EEG Feed-in Tariffs for 2026: What feed-in tariffs will apply starting in August—and what changes will the EEG 2027 bring?
As of August 1, 2026, the 2026 EEG feed-in tariff stands at 7.70 ct/kWh (partial feed-in) and 12.22 ct/kWh (full feed-in) for rooftop systems up to 10 kWp—legally guaranteed for 20 years from the date of commissioning. At the same time, on July 29, 2026, the Federal Cabinet approved the government’s draft of the EEG 2027: The fixed feed-in tariff is to be eliminated for new systems.
The short answer
Starting August 1, 2026, a feed-in tariff of 7.70 ct/kWh (partial feed-in) or 12.22 ct/kWh (full feed-in) will apply to rooftop systems up to 10 kWp, guaranteed for 20 years. The next reduction of approximately 1% will take effect on February 1, 2027.
Anyone who begins operations by December 31, 2026, will secure the proven subsidy system with a one-sided market premium—without the repayment obligation associated with two-sided contracts for difference (CfDs) that the EEG 2027, adopted by the Cabinet on July 29, 2026, imposes on new installations.
The 2026 EEG feed-in tariff is the final component of a subsidy system that will undergo fundamental changes in 2027. This guide explains all current feed-in tariff rates set by the Federal Network Agency, the historical development of feed-in tariffs since 2000, the difference between full and partial feed-in, the applicable value, and the consequences of the 2027 EEG reform for investors and companies.
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1. What is the EEG feed-in tariff—and how does it work?
The Renewable Energy Sources Act (EEG) was enacted in 2000 as the world’s first law of its kind. The basic principle has not changed since then: Anyone in Germany who operates a photovoltaic system and feeds solar power into the public grid receives a fixed amount in cents for each kilowatt-hour—for exactly 20 years from the date the system is commissioned.
The feed-in tariff is set once when the solar power system is built and remains in effect for the entire term. Subsequent changes in the law, falling market prices, or shifts in political policy do not affect it. In over 25 years of EEG history, Germany has never retroactively reduced feed-in tariffs for existing systems. It is precisely this protection of existing rights that will become the decisive factor in 2026.
The two ways to receive EEG compensation
In practice, there are two technically distinct ways to receive EEG subsidies. The fixed feed-in tariff (Section 21 EEG): The grid operator pays a fixed amount in cents per kWh directly for the PV electricity fed into the grid—without reference to market prices. This option is available for systems up to 100 kWp. The market premium model / direct marketing (§ 20 EEG): The system markets its electricity on the spot market through a direct marketer. If the market price falls below the applicable reference price, the grid operator pays the difference as a sliding market premium. This option is mandatory for systems of 100 kWp or more.
Both approaches guarantee the same minimum economic return. Direct marketing structurally yields about 0.4 cents per kilowatt-hour more—the difference between the applicable value and the fixed feed-in tariff—and significantly more during periods of high prices. Our article on the direct marketing of PV electricity in 2026 provides a detailed analysis.
Which photovoltaic systems are eligible for EEG feed-in tariffs?
In principle, all operators of PV systems with a capacity of up to 1,000 kWp are eligible, provided that the system is located in Germany, is registered in the Federal Network Agency’s Market Master Data Register, and meets the technical requirements under Section 9 of the EEG. Registration is a prerequisite for eligibility for feed-in tariffs. For installed capacities of 1,000 kWp or more, the tendering requirement applies.
2. Current Feed-in Tariffs for 2026: An Overview of All Rates
What will the feed-in tariff be in 2026, in ct/kWh?
The Federal Network Agency publishes the current feed-in rates in ct/kWh every six months. The date of commissioning is always the determining factor—not the date the project was commissioned or the date the building permit was issued. The specific rates for each power class are shown in the following lists and the summary table.
Building-Integrated PV Systems (Roof and Facade PV) – Partial Feed-in
With partial feed-in—also known as surplus feed-in—only the solar power that remains after self-consumption is fed into the grid. For most rooftop systems with self-consumption, this is the more economical choice:
- Up to 10 kWp: 7.70 ct/kWh (base rate: 8.10 ct/kWh)
- 10 to 40 kWp: 6.66 ct/kWh (base rate: 7.06 ct/kWh)
- 40 to 100 kWp: 5.44 ct/kWh (reference value: 5.84 ct/kWh)
Building Systems – Full Feed-in
In full-feed-in mode, the system feeds all of the electricity it generates into the grid. The rate per kilowatt-hour is higher, and there is no self-consumption:
- Up to 10 kWp: 12.22 ct/kWh (base rate: 12.62 ct/kWh)
- 10 to 40 kWp: 10.24 ct/kWh (reference value: 10.64 ct/kWh)
- 40 to 100 kWp: 10.24 ct/kWh (base rate: 10.64 ct/kWh)
Tenant electricity surcharge and other facilities
- Tenant electricity surcharge up to 10 kWp: 2.51 ct/kWh
- Tenant electricity surcharge for 10 to 40 kWp: 2.33 ct/kWh
- Tenant Electricity Surcharge for 40 to 1,000 kWp: 1.57 ct/kWh
- Other PV systems, including ground-mounted systems up to 100 kWp (Section 48(1) of the EEG): 6.19 ct/kWh (base rate: 6.59 ct/kWh)
| Performance class | Partial injection | Full feed-in | Value to be invested (per share) |
|---|---|---|---|
| up to 10 kWp | 7.70 ct/kWh | 12.22 ct/kWh | 8.10 ct/kWh |
| 10–40 kWp | 6.66 cents per kWh | 10.24 ct/kWh | 7.06 ct/kWh |
| 40–100 kWp | 5.44 ct/kWh | 10.24 ct/kWh | 5.84 ct/kWh |
| Other/Open Space up to 100 kWp | 6.19 ct/kWh | 6.19 ct/kWh | 6.59 ct/kWh |
| Tenant-Generated Electricity Up to 10 kWp | +2.51 ct/kWh surcharge | – | – |
| Tenant-generated electricity 10–40 kWp | +2.33 ct/kWh surcharge | – | – |
| Tenant-Generated Electricity 40–1,000 kWp | +1.57 ct/kWh surcharge | – | – |
| Applies to systems commissioned between August 1, 2026, and January 31, 2027. The surcharge of +1.5 ct/kWh (Solar Package I) for systems of 40 kW or more is not included—according to the Federal Network Agency, approval under EU state aid law is still pending. Source: Federal Network Agency, as of August 2026. | |||
Decrease: The new rates effective August 2026
Since February 2024, the EEG feed-in tariff has been decreasing by approximately 1 percent every six months (Section 49 EEG 2023). The next reduction took effect on August 1, 2026; the following reduction will take effect on February 1, 2027. The trend in the partial feed-in tariff for systems up to 10 kWp:
| Period | ≤ 10 kWp partial feed-in | 10–40 kWp partial feed-in | ≤ 10 kWp full feed-in |
|---|---|---|---|
| Feb–Jul 2025 | 7.94 cents per kWh | 6.82 cents per kWh | 12.60 cents per kWh |
| Aug 2025–Jan 2026 | 7.86 cents per kWh | 6.73 cents per kWh | 12.47 cents per kWh |
| Feb–Jul 2026 | 7.78 cents per kWh | 6.73 cents per kWh | 12.34 cents per kWh |
| Aug 2026–Jan 2027 (current) | 7.70 ct/kWh | 6.66 cents per kWh | 12.22 ct/kWh |
| Decrease: approximately 1% every six months (Section 49 of the EEG 2023). The August 2026 figures are the official rates published by the Federal Network Agency. Next reduction: February 1, 2027. Source: Federal Network Agency. | |||
Tender Requirement for Systems of 1,000 kWp or More – Maximum Values for 2026
Since the introduction of Solar Package I, the tender threshold for rooftop systems has been set at 1,000 kWp; for ground-mounted systems, the requirement also applies starting at 1 MWp. Electricity is then no longer paid for at a fixed rate but is sold through auctions. The following thresholds apply for 2026:
- Ground-mounted systems (Segment 1), maximum rate for 2026: 5.90 ct/kWh (Section 37b(1) of the EEG). The most recent published round (bid deadline: March 1, 2026) resulted in a volume-weighted average award price of 4.94 ct/kWh (range: 3.99–5.10 ct/kWh) and was significantly oversubscribed. The results of the round held on July 1, 2026 (volume approximately 2.13 GW) had not yet been published at the time of writing.
- Roof-mounted systems over 1 MWp (Segment 2), maximum rate in 2026: 10.00 ct/kWh (2025: 10.40 ct/kWh).
3. Feed-in Tariff Table: Trends from 2000 to 2026
The Renewable Energy Act and Its Degression Mechanism
The Renewable Energy Act was not designed as a static subsidy program, but rather as a self-regulating mechanism: The more systems were installed and the lower production costs fell, the faster the feed-in tariff was supposed to decrease. The law aimed to gradually make photovoltaics competitive—without placing a permanent burden on the national budget.
| Year | Rate (ct/kWh) | EEG version / Event |
|---|---|---|
| 2000 | 50,62 | EEG Takes Effect – Uniform Rate for All Solar Power Systems |
| 2004 | 57,40 | EEG 2004 – All-Time High, Market Explodes |
| 2008 | 46,75 | The 5% reduction in effect since 2005 |
| July 2010 | 34,05 | PV Amendment – Emergency Cut of About −13% Due to Record Expansion |
| Apr 2012 | 19,50 | The Most Severe Cuts – Monthly Decrease + One-Time Reduction |
| 2014 | 12,88 | EEG 2014 – Direct Sales Requirement for Large PV Systems |
| 2017 | 12,30 | EEG 2017 – Tender System for PV Systems Over 750 kWp |
| 2020 | 9,87 | Accelerated phase-out due to rapid expansion |
| July 2022 | 6,24 | Record low for the feed-in tariff |
| Aug 2022 | 8.20 (T) / 13.00 (V) | EEG 2023 – First Feed-in Tariff Increase, Full Feed-in Introduced |
| Feb 2024 | 8.11 (T) / 12.87 (V) | The semi-annual 1% reduction begins |
| Feb 2025 | 7.94 (T) / 12.60 (V) | Solar Peak Act Takes Effect |
| Feb 2026 | 7.78 (T) / 12.34 (V) | The last half-year before the August degression |
| Aug 2026 | 7.70 (T) / 12.22 (V) | Currently in effect – the last full year before the 2027 EEG system change |
| Reference: Rooftop systems up to 10 kWp, fixed feed-in tariff. (T) = partial feed-in, (V) = full feed-in. Sources: BNetzA Archive, BSW Solarwirtschaft, EEG|KWKG Clearing House, SFV. | ||
Historical trends reveal the most significant pattern: feed-in tariffs and investment costs for photovoltaic systems have fallen in tandem. Those who invest in 2026 will benefit from low system costs while still receiving guaranteed EEG subsidies for 20 years—before the current subsidy system is overhauled in 2027.
4. Full Feed-In vs. Partial Feed-In – Which Is More Cost-Effective and When?
Since August 2022, operators of rooftop systems have been able to choose between the two models. Full-feed-in operators generally receive higher feed-in tariffs—in 2026, the rate will be 12.22 ct/kWh, compared to 7.70 ct/kWh for systems up to 10 kWp. The decision should be made before construction begins. A change is possible annually (notification must be submitted by November 30 for the following year), but the feed-in tariff is fixed as of the commissioning date.
Calculation Example: 10 kWp rooftop system, 30 percent self-consumption
Assumptions: 10 kWp system, 9,500 kWh/year, 30 percent self-consumption (2,850 kWh), electricity purchase price of 35 cents per kWh.
Partial injection:
- Self-consumption: 2,850 kWh × 35 ct = €997.50 in electricity costs saved
- Feed-in: 6,650 kWh × 7.70 ct = 512.05 € in revenue
- Total: 1,509.55 €/year
Full feed-in:
- Feed-in: 9,500 kWh × 12.22 ct = €1,160.90 in revenue
- All electricity must be purchased from the grid
- Total: 1,160.90 €/year
Benefit of partial feed-in: approximately €349 more per year. This sample calculation is for illustrative purposes only and is based on hypothetical assumptions; actual results depend on location, system size, consumption profile, and the grid operator. This does not constitute advice regarding the system, tax matters, or legal issues.
When full feed-in makes sense
- Buildings with very low or no electricity consumption (warehouses, barns, vacant properties)
- As a separate secondary system in addition to an existing self-consumption system (Section 100(14) of the EEG permits two separate systems within a 12-month period)
- If the self-consumption rate is below about 15–20 percent
For companies with high electricity needs, optimizing self-consumption is the strongest driver of returns—far ahead of feed-in tariffs. Self-generated electricity costs significantly less than the price of grid electricity. Our article on solar system returns in 2026 shows the realistic returns a commercial system can achieve. Our guide, “Photovoltaics for Industry,” provides an overview for businesses.
5. Target value, market premium, and direct marketing
How the sliding market premium works
The formula is: Market Premium = Base Value − Monthly Market Value for Solar. The Monthly Market Value for Solar is the generation-profile-weighted average spot market price for solar power for a given month, published by the four transmission system operators on netztransparenz.de. It fluctuates significantly: The annual solar market value for 2025 averaged 4.508 ct/kWh, with individual months ranging from well over 10 ct/kWh in winter to less than 2 ct/kWh during sunny spring months.
If the market value is below the applicable value, the grid operator pays the difference as a market premium. If it is above that value, the market premium drops to zero, but the operator retains all proceeds. The current EEG subsidy system is thus asymmetric: it guarantees a minimum but does not cap profits. It is precisely this asymmetry that will end with the transition to two-way difference contracts under the EEG 2027.
Direct Sales Requirement: Who Is Required to Do It, and Who Can?
- Solar Power Systems Over 100 kWp: Direct Sales Requirement (Section 21b in conjunction with Section 20 of the EEG 2023)
- Systems up to 100 kWp: free choice between a fixed feed-in tariff and voluntary direct sales
- Since Solar Package I: Systems under 25 kWp no longer require remote control capabilities for direct marketing
- You can switch between the models each month with advance notice
A proposal initially discussed to lower the direct sales requirement to 25 kWp has not yet been implemented in current law—the 100-kWp threshold remains in effect. However, the EEG 2027 is intended to extend the direct marketing requirement to all systems. Our article on the direct marketing of PV electricity in 2026 explains how direct marketing revenues are calculated.
6. Solar Peak Act: Zero compensation when electricity prices are negative
The Solar Peak Act (Federal Law Gazette 2025 I No. 51) has replaced the previous hourly buffer system. Specifically, the following applies: Prior to February 25, 2025, compensation was suspended only after three consecutive hours of negative prices, and only for systems of 400 kW or more. As of February 25, 2025, the EEG feed-in tariff for new systems of 2 kWp or more will drop to zero as early as the first negative quarter-hour. For systems between 2 and 100 kWp, the rule applies only after the installation of a smart metering system; until then, a feed-in limit of 60 percent of the installed capacity applies. Existing systems installed before February 25, 2025, will continue to be subject to the more lenient regulations (Section 100(46) of the EEG).
573 Hours of Negative Prices in 2025—and the Trend for 2026
The trend in negative day-ahead price hours shows a long-term upward trend, which, however, will not continue linearly in 2026:
- 2022: 69 hours
- 2023: 301 hours
- 2024: 457 hours
- 2025: 573 hours (a record, about 6.5 percent of all hours in the year)
- First half of 2026: approximately 291 hours—the frequency of negative hours decreased compared with the same period the previous year, while price depths increased (reaching an all-time low of approximately −499 €/MWh in day-ahead trading on May 1, 2026)
For investors, the risk of negative prices remains a serious concern—but it can be actively mitigated through battery storage and smart charging management: Storage prevents revenue losses and generates additional income through arbitrage. Our cluster article on the Solar Peak Act and Section 51a of the EEG for PV investors explains in detail how these provisions work.
7. EEG 2027 and Mandatory CfDs: What Will Change After the Investment Window Closes
Under the current market premium model, the government subsidizes the difference if the market price falls below the reference value—if the price rises, the operator profits without limit. This asymmetry ends with CfDs: If the market price is below the reference value (strike price), the operator receives the difference, as before. If it is above the reference value, the operator pays back the difference (excess profit clawback). The risk is shared between the government and the operator. EU Regulation 2024/1747 makes no exceptions for individual technologies—wind, solar, geothermal, and hydropower are all subject to the CfD requirement; only biomass is exempt.
Key Points for New Solar Power Systems (Cabinet Decision, July 29, 2026)
According to the draft bill that has been adopted—which may still be amended during the legislative process—the following provisions are included:
- Elimination of the fixed feed-in tariff for new installations; instead, a time-limited transitional payment at market value for small-scale installations
- Direct Sales Requirement for All New Facilities
- Bilateral difference contracts with excess profit clawback for larger new subsidized facilities
- Limiting the maximum feed-in power at the grid connection to 50 percent for small PV systems and 70 percent for ground-mounted systems
- Concessions from the cabinet meeting: The redispatch provision is limited to 6 years and applies only when curtailment exceeds 5 percent; curtailment without compensation is capped at a maximum of 20 percent; an evaluation is scheduled after 2 years
- It should no longer be possible to switch between a CfD and a PPA at a later date
Time is of the essence because the current EU state aid approval for the EEG expires on December 31, 2026; this approval is also a prerequisite for the new regulations to take effect. The draft is politically controversial, and the details have not yet been finalized. We analyze what the CfD requirement specifically means for investment planning in our article on the 2027 CfD requirement for PV investors.
What this means for existing facilities
Crucial for investors: The regulatory change applies to new installations. Installations commissioned by December 31, 2026, are eligible for the unilateral market premium under the EEG 2023 for the full 20 years—with no repayment obligation. Whether an excess profit levy could also apply to existing plants in the future has not been conclusively clarified in the ongoing proceedings; as things stand today, the proven grandfathering provision remains decisive. We reassess the regulatory status before every investment decision.
8. The 2026 Regulatory Investment Window
Factor 1 – 20 Years of EEG Subsidies with Grandfathering Provisions
Anyone who begins operations by December 31, 2026, will benefit from the EEG 2023 remuneration system—for 20 years, regardless of future legislative changes. This means: no CfD repayment risk, no elimination of the fixed feed-in tariff for your own system, and full participation in periods of high electricity prices. Electricity fed into the grid at high exchange prices generates additional revenue that does not have to be repaid.
Factor 2 – Low Investment Costs
The system costs for photovoltaics are low. The ranges provided in the Fraunhofer ISE study on levelized cost of electricity (July 2024, which remains the most recent edition) serve as a guide: large rooftop systems over 30 kWp (commercial/industrial) at around 900–1,600 €/kWp, and ground-mounted systems over 1 MWp at around 700–900 €/kWp. Module prices rose temporarily in early 2026; the increase has come to a halt since July 2026, and availability has improved.
Factor 3 – Increasing Risk of Negative Prices for New Investments Starting in 2027
Without grandfathering provisions, the following will apply starting in 2027: zero compensation for negative prices starting from the first quarter-hour, a requirement to market electricity directly, and a transition to two-sided differential contracts with a repayment obligation. Given the long-term increase in the number of hours with negative prices, an investor with a new installation starting in 2027 will face a structurally higher revenue risk than an investor with grandfathering status from 2026.
For Businesses: Self-Consumption Beats Feeding Electricity into the Grid
Companies planning to install their own photovoltaic system for their operations should note the following: The feed-in tariff is of secondary importance for self-consumption systems—what matters most is the value of the electricity generated on-site (35–40 cents per kWh of grid electricity saved). Since grid electricity prices are rising structurally, while feed-in tariffs and system costs are falling, the benefit of self-consumption continues to grow. Learn more on our page “Your Own PV System for Your Business.” A comprehensive analysis of the investment model—including expected returns, tax benefits, and a comparison with other asset classes—can be found under “Photovoltaic Investment 2026.”
Take Advantage in 2026: Secure 20 Years of Funding Without a Clawback
The window for 20 years of guaranteed EEG subsidies with no repayment obligation closes on December 31, 2026. Logic Energy designs and builds turnkey PV systems—with financing secured before construction begins, its own operations team, and a long-term profit-sharing arrangement. The contractual partner for direct investments is mediplan Helm e.K., with personal liability on the part of the owner.
9. Frequently Asked Questions About the 2026 EEG Feed-in Tariff
What is the current EEG feed-in tariff for 2026?
As of August 1, 2026, rooftop systems up to 10 kWp will receive 7.70 ct/kWh for partial feed-in and 12.22 ct/kWh for full feed-in. For systems between 10 and 40 kWp, the rates are 6.66 and 10.24 ct/kWh, respectively; for systems between 40 and 100 kWp, the rates are 5.44 and 10.24 ct/kWh, respectively. These rates are valid through January 31, 2027 (Source: Federal Network Agency, as of August 2026).
What is the difference between the applicable value and the feed-in tariff?
The applicable value is the EEG reference price. The fixed feed-in tariff is 0.4 ct/kWh lower than this; the sliding market premium makes up the difference to the monthly market value for solar power. For direct marketing, the applicable value therefore structurally yields about 0.4 ct/kWh more than the fixed tariff.
How long does the EEG feed-in tariff apply, and what happens after that?
The EEG feed-in tariff applies for 20 years from the date of commissioning, plus the year of commissioning. The rate is set on the date of commissioning and remains constant. After the term expires, the system can continue to operate—for example, through direct sales, a PPA, or increased self-consumption. There have never been any retroactive reductions for existing systems.
How will the EEG 2027 affect existing facilities?
The Federal Cabinet approved the draft EEG-2027 on July 29, 2026; it has not yet entered into force. The transition to two-sided differential contracts affects new installations. As things stand, installations commissioned by December 31, 2026, will retain their grandfathered status with a one-sided market premium for 20 years.
How does the Solar Peak Act affect EEG feed-in tariffs?
As of February 25, 2025, EEG feed-in tariffs for new installations of 2 kWp or more will no longer apply starting with the first negative quarter-hour on the electricity market. In 2025, this amounted to 573 hours. Section 51a of the EEG partially compensates for shortfalls after 20 years (factor of 0.5). Existing systems installed before February 25, 2025, are protected.
Can I switch between full feed-in and partial feed-in?
You can switch providers once a year; you must notify the grid operator by November 30 for the following year. The feed-in tariff itself remains fixed as of the date the system is commissioned. For systems with self-consumption, partial feed-in is usually more economical; full feed-in is only advisable if self-consumption is very low.
When will the feed-in tariff go down again?
The next reduction will take place on February 1, 2027, by approximately 1 percent (Section 49 of the EEG 2023). The Federal Network Agency publishes the new rates every six months. Furthermore, the EEG 2027 could fundamentally change the subsidy system for new installations; the Cabinet draft on this matter has been available since July 29, 2026.
Conclusion
The 2026 EEG feed-in tariff is not the end of PV profitability—it is the final building block of a system that will undergo fundamental changes in 2027. Anyone who understands the interplay between grandfathering provisions, CfD risk, the trend toward negative prices, and low system costs will realize that the window for 20 years of guaranteed feed-in tariffs without clawback closes on December 31, 2026. For business self-consumption projects, the grid electricity saved is the strongest lever anyway—for details, see our guides on Solar System Returns in 2026, Photovoltaic Investment in 2026, and the 2027 CfD Requirement for PV Investors.
Sources and Legal Basis
- Federal Network Agency – EEG Subsidies and Subsidy Rates (Feed-in Tariff, Market Premium, Tenant Electricity Surcharge, Period August 1, 2026–January 31, 2027), accessed August 4, 2026
- Federal Network Agency – Completed Tenders for Solar Power Plants, Segment 1 (Maximum and Awarded Values for 2025/2026)
- Laws on the Internet – EEG 2023 (including Sections 20, 21, 21b, 48, 48a, 49, 51, 51a, and 100)
- EUR-Lex – Regulation (EU) 2024/1747 amending the Electricity Market Regulation (CfD Requirement), June 26, 2024
- pv magazine Germany – “Cabinet Approves Drafts of the EEG 2027 and Grid Package,” July 29, 2026
- netztransparenz.de – Market Value Overview (Solar Market Value), Annual Market Value for 2025: 4.508 ct/kWh
- SMARD / Federal Network Agency – Market Data (Negative Day-Ahead Price Hours)
- Fraunhofer ISE – Levelized Cost of Electricity for Renewable Energy, July 2024 (latest edition)
- EEG|KWKG Clearing House – Change in Payment Rates for PV Electricity
- Helm Group – Portfolio Return Data for 2024 (internal project data, 6–10% per annum)
Edited by Logic Energy. Last updated: August 2026.
