees in 2026: Short-Term Relief, Long-Term Increase
Grid fees will drop significantly in 2026—solely due to a one-time federal subsidy of €6.5 billion. Without this subsidy, transmission grid fees would return to 2025 levels or rise above them. Structural cost pressures remain and will lead to rising grid fees in the long term.
Current figures for 2026
| Key figure | Value 2026 |
|---|---|
| Average grid fee for households (3,500–4,000 kWh/year) | ~9.3 ct/kWh (net) |
| Decrease compared to 2025 | −15% to −18% (one-time federal subsidy) |
| All-time high in 2024 | 11.62 cents per kWh — just under 30% of the electricity price |
| Federal Transmission Grid Tariff (Transmission Grid) 2026 | ~2.86 ct/kWh (a 57% reduction due to the subsidy) |
| Share of grid fees in the household electricity price in 2026 | ~24.8% (at an average of 37.2 cents per kWh) |
| Source: BDEW Electricity Price Analysis, January 2026 | |
Average grid fee for households (3,500–4,000 kWh/year): ~9.3 cents/kWh net (BDEW Electricity Price Analysis, January 2026)
Decrease compared to 2025: approx. −15% to −18% — Costs are falling, but only temporarily
All-time high in 2024: 11.62 ct/kWh — Grid fees accounted for nearly 30% of the household electricity price at that time
Federal Transmission Grid Tariff (2026): ~2.86 ct/kWh — 57% decrease due to federal subsidy
Share of grid fees in the household electricity price in 2026: ~24.8% (at an average of 37.2 cents/kWh) — temporarily reduced due to a federal subsidy, but set to rise again in the long term
⚠️ The figure of ~24.8% applies to 2026 and takes into account the one-time federal subsidy of €6.5 billion. Without this subsidy, the figure would return to approximately 30%. As of April 2026.
Renewable energy is driving the need for grid expansion
According to a study by the IMK at the University of Mannheim (December 2024) , the investment required for Germany’s electricity grids through 2045 amounts to €651–732 billion. Of this total, approximately €328 billion is allocated to the transmission grid and €323 billion to distribution grids. The massive grid expansion is a direct consequence of the growth in solar installations, wind power, and battery storage—Germany’s energy transition is placing structurally new demands on the power grid. Compared to other European markets, Germany’s expansion needs are particularly high because renewable energy generation is heavily concentrated in certain regions. Annual investments must more than double from approximately €15 billion (2023) to around €34 billion. The financing of this grid expansion will be passed on to all grid users through rising grid fees.
The federal government has approved the subsidy only for 2026—whether it will be extended beyond 2026 remains to be seen. For PV investors, this means that self-consumption, which offsets the cost of grid electricity, will become structurally more valuable—regardless of short-term fluctuations in grid fees.
⚠️ Grid fees vary significantly by region (Bavaria: ~7.8 ct/kWh; Baden-Württemberg: ~9.8 ct/kWh; Berlin: ~8.6 ct/kWh). All figures are based on BDEW data from January 2026 and are subject to change during the year. As of April 2026.
3. Feed-in tariffs: For the first time, solar power systems will be required to pay for feeding electricity into the grid
With AgNes, the BNetzA plans to introduce construction cost subsidies (BKZ) for feed-in operators for the first time—a one-time payment upon grid connection, based on the connected capacity. For a typical 10-kWp rooftop system, additional costs of approximately €1,000 are expected. In addition, the BNetzA is discussing dynamic feed-in grid fees that reflect the strain on the grid caused by PV feed-in and are intended to provide incentives for behavior that better serves the grid.
What the BNetzA specifically proposes
In February 2026, the BNetzA issued guidelines on two instruments:
1. Construction Cost Subsidies for Grid Feeders (BKZ-E) Currently, only consumers pay a one-time BKZ fee when connecting to the grid. The Federal Network Agency (BNetzA) intends to extend this to grid feeders. For solar installations and other grid feeders, this is intended to partially cover the actual costs of new grid connections:
One-time payment upon commissioning
Regionally differentiated — Locations in grid areas with bottlenecks pay more
BDEW calls for a de minimis threshold starting at 30 kW (excluding small-scale facilities)
For a typical 10-kWp system: estimated additional cost ~€1,000
A well-designed BKZ system must take into account the differences between output-dependent technologies (PV, wind—feed-in cannot be controlled) and output-independent technologies (CHP, biogas—feed-in can be planned), as their impact on grid congestion varies significantly. The BNetzA considers this an important distinction for the final design.
At the same time, the Federal Network Agency (BNetzA) is discussing the introduction of base rates for prosumers—a fixed annual fee intended to cover grid maintenance costs regardless of actual consumption. This regulation is also being opposed by industry associations.
2. Dynamic feed-in tariffs: Time-varying tariffs for grid feed-in, depending on actual grid utilization. During peak hours (when the grid is already at capacity), feeding into the grid should cost more—a direct incentive for storage rather than direct production into the grid. This component of the reform is intended to create flexibility in the energy system and reduce redispatch costs.
Background: Solar Peak Act effective February 25, 2025. Regardless of AgNes, new feed-in regulations are already in effect: As of February 25, 2025 (Federal Law Gazette 2025 I No. 51), new installations with an intelligent metering system (iMSys) will no longer receive a feed-in tariff if electricity exchange prices are negative (Section 51 EEG). In addition, new PV systems without smart meters and control boxes must limit their feed-in to 60% of installed capacity (Section 9(2) EEG). Both regulations strengthen the economic incentive to store electricity on-site rather than feed it into the grid.
The industry is unanimously opposed to this
The comment period ended on March 27, 2026. The result is clear: All major associations—BDEW, VKU, BEE, BDI, and bne—reject the proposed regulations in their current form. The main points of criticism regarding the new fees for feed-in operators:
BNE warns against perverse incentives (undersizing facilities to avoid costs) — a concrete example: Operators could intentionally design facilities to be smaller in order to fall below the de minimis threshold
The BDEW describes the base rates specific to prosumers as "discriminatory and not cost-reflective"
BEE considers the approach to be contrary to European law
A significant revision of the guidelines is considered likely. The final draft is not expected until mid-2026.
What this means for PV investors
The reform will moderately increase investment costs for new PV systems—one-time connection fees will be introduced, while ongoing annual fees are unlikely under current plans. For large-scale commercial systems (>100 kWp), higher connection fees are more realistic than for rooftop systems. Ongoing feed-in grid fees (annual charges) have become unlikely in the form originally proposed. For investment decisions, this means: The new framework conditions moderately increase one-time costs but, for the time being, have little impact on the ongoing return on investment.
At the same time, the conditions for pure grid injection are gradually deteriorating: The feed-in tariff is suspended when market prices are negative (effective February 25, 2025, for systems with iMSys), and potential feed-in fees starting in 2029 would further reduce profitability for full grid injection. Higher grid costs for feed-in thus make investments in battery storage structurally more attractive—the electricity is used on-site instead of being fed into the grid.
⚠️ The BNetzA guidelines on feed-in tariffs are not a final document. All cost figures cited are estimates based on the state of discussions as of April 2026. As of April 2026.
4. Storage Grid Fee Exemption under Section 118 of the Energy Industry Act: Grandfathering or Risk?
Battery storage systems connected to the grid by August 4, 2029, are formally exempt from grid fees for purchased electricity for 20 years under Section 118(6) of the Energy Industry Act (EnWG). However, the Federal Network Agency (BNetzA) is fundamentally questioning this full exemption—including the possibility of retroactive termination for systems already in operation.
The current legal status
The exemption remains in effect. An amendment to the Energy Industry Act (EnWG) passed in November 2025 has even expanded its scope to include other storage concepts:
Changing "if" to "provided that" allows for a proportional exemption for multi-use storage facilities
Vehicle-to-Grid charging points will be treated equally
The deadline remains: August 4, 2029, for commissioning
The BNetzA's Position in the Determination Proceedings
In its guidance on grid access fees dated January 16, 2026, the authority stated unequivocally:
The total exemption is not tenable under European law
Storage systems incur grid costs and must be integrated into the general tariff system
The Federal Network Agency is considering "retroactive application" — an early termination that would also apply to existing installations
Since the 2021 ECJ ruling, the authority no longer recognizes the principle of legitimate expectations
The Federal Network Agency (BNetzA) has announced that it will issue initial guidelines for storage network fees by the end of May 2026. The model to be implemented starting in 2029, which will affect both network operators and market participants, is taking shape:
Energy rate applies only to net quantities (storage losses)
Capacity price (€/kW) as a base fee
Dynamic pricing as an incentive for grid-friendly behavior
| Compensation component | Description | Economic frontier |
|---|---|---|
| Electricity rate | Only on the net amount (storage losses) — not on the full charging current | Depending on the final sentence |
| Capacity price | Fixed annual amount per kW of connected capacity as a grid maintenance fee | max. 6–10 €/kW (BVES/ECO STOR) |
| Dynamic fees | Variable component based on grid utilization — Incentive for grid-friendly charging and discharging | +30% value added vs. static (Neon/Consentec) |
What Investors Need to Know Now
The BVES (Federal Association of Energy Storage Systems) and the large-scale storage operator ECO STOR estimate that the economic viability is limited to a maximum capacity price of €6–10 per kW. Beyond that, projects would become uneconomical. The FfE (Research Center for Energy Economics) and the Foundation for Environmental Energy Law state that full exemption “is on thin ice.”
The risk of a retroactive change is real—but industry-wide opposition and legal hurdles make a complete repeal unlikely for existing installations. Anyone who commissions a storage facility before August 4, 2029, will at least secure the exemption currently in effect until a final decision is made.
For investors looking to combine solar power with battery storage, this timeline is an important consideration—learn more in our overview of solar-battery storage systems and their revenue potential.
⚠️ The exemption from grid fees under Section 118(6) of the Energy Industry Act (EnWG) is currently the subject of active regulatory discussion. This article reflects the situation as of April 2026. Changes—including retroactive ones—cannot be ruled out. Please check the current legal situation or consult a legal advisor. As of April 2026.
5. Dynamic Grid Tariffs for Solar Power and Battery Storage: How Flexibility Drives Returns
Dynamic grid tariffs are prices that vary by time and location based on the current load on the power grid—they apply to both consumers and, increasingly, to those feeding electricity into the grid. Those who use the grid during peak hours pay more; those who feed electricity into the grid or consume it during off-peak hours pay less or receive credits.
As of April 1, 2025, all distribution system operators must offer time-of-use grid tariffs (Section 14a of the Energy Industry Act, Module 3). For PV investors with battery storage, this means that those who consume electricity when grid demand is low will pay significantly lower grid tariffs. The combination of PV, storage, and dynamic grid tariffs can save several hundred euros per year.
How Module 3 under Section 14a of the Energy Industry Act works
Starting in April 2025, a three-tier grid fee model will apply to taxable consumer devices (heat pumps, electric vehicles, storage systems) with a capacity of 4.2 kW or more:
| Rate tier | When does it apply? | Impact on PV + Storage |
|---|---|---|
| Standard rate | Normal operation | As before |
| Peak-hour rate | The network is heavily loaded | Discharge storage systems instead of charging them — feeding power into the grid pays off |
| Off-peak rate | The grid has spare capacity | Charge affordably — maximize savings |
Standard rate: Same as before
Peak-hour rate: More expensive — when the grid is under heavy load
Off-peak rate: Cheaper—when the grid has spare capacity
This requires a smart meter and a controllable consumption device. Potential savings from Module 1 (flat rate for controllability): a reduction of €110–190 per year in grid fees.
Real-world figures
| Scenario | Potential savings |
|---|---|
| Module 1 — Flat rate for controllability (4.2 kW and above) | $110–$190 per year |
| Module 3 — Household SH, 4,500 kWh of controllable consumption | up to €421 per year |
| Combination of dynamic electricity rates and dynamic grid fees | Up to 68% savings compared to a fixed price |
| Sources: Grid operator calculations; 1KOMMA5°/Destatis study 2025 | |
A family in Schleswig-Holstein with 4,500 kWh of controllable consumption: up to €421/year in grid fee savings with Module 3
Combination of dynamic electricity rates and dynamic grid fees: up to 68% savings compared to fixed rates (1KOMMA5°/Destatis study)
A study by the universities of Bamberg, Würzburg, Zurich, and Chemnitz (448 households, 5 years of data) shows a clear financial benefit from battery storage combined with dynamic rates
Beyond mere cost savings, battery storage systems contribute to grid stability: through targeted charging and discharging cycles, they help smooth out power peaks and avoid the need for redispatch. Modern inverters can also provide reactive power, thereby actively contributing to frequency stabilization—a foundation for new business models such as the marketing of system services (instantaneous reserve, control power).
The AgNes AP3 Work Award, starting in 2029
As part of the reform, a more comprehensive dynamic energy price (AP3) is to be introduced—differentiated by time and location, depending on the actual congestion situation in the grid. Specifically, the BNetzA plans to allocate the costs of congestion management proportionally among feed-in providers: Those who feed into the grid during hours of high grid load will pay a higher active power price—those who feed in during off-peak hours will pay less or nothing at all. This market mechanism is a key instrument of the energy transition: It is intended to create incentives for grid-friendly behavior rather than distributing costs on a flat-rate basis. A study by Neon/Consentec shows that a congestion-based dynamic active power price can reduce redispatch costs five times more effectively than alternative models. The economic value added by a storage facility increases by around 30% due to dynamic active power prices .
For investors, this means that PV systems with battery storage that can be operated in a grid-friendly manner starting in 2029 will benefit directly from lower grid fees during off-peak hours—and, conversely, from revenue generated by feeding electricity into the grid during peak hours. Flexibility in grid operation thus becomes a measurable factor in return on investment, not just a technical feature.
The article on battery storage and solar power arbitrage as an investment strategy provides a detailed explanation of how these potential returns translate into actual returns.
⚠️ Potential savings are based on model calculations and studies (as of 2025/2026) and do not guarantee individual results. The AgNes AP3 working price has not yet been determined. As of April 2026.
6. The 2026 Grid Package: What the Bill Means for PV Connections
A draft bill from the Federal Ministry for Economic Affairs and Energy (BMWE) that was leaked in February 2026—the so-called “Grid Package”—includes not only the BKZ authorization but also a controversial redispatch clause that would exclude new facilities in certain grid areas from compensation payments for up to 10 years. The draft primarily affects solar and wind power plants in regions with grids that are already congested.
What's included in the network package
BKZ for Feed-in Providers: Legal Authorization for the Federal Network Agency to Introduce Construction Cost Subsidies for Generators — Applies to All Feed-in Facilities, Not Just PV
Redispatch provision: In grid areas with more than 3% curtailment, grid operators may designate areas as "capacity-limited" — new plants would then receive no compensation for curtailment for up to 10 years, unlike under the current system
Change in Feed-in and Connection Priority for Renewable Energy in Areas with Grid Congestion
The industry's reaction
BSW-Solar referred to a "de facto ban on connections" for solar power systems in grid areas suffering from congestion. The draft bill was sharply criticized by the SPD parliamentary group, BEE, BSW, parts of the business community, and even RWE. A significant revision is considered likely—the draft has not yet been adopted.
What Investors Should Be Looking Into Now
Anyone investing in solar power systems or planning to install their own system should check the grid capacity at the planned location well in advance. Areas with a high share of renewable energy and existing curtailment situations could be subject to redispatch restrictions if the final legislation is enacted. Logic Energy assesses grid connection conditions as part of the project planning process—please feel free to contact us for more information.
A more comprehensive overview of the grid connection issue—particularly the KraftNAV reform for large-scale plants—is provided in the article “KraftNAV and Photovoltaics: What the Grid Connection Reform Means.”
⚠️ The Network Package is a draft bill (as of February 2026) and has not yet entered into force. All information is based on the draft version currently under discussion. As of April 2026.
7. Grid Tariff Reform for PV Investors: Three Scenarios Depending on the Timing of the Investment
For PV investors, the AgNes timeline results in three different regulatory scenarios—depending on when a plant begins operations. Commissioning before the end of 2028 offers the greatest planning certainty, while entering the market after 2029 offers the least.
| Criterion | Scenario 1 : Commissioning by the end of 2028 |
Scenario 2 : Commissioning in 2027–2028 |
Scenario 3 : Commissioning starting in 2029 |
|---|---|---|---|
| Grid Tariff Regulations | StromNEV (known) | StromNEV + Key Points Announced | AgNes in full |
| Exemption from storage requirements § 118 | ✔ Saved | ✔ Secured (before Aug. 2029) | ⚠ unclear / reduced |
| Current feed-in tariffs | ✔ None | ⚠ BKZ available as a one-time option | ⚠ Possible |
| Dynamic grid fees | Module 3 is available | Module 3 is available | Module 3 + AgNes AP3 |
| Planning certainty | High | Medium | Low |
Scenario 1: Commissioning by the end of 2028 — maximum grandfathering
Applicable StromNEV rules for the payback period
Exemption from grid fees for battery storage systems under Section 118(6) of the Energy Industry Act (formally guaranteed through 2029)
No ongoing feed-in tariffs under the old regulations
A one-time BKZ-E is possible, but based on the current state of discussions, it would be subject to de minimis thresholds
Scenario 2: Commissioning in 2027–2028 according to the policy paper
The AgNes draft is expected in mid-to-late 2026: greater planning certainty regarding post-2029 costs
BKZ likely to be introduced for feed-in providers (one-time)
The rules regarding storage exemptions are still unclear, but commissioning before August 2029 ensures a legal entitlement
Dynamic grid fees (Module 3) are now available
Scenario 3: Commissioning starting in 2029 — new regulatory framework
Fully covered under the AgNes framework: new grid fee structure, potential feed-in grid fees
Storage exemption may be limited to dynamic fee models rather than a full exemption
Dynamization fully implemented: greater potential for flexibility, but also greater cost exposure
No planning certainty without knowing the final specifications
Conclusion: When it comes to the grid tariff reform for PV investors, the rule is: those who act early secure better conditions. The regulatory advantage of an early investment is measurable. At the same time, system costs continue to fall—in the commercial segment, the LCOE for ground-mounted systems was already below 4 ct/kWh in 2026 (Fraunhofer ISE). The combination of falling project costs, clear incentives through dynamic grid tariffs, and regulatory grandfathering makes the case for investment decisions in the next 12–24 months. Those who launch projects now secure the most favorable conditions—both in terms of costs and grid tariff regulations.
The grid fee reform and its impact on investment timing were also outlined in the previous article—this article takes a closer look at the specific AgNes developments in 2026.
⚠️ These three scenarios are based on the state of discussions as of April 2026. Regulatory changes could significantly alter the cost-benefit ratio of each scenario. This is not investment advice. As of April 2026.
Conclusion: The AgNes Reform and the Grid Fee Reform — A Basis for Planning, Not a Halt to Investment
The grid tariff reform for PV investors marks the most significant regulatory change in Germany’s electricity grid in decades. For investors and businesses in Germany, the message is nuanced: In the short term, grid tariffs will drop noticeably in 2026. In the medium term, costs will rise structurally—and those who invest by the end of 2028 will secure planning certainty under the old regulations.
The three trends investors should keep an eye on:
Feed-in tariffs: One-time BKZ fees are on the way — ongoing annual fees are unlikely under current circumstances
Storage Exemption: Formally, Section 118 of the Energy Industry Act (EnWG) remains in effect until 2029—but the regulatory risk remains real; investments made before August 2029 protect the entitlement
Dynamic grid tariffs: Those who integrate battery storage and operate it in a way that benefits the grid will benefit—and even more so starting in 2029 thanks to AgNes AP3 and its incentives for flexibility
About PV Investments → Would you like to understand how regulatory changes will specifically affect your return on investment? About PV Investments →
Disclaimer: This article is intended solely for general informational purposes and does not constitute investment, tax, or legal advice. Return figures are based on historical data from the Helm Group and are not a guarantee of future results. Information regarding laws and procedures is current as of April 2026—ongoing proceedings (AgNes, Netzpaket) are subject to change at any time. For advice tailored to your individual situation, please consult a licensed advisor. All information is provided without warranty. As of April 2026.
The grid tariff reform is reshaping the cost structure of PV projects—but it does not undermine the investment logic. Self-consumption remains five times more valuable than feeding electricity into the grid, the production costs for photovoltaic electricity continue to fall, and battery storage is becoming a mandatory component under regulatory requirements rather than an optional add-on. Logic Energy systematically analyzes the grid connection situation, AgNes cost trends, and location risks for every project—and calculates how various regulatory scenarios will impact your return on investment. Contact us—free of charge and with no obligation.
FAQ
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AgNes stands for “General Electricity Grid Tariff System” — a regulatory process established by the Federal Network Agency (BNetzA) (Ref. GBK-25-01-1#3) that will fully replace the current Electricity Grid Tariff Ordinance (StromNEV) as of January 1, 2029. For the first time, feed-in operators will also be required to contribute to grid costs. The first draft determination is scheduled for mid-2026, and the new system will take effect in 2029.
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As of April 2026, the full implementation of ongoing feed-in tariffs is unlikely—all major associations have rejected the BNetzA’s proposals. One-time construction cost subsidies for grid connections to systems of approximately 30 kW or more are more likely. For a 10-kWp system, a one-time subsidy of approximately €1,000 is expected. Ongoing feed-in fees remain a subject of regulatory debate.
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Yes — formally, Section 118(6) of the Energy Industry Act (EnWG) remains in effect: Storage facilities that become operational by August 4, 2029, are exempt from grid fees for the energy to be stored for a period of 20 years. However, the Federal Network Agency (BNetzA) is fundamentally challenging this full exemption in the AgNes proceedings and is examining the possibility of retroactive application. A final decision is not expected until the end of 2026 at the earliest.
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Dynamic grid tariffs vary depending on grid load: they are expensive during peak hours and inexpensive during off-peak hours. They are a key instrument of the energy transition because they create incentives for grid-friendly behavior and strengthen the market for flexibility services. Starting in April 2025, all grid operators must offer Module 3 in accordance with Section 14a of the Energy Industry Act (EnWG). For PV investors with storage: Those who store energy cheaply and feed it into the grid or consume it when prices are high can save up to €421 per year.
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The Grid Package is a draft bill from the Federal Ministry for Economic Affairs and Energy (as of February 2026; not yet adopted). It includes a redispatch clause: In grid areas with more than 3% curtailment, new grid connections for installations may be excluded from compensation payments for up to 10 years. BSW-Solar described this as a de facto ban on new connections in areas experiencing grid congestion. The draft is considered in need of revision.
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The decline in 2026 is attributable solely to a one-time federal subsidy of €6.5 billion. Structurally, grid costs are rising: The investment requirement for Germany’s electricity grids through 2045 is €651–732 billion, and annual investments must more than double from approximately €15 billion to approximately €34 billion. Without a continuation of the federal subsidy beyond 2026, grid fees would rise significantly in the medium term.
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Yes—with important caveats. The return on direct PV investments in the commercial sector remains at 6–10% per annum (Helm Group, 2024 portfolio data). The LCOE for ground-mounted systems is below 4 ct/kWh (Fraunhofer ISE 2026). On-site consumption replaces grid electricity at 37+ ct/kWh. Regulatory uncertainty calls for careful site and storage planning—but does not argue against PV as an asset class.
References
Federal Network Agency — AgNes Procedure: Discussion Paper, Workshops, Guidelines — File No. GBK-25-01-1#3, May 2025 et seq.
Federal Network Agency — Key Points Paper on Successor Regulations for ARegV, StromNEV, and GasNEV — 2025
pv magazine — Federal Network Agency Opens Discussion on Grid Fees — May 12, 2025
pv magazine — Federal Network Agency examines "retroactive effect" regarding the early termination of the grid fee exemption for battery storage systems — January 30, 2026
pv magazine — Federal Network Agency Presents Guidelines for Dynamic Feed-in Tariffs and Construction Cost Subsidies — February 17, 2026
pv magazine — Draft grid package challenges priority for renewable energy connections and feed-in — February 9, 2026
pv magazine — Between the Market and the Grid: The AgNes Reform as a Test for Storage Expansion — March 16, 2026
BDEW — BDEW Statement on the Discussion Paper on the General Grid Tariff System (AgNes) — 2025/2026
BDEW — BNetzA's capacity price is a step in the right direction — 2026
BDEW — BDEW Electricity Price Analysis January 2026 — Grid Fees for 2026 and Electricity Price Breakdown
DVhub — AgNes Reform: Industry United in Opposition to the Federal Network Agency’s Feed-in Tariffs — 2026
Rödl & Partner — New Electricity Transmission Tariff System (AgNes) – Status as of the End of 2025 — December 2025
Energy and Law — New Grid Tariff System Starting in 2029 – Federal Network Agency Launches Consultation Process on "AgNes" — 2025
Hans Böckler Foundation / IMK — Over 650 billion euros by 2045: Study estimates investment needs for German power grids — December 2024
Federal Government — Lower grid fees for 2026 — Federal subsidy of €6.5 billion
Solarserver — Grid fees in 2026 will lower electricity costs, with regional variations — October 31, 2025
FfE — New Grid Fee Exemptions for Storage Systems and Charging Points — Are the Exemptions on Shaky Ground? — 2026
Renewable Energy Magazine — Storage Grid Fees on the Brink of Change: What the BNetzA Plans Really Mean — 2026
Gallehr & Partner — Restructuring of the Grid Tariff System — AgNes Process at the Federal Network Agency — 2026
Fraunhofer ISE — Levelized Cost of Electricity for Renewable Energies — LCOE Data for Photovoltaics, July 2024
Helm Group — Portfolio Return Data for 2024 — Internal Project Data, 6–10% p.a.
