Grid Fees in 2026: What Does the AgNes Reform Mean for PV Investors?
On May 27, 2026, the Federal Network Agency presented the overall concept for the AgNes reform—the largest grid tariff reform in 20 years. Starting in 2029, generators will pay an annual capacity fee for the first time; legal protection for battery storage systems will remain in place; and dynamic grid fees will be phased in starting in 2030. This article explains what this means for PV investors and which deadlines are now critical.
The short answer
The AgNes reform (General Electricity Grid Tariff System) is the Federal Network Agency’s tariff-setting procedure that will replace the Electricity Grid Tariff Ordinance starting in 2029. Key points for PV investors: Starting in 2029, generation facilities will pay an annual capacity charge for the first time (initially expected to be 4 to 7 €/kW/year); the protection of legitimate expectations for battery storage systems under Section 118 of the Energy Economy Act (EnWG) will remain in place; and dynamic grid fees will be phased in starting in 2030.
The key milestone is the final investment decision before January 1, 2027, along with commissioning by August 2029.
Grid fees will decrease in the short term in 2026—but the AgNes reform will fundamentally reshape the cost structure of every photovoltaic investment in Germany starting in 2029. With its comprehensive concept dated May 27, 2026, the Federal Network Agency has, for the first time, outlined how grid fees are to function starting in 2029—and in doing so, deviates from its earlier announcements in several respects. The following article is intended for investors and companies that are planning, building, or operating photovoltaic systems, and explains the specific cost implications of the AgNes reform for generators and battery storage systems.
1. What is the AgNes reform—and what did the BNetzA propose on May 27, 2026?
AgNes stands for “General Electricity Grid Fee System.” With this regulatory framework, the Federal Network Agency is replacing the Electricity Grid Fee Ordinance (StromNEV). The StromNEV will expire on December 31, 2028; the new system will take effect in 2029. On May 27, 2026, the Grand Energy Decision-Making Chamber presented an overarching concept that consolidates the previous discussion and guidance papers.
This is not yet a final decision. The complete draft decision is scheduled to be published and formally submitted for public comment in the summer of 2026; the framework decision is planned for late 2026. According to the agency’s own statement, the framework decision will not take effect before January 1, 2027, and more detailed follow-up decisions are expected to follow in 2027.
The reform was triggered by a ruling of the European Court of Justice (September 2, 2021, C-718/18), which found that the previous regulation by government ordinance was contrary to EU law. Consequently, the legislature must repeal the provisions of the StromNEV, and the authority to set rates now lies with the Federal Network Agency as an independent regulatory authority. For the first time, not only consumers but also generators, storage facilities, and electrolysis plants will contribute to grid financing. This change is driven by the challenges of the energy transition: volatile feed-in, new consumers, and the expanding grid infrastructure are altering the requirements for a secure energy supply. The total cost amounts to approximately 37 billion euros per year, accounting for about 30 percent of a household’s electricity costs.
The focus is on distinguishing between charges that serve a financing function—covering grid costs—and charges that serve an incentive function—designed to steer grid-friendly behavior through dynamic prices that vary by time and location. BNetzA President Klaus Müller summarizes the new approach by stating that greater weight is being given to the protection of legitimate expectations than in previous proposals—a statement that is particularly significant for storage and generation projects.
1.1 Overview of the AgNes Schedule
| Date and time | Milestone |
|---|---|
| June 2–3, 2025 | Launch of the AgNes process with expert hearings and individual consultations |
| Jan.–Feb. 2026 | Guidelines on Dynamization, Storage, and Feed-in Fees |
| May 27, 2026 | Overall Concept (Background Paper) Presented — New Developments in Data Retention and Protection of Legitimate Expectations |
| Summer 2026 | First draft decision with formal consultation (planned) |
| By the end of 2026 | Adoption of the framework (planned); effective no earlier than January 1, 2027 |
| 2027 | Follow-up Provisions (Special Industrial Tariffs, Construction Cost Subsidies, Dynamic Grid Tariff Model) |
| January 1, 2029 | New Grid Fee System in Effect; StromNEV Expired as of December 31, 2028 |
| Source: Federal Network Agency, AgNes Draft Decision (GBK-25-01-1#3) dated August 6, 2026, operative provisions 2, 9, 17, and 20, as well as the press release and background paper dated May 27, 2026. The consultation runs through September 18, 2026; the decision is still scheduled for 2026. BVES and BDEW have called for revisions. This is a draft, not a final ruling. As of August 2026. | |
2. Grid Fees in 2026: Short-Term Relief, Structural Increase
Grid fees are the cost of accessing the electricity grids and account for about 30 percent of the electricity price. They appear on the electricity bill alongside taxes and levies such as the electricity tax, sales tax, and concession fee. The grid usage fees themselves are divided into transmission grid fees for interregional transmission, distribution grid fees for regional distribution, and metering point operation fees.
The fact that grid fees will decrease in 2026 is primarily due to a one-time federal subsidy of 6.5 billion euros for transmission grid costs, as approved by the federal government (law in effect since December 12, 2025). Without this subsidy, grid fees would remain at the previous year’s level or higher.
Structurally, the trend is upward: Grid expansion as part of the energy transition and rising congestion management costs are driving up costs; at the same time, incentive-based regulation is intended to curb them. Because approximately 860 electricity grid operators calculate their fees individually, electricity grid fees vary significantly by federal state—in regions with high levels of renewable energy expansion, such as Schleswig-Holstein, Mecklenburg-Western Pomerania, and Saxony-Anhalt, they have long been above the national average. The nationwide pass-through of additional renewable energy costs and the new allocation formula under the AgNes reform are intended to reduce these differences.
For PV investors, the logic is simple: self-consumption, which replaces expensive grid electricity, becomes more valuable regardless of short-term fluctuations—and the AgNes reform determines who will bear the grid costs starting in 2029. The subsidy has been approved only for 2026; whether it will be extended remains an open question politically.
3. Feed-in tariff: Starting in 2029, producers will pay a capacity charge
Contrary to expectations at the beginning of 2026, a recurring grid fee for generators is now being introduced. The guidelines from February 2026 focused primarily on one-time construction cost subsidies; a recurring annual fee was considered unlikely. Now the situation has reversed: The annual capacity price will serve as the financing component, while the regulations governing construction cost subsidies and flexible grid connection agreements are to be developed separately starting in 2027.
It remains to be seen exactly beyond which performance threshold the capacity charge will apply. The Federal Network Agency does not specify a fixed de minimis threshold in its documents; it merely clarifies that plug-in solar devices are not covered and that prosumers will only be charged the higher base rate. For commercial and industrial systems, the scale remains manageable but is relevant for cost calculations.
| System size | Annual capacity fee | Classification |
|---|---|---|
| 100 kWp | €400–700 | typical commercial rooftop system |
| 500 kWp | €2,000–€3,500 | large rooftop/industrial facility |
| 1 MWp | €4,000–€7,000 | small solar farm |
| Illustrative calculation based on BNetzA benchmark figures (€4–7/kW/year). Plug-in solar systems and prosumers are excluded; the de minimis threshold and final amount per kW have not yet been determined. As of August 2026. | ||
Existing facilities are protected: Generation facilities that were commissioned before the AgNes framework took effect remain exempt from the new fee for 20 years from the date of initial commissioning. The Federal Network Agency grants this protection of legitimate expectations in close accordance with the legal interpretation of Section 118(6) of the Energy Industry Act (EnWG). Participants in tenders do not have to factor in the new capacity fees if their bids are submitted before the framework regulation takes effect—and this will not occur before January 1, 2027. In total, the capacity fee could contribute up to 2 billion euros per year to grid costs over the years, but according to the agency, it will have little impact on the market price.
At the same time, the conditions for pure feed-in are deteriorating anyway. Since February 25, 2025 (Solar Peak Act, Federal Law Gazette 2025 I No. 51), the feed-in tariff no longer applies to new installations with smart metering systems when exchange prices are negative (Section 51 EEG); In 2025, there were already approximately 573 hours with negative day-ahead prices. Higher grid costs for feed-in thus make on-site storage and self-consumption structurally more attractive. Our guide to EEG remuneration for 2026 provides an overview of the current feed-in rates and their trends.
4. Base price for prosumers and a new plan for large-scale consumers
On the consumption side, the system remains essentially the same for approximately 40 million residential customers: a base rate in euros per year plus a variable rate in cents per kilowatt-hour. A new feature is the introduction of binding, capped limits on the base rate. Prosumers—households that draw less electricity from the grid thanks to their own PV systems—will pay a higher base rate in the future. According to Rödl & Partner, this corresponds to a surcharge of 70 to 90 percent on the base rate; the absolute additional cost varies by location and is expected to remain below 100 euros per year on average. Plug-in solar devices are exempt.
The Federal Network Agency justifies this on the grounds of fairness: Those who generate their own electricity continue to rely on a constant supply from the grid and should therefore contribute somewhat more to its financing. For businesses with their own PV systems, however, self-consumption remains the key factor in determining value because it replaces expensive grid electricity.
For larger consumers with annual electricity consumption exceeding 100,000 kilowatt-hours, the current capacity price will be replaced by a capacity charge in euros per kilowatt per year. In addition, there will be an energy price for volumes within the contracted capacity and a surcharge once the contracted capacity is exceeded. The model is intended to encourage companies to contract capacity realistically and to allow for greater flexibility in electricity procurement. For large industrial consumers, the framework initially applies only transitional provisions: The band load regulation under Section 19(2) of the StromNEV will be extended for existing customers until December 31, 2031, and the discount structure for atypical grid usage will remain in place on a transitional basis for users with an annual consumption of 10 gigawatt-hours or more. A follow-up regulation in early 2027 will determine the final rules for the industrial sector.
5. Storage Grid Fees and Section 118 of the Energy Industry Act (EnWG): Protection of Legitimate Expectations Is Being Tightened
The Federal Network Agency has abandoned the retroactive repeal of the storage exemption that was under consideration at the beginning of the year. Battery storage systems for which a final investment decision was made before January 1, 2027, and which are commissioned by August 2029, will retain their 20-year exemption from grid fees. The exact cutoff date is not uniformly specified: According to the deadline calculation under Sections 187(2) and 188(2) of the German Civil Code (BGB), the deadline expires at the end of August 3, 2029, while documents from the Federal Network Agency cite August 4, 2029. There is no judicial clarification on this matter—those planning down to the exact day should use the earlier date. The new sticking point is the definition of this investment decision.
At the beginning of 2026, the agency had still been considering “pseudo-retroactivity”—that is, applying the new system to storage facilities that were already planned or under construction. This sparked massive opposition because investments worth billions had been calculated based on the existing exemption. In its comprehensive concept dated May 27, 2026, the Federal Network Agency explicitly ruled out introducing the fees for all storage facilities as early as January 1, 2029. The collection of fees will not begin until the special provisions of Section 118(6) of the Energy Industry Act (EnWG) have expired.
| Constellation | Protection of legitimate expectations |
|---|---|
| Commissioning after August 4, 2011, within the statutory deadline | protected (20 years from the date of initial commissioning) |
| Final investment decision by January 1, 2027 + commissioning by August 2029, proof by March 31, 2027 | protected |
| Residential Energy Storage in the Low-Voltage System | No separate grid fee |
| New Storage Facility Without a Final Investment Decision in Time | Capacity price similar to that for generators (approx. 4–7 €/kW/year) |
| Source: BNetzA Comprehensive Concept, May 27, 2026; legal analysis by, among others, CMS and Rödl & Partner (June 2026). As of August 2026. | |
Where the principle of protection of legitimate expectations applies, nothing will change for existing installations. Where it does not apply, grid-connected storage systems will in the future—like generators—pay a moderate capacity fee in the range of 4 to 7 euros per kilowatt per year, without any activity-based charges. Quantities drawn from and fed back into the grid remain exempt from active-power charges. Low-voltage home storage systems will continue to be exempt from separate grid fees.
The point of contention lies in the details: What counts as a final investment decision? According to the Federal Network Agency, a decision is considered to have been made when binding orders for components totaling at least half of the investment volume have been placed, and these contracts cannot be rescinded without significant financial loss. The cut-off date is decisive: The decision must be made before the determination is announced —the draft specifies January 1, 2027, as the date of announcement. Anyone invoking this provision must provide proof of this to the responsible grid operator by March 31, 2027 (Tenor, Section 17.5, Sentence 3). Thus, the draft is more restrictive than the law: Section 118(6), sentence 1 of the Energy Industry Act (EnWG) is based solely on the date of commissioning. Anyone who makes a decision after January 1, 2027, is required to pay grid fees starting January 1, 2029—even if the statutory commissioning deadline were met. For investors combining PV and storage, this timeline is crucial; the overview classifies revenue sources and returns under “PV with Battery Storage and Co-Location,” while the grid-oriented controllability is addressed in the section on § 14a EnWG for battery storage investors.
6. Dynamic grid fees: phased introduction starting in 2030
Dynamic grid fees are coming—but later and in phases. According to the overall plan, they are to be introduced for electricity storage systems no earlier than 2030, and ideally by 2033; for feed-in providers, no earlier than 2032, and ideally by 2035 (exception: offshore wind energy). The agency plans to develop a concrete plan in 2027 and assess its effects. The phased introduction gives investors more lead time than initially anticipated.
The goal of dynamic tariffs is to reduce the need for redispatch. By 2025, the costs for redispatch and other congestion management measures by transmission system operators had already reached approximately 3.06 billion euros, including the costs of maintaining reserve power plants. In the future, those who feed power into the grid or consume it when the grid is not under strain will pay less; those who place a load on the grid during peak hours will pay more. For battery storage systems, this represents an additional revenue opportunity rather than a pure cost burden.
Regardless of AgNes, a time-variable model already applies to controllable consumption devices: As of April 1, 2025, all distribution system operators must offer time-variable grid fees in accordance with Section 14a of the Energy Industry Act (EnWG) (Module 3). The technical prerequisite is smart metering systems (smart meters)—without quarter-hourly metering, the time-variable signals do not function; for more on this, see the article on the 2026 smart meter mandate for PV. For PV systems with battery storage, this already means charging at low rates when the grid is free and discharging during peak load periods. The article on battery storage and dynamic electricity rates shows how such revenue potentials can be translated into a strategy.
7. The 2026 Grid Package: Cabinet Decision and Redispatch Provision
In addition to AgNes, a second initiative is relevant for PV investors: the “Grid Package” from the Federal Ministry for Economic Affairs and Energy. The Federal Cabinet approved the draft bill on July 29, 2026; deliberations in the Bundestag are scheduled to begin in September 2026, with the law set to take effect on January 1, 2027. A key provision for renewable energy is a redispatch clause that may temporarily exclude new plants in grid areas with high utilization rates from compensation.
Compared to the first draft bill from February 2026, the provision has been softened but not eliminated: The threshold is now set at 5 percent curtailment in the previous year instead of 3 percent; the period of validity is 6 years instead of 10; classification is technology-specific; and the waiver of compensation is capped at a maximum of 20 percent of annual output. The draft also provides for grid operators to independently prioritize grid connections with a rated output of 135 kilowatts or more and a departure from the pure first-come, first-served principle. Concerns remain under European law regarding the redispatch provision, as Article 13 of EU Regulation 2019/943 generally provides for compensation in the event of redispatch.
Anyone investing in solar power or planning a solar power system should assess the grid capacity at the site early on. The article on KraftNAV and the changes affecting the solar power market provides a more comprehensive overview of grid connection issues—especially for large-scale systems.
8. Three Scenarios Depending on the Timing of the Investment
| Criterion | through the end of 2028 | 2027–2028 | Starting in 2029 |
|---|---|---|---|
| Grid Tariff Regulations | StromNEV (known) | StromNEV + Key Figures Announced | AgNes in full |
| Protection of Confidential Information in Storage § 118 | secured | Guaranteed (only for FIDs issued before January 1, 2027 (IBN valid through August 2029)) | only with FID protection |
| Current Feed-in Capacity Price | none | none (protection of legitimate expectations) | 4–7 €/kW/year |
| Dynamic grid fees | § 14a Module 3 | § 14a Module 3 | § 14a + AgNes (effective 2030/2032) |
| Planning certainty | High | Medium | Low |
| Our own classification based on the AgNes Overall Concept dated May 27, 2026. FID = final investment decision, IBN = commissioning. As of August 2026. | |||
The key factor is the time window for the final investment decision. At the same time, system costs continue to fall—according to Fraunhofer ISE, the turnkey benchmark stands at around 1,015 euros per kilowatt-peak. The combination of falling project costs and regulatory grandfathering makes it advisable to make investment decisions within the next 12 to 24 months. Four steps can help achieve this: assess the site and any bottlenecks early on, make the final investment decision before January 1, 2027, ensure commissioning by August 2029, and design the battery storage system from the outset to provide grid services for dynamic remuneration.
How will the AgNes reform affect your returns?
Logic Energy analyzes the grid connection situation, AgNes cost trends, and site-specific risks for each project—and calculates how each scenario affects your return on investment. The contractual partner for direct investments is mediplan Helm e.K., with personal liability on the part of the owners.
9. Conclusion: What Needs to Be Done Specifically Now
The AgNes reform is the most significant change to grid fees in decades—but it does not put an end to the investment logic; rather, it reinforces it. First, starting in 2029, generators will face a rolling capacity charge of 4 to 7 euros per kilowatt per year, from which existing plants will be exempt for 20 years. Second, the storage exemption under Section 118 of the Energy Industry Act (EnWG) remains in place—making the final investment decision before January 1, 2027, and commissioning by August 2029 safeguards this entitlement. Third, dynamic grid fees will be phased in starting in 2030; those who operate battery storage systems in a way that benefits the grid will benefit from this.
Self-consumption remains significantly more valuable than simply feeding electricity into the grid; the production costs for solar power continue to fall; and battery storage is becoming a mandatory component under regulatory requirements. More in-depth analyses are provided in the articles on the 2025 amendment to the Energy Economy Act (EnWG) and its implications for PV investors, as well as on the 2026 EEG feed-in tariff.
Frequently Asked Questions About the AgNes Reform
What is the AgNes reform, and what did the BNetzA propose on May 27, 2026?
AgNes (General Electricity Transmission Tariff System) is the Federal Network Agency’s tariff-setting procedure that will replace the Electricity Transmission Tariff Ordinance starting in 2029. On May 27, 2026, the agency presented an overall concept. The complete draft framework will be subject to public consultation in the summer of 2026; the framework is scheduled to be finalized by the end of 2026 and will not take effect before January 1, 2027.
Will solar power systems have to pay grid fees for feeding electricity into the grid starting in 2029?
Yes. Under the overall plan, generation facilities will pay an annual capacity charge starting in 2029, initially expected to range from 4 to 7 euros per kilowatt per year, excluding the energy charge. Plug-in solar devices and prosumers are exempt. Existing facilities will remain exempt for 20 years from the date of initial commissioning. The exact capacity threshold has not yet been determined.
Does the grid fee exemption for battery storage systems still apply?
According to the draft regulation dated August 6, 2026, yes, but the scope is narrower than in the law: Storage systems for which a final investment decision was made before January 1, 2027, are protected; proof of this decision must be provided to the grid operator by March 31, 2027. Those who make a decision later will be required to pay grid fees starting in 2029. Low-voltage home storage systems will continue to be exempt from separate grid fees.
When will dynamic grid fees be introduced under AgNes?
Phased approach: Dynamic grid fees are to be introduced for electricity storage systems no earlier than 2030 (if possible, by 2033) and for feed-in providers no earlier than 2032 (if possible, by 2035), with the exception of offshore wind. The Federal Network Agency will develop a concrete plan in 2027. Regardless of this, the time-variable model under Section 14a of the Energy Economy Act (EnWG) already applies to controllable consumers.
What is the grid package, and what risks does it pose for PV investors?
The BMWE’s grid package was approved by the Cabinet on July 29, 2026; the Bundestag will begin deliberations in September 2026. It includes a scaled-back redispatch provision: a 5 percent curtailment threshold, a 6-year validity period, technology-specific provisions, and a waiver of compensation limited to a maximum of 20 percent of annual output. Affected sites should assess grid capacity early on.
What does the final investment decision mean for the protection of legitimate expectations?
The Federal Network Agency considers a final investment decision to have been made when binding component orders totaling at least half of the investment volume have been placed; withdrawal is possible only if it would result in significant financial loss. The exact details have not yet been finalized and will determine the scope of protection.
Is investing in solar power still worthwhile despite regulatory uncertainty?
The reform does not put an end to the investment logic; rather, it reinforces it. Self-consumption remains valuable, system costs are falling (approximately 1,015 euros per kilowatt-peak, according to Fraunhofer ISE), and grandfathering provisions can be planned for if a decision is made in a timely manner. Individual profitability depends on location, size, and timing.
Sources and Legal Basis
- Federal Network Agency — Current Considerations on the Reform of the Electricity Transmission Tariff System (AgNes), May 27, 2026 (GBK-25-01-1#3)
- Federal Network Agency — AgNes Background Paper (PDF), May 27, 2026
- § 118 EnWG — Exemption from Grid Fees for Storage Facilities (Paragraph 6)
- § 19 StromNEV — Special Charges (Peak Load, Atypical Grid Usage)
- § 14a EnWG — Grid-Oriented Control of Controllable Consumer Equipment
- CMS — Update on the AgNes Proceedings: Current Considerations by the BNetzA, May 29, 2026
- Rödl & Partner — Federal Network Agency Outlines Details of Grid Fee Reform AgNes, June 10, 2026
- pv magazine — Grid Package: Grid Connection, Redispatch 2.0, and Renewable Energy Projects, 2026
- BDEW — Electricity Price Analysis, January 2026
- Fraunhofer ISE — Study on Levelized Cost of Electricity for Renewable Energy Sources, July 2024
Edited by Logic Energy. Last updated: August 2026.
