Germany Solar Peak Act 2026: The EPC Guide to EEG Feed-In Tariff Changes

What Germany's Solar Feed-In Tariff Actually Looked Like Before This Law

For 25 years, the EEG gave German solar system owners something almost uniquely valuable in the global solar market: a government-backed, fixed payment for every kilowatt-hour they exported to the grid, locked in for 20 years from the date of commissioning. The rate degraded every six months, but whatever rate you locked in on registration day was yours for two decades. That certainty was the foundation of every solar investment case in Germany since 2000.

The logic worked well when solar was a minor contributor to the grid. It stopped working when solar became Germany's single largest electricity source on clear summer days. By 2024, Germany had over 90 GW of installed solar capacity. On peak days, that capacity generates more electricity than the grid can absorb. Wholesale electricity prices go negative: generators are paying the market to take their power. Under the old EEG, solar system owners still received their fixed feed-in tariff during those negative price periods, regardless of what the market was doing. The government was paying people for generating electricity that was actively destabilising the grid.

The Solarspitzengesetz ended that. It is a direct, targeted fix: stop paying the feed-in tariff when the market price is negative. The policy logic is rational. The financial consequences for EPCs who have not updated their proposals are not.

What the Solar Peak Act Actually Changed: The Three Rules

The Solarspitzengesetz amends three sections of German energy law simultaneously: Section 51 of the EEG (feed-in remuneration), the Metering Point Operation Act (MsbG), and the Energy Industry Act (EnWG). In practical terms for a solar EPC, it creates three distinct obligations.

Rule 1: Zero feed-in income during negative pricing intervals

For all PV systems above 2 kW commissioned since February 25, 2025, the EEG feed-in tariff is suspended during any 15-minute interval when the EPEX SPOT day-ahead price is negative. Zero. Not reduced. Not deferred. Zero. The sun is shining, the system is generating, the inverter is exporting, and the meter is recording nothing for those intervals. If the client's system exported for 457 hours during 2025 and those hours were largely negative-price hours, a portion of those exports earned nothing.

Rule 2: Permanent 60% export cap without a smart meter

For new systems above 2 kW, the feed-in capacity is permanently capped at 60% of the installed system's peak output unless a smart metering system (iMSys) is installed. A 10 kWp system without an iMSys can only export up to 6 kWp to the grid, regardless of what it generates. The remaining 40% of generation capacity either goes to self-consumption or is curtailed. This is not a temporary or transitional measure. It applies for the full operational life of the system.

Rule 3: Smart meter makes the difference

If an iMSys is installed, the picture changes materially. Lost feed-in hours during negative pricing periods are counted and added to the end of the 20-year support period. The total income over the system's supported life is largely preserved, just shifted later. The full 100% of generation capacity can be exported. And for existing system owners who voluntarily switch to the new framework, PV Magazine confirmed a feed-in tariff increase of €0.006 per kWh as an incentive for the voluntary switch.

The smart meter (iMSys) itself costs approximately €100 for installation and €30 per year in operational fees. For a 10 kWp system, that annual cost is negligible compared to the lost generation value from a permanent 40% export cap. For systems above 7 kWp, the grid operator is legally required to install an iMSys, meaning the 60% cap issue resolves itself automatically for larger installations. For systems between 2 and 7 kWp, the owner has the choice. How an EPC presents that choice determines whether the client makes the right decision.

What This Costs in Real Money

Enjoyelec's financial modelling illustrates the gap across three scenarios for a standard residential system in Germany.

In a standard PV system without any response to the Solar Peak Act, the annual feed-in tariff income drops from approximately €289 to €254, while the annual electricity bill rises correspondingly. The net change is a degradation in the total financial return of the installation relative to what pre-February 2025 models projected.

When battery storage is added but without a Home Energy Management System (HEMS), self-consumption improves and partially offsets the feed-in loss. The annual FiT decreases from approximately €210 to €188, and the electricity bill rises modestly. The outcome is better than the unshielded system but still suboptimal.

In the optimal scenario with PV, battery storage, HEMS, and dynamic tariff integration, the system is designed around maximising self-consumption and selling surplus only when prices are positive. Total annual costs reduce to approximately €205, and annual savings relative to a standard unoptimised PV system reach €372. Over 20 years, that compounds to a €7,447 difference between an optimised and an unoptimised installation on the same rooftop.

That €7,447 difference is not a technical detail. It is the commercial argument for designing German solar systems differently from 2025 onward, and it belongs in every EPC proposal.

The 60% Cap: Why It Is the Bigger Problem Than Negative Pricing

The negative pricing rule gets most of the attention because it is dramatic: feed-in income going to zero. But in practice, the financial impact of negative pricing hours, spread across an annual total of 457 hours, represents roughly 2 to 8 percent of annual feed-in income depending on the system and location. That is real money, but it is manageable.

The 60% export cap for systems without a smart meter is structurally more damaging because it is permanent and continuous, not episodic. A 10 kWp system that generates 10,000 kWh per year can only export 6,000 kWh at most, even on a clear day in July when demand is high and prices are positive. The other 40% of generation capacity either goes to self-consumption or is wasted. For a client who installed a 10 kWp system specifically because their household consumption during the day justified the size, losing 40% of export capacity could represent €200 to €400 per year in permanently foregone feed-in income.

The fix is simple: install an iMSys. The cost is approximately €100 upfront and €30 per year. For systems above 7 kWp, the grid operator installs it regardless. For systems between 2 and 7 kWp, the EPC must recommend it proactively. An EPC who commissions a 5 kWp system without raising the smart meter question, and whose client later discovers their system has been running at 60% export capacity for three years, has a complaint on their hands that is both expensive and entirely avoidable.

The one thing to do on every German proposal above 2 kWp: Include a line item for iMSys installation. Explain the binary choice. Without iMSys: 60% export cap, permanent. With iMSys: full export capacity, lost negative-price hours recovered at end of 20-year period. The cost difference is approximately €100 plus €30 per year. The income difference can be hundreds of euros per year for the client's entire operating life. This is not a upsell. It is a fiduciary obligation to the client.

How to Update Your German Solar Proposal for the New Reality

Three specific changes are required in every German solar proposal issued for systems commissioned after February 25, 2025.

1. Remove any financial model built before February 2025

Any 20-year financial projection that assumes full feed-in compensation for 100% of export hours is now incorrect. Update the model to reflect: (a) suspension of FiT during negative price periods, modelled as a conservative reduction of 3 to 5 percent of annual feed-in income; and (b) if no iMSys is proposed, the 60% export cap applied to all export calculations.

2. Present the smart meter choice explicitly

Every proposal for a system above 2 kWp should include two scenarios side by side: with iMSys (full export, lost hours recovered, additional annual cost €30) and without iMSys (60% export cap, no recovery of negative-price hours, no additional cost). Most clients choose iMSys when the numbers are presented clearly. The EPC who does not present the choice and defaults to the cheaper option is making a decision on the client's behalf that they have not been authorised to make.

3. Lead with self-consumption, not feed-in

The Solar Peak Act has made self-consumption economics the primary financial case for German solar. At 28 to 32 cents per kWh for imported electricity versus 7.86 cents per kWh for exported electricity, every kilowatt-hour consumed on site is worth four times more than one exported. Proposals that lead with feed-in tariff income as the headline return metric are underselling the actual financial case for the client. Lead with electricity bill reduction. Show the feed-in income as supplementary income. Design the system size around self-consumption first, export second.

Reslink's solar EPC software generates proposals and financial models that can be updated to reflect current EEG rates, iMSys scenarios, and self-consumption versus export splits in a single design workflow. For EPCs working across multiple German clients simultaneously, having a proposal template that automatically applies the correct post-Solar-Peak-Act financial logic removes the manual error risk that comes from updating dozens of individual spreadsheet models.

Frequently Asked Questions

Q1. What is Germany's Solar Peak Act (Solarspitzengesetz)?

The Solarspitzengesetz, effective February 25, 2025, is a German law that suspends EEG feed-in tariff payments for new PV systems above 2 kW during any 15-minute interval when electricity spot prices on the EPEX day-ahead market turn negative. It also permanently caps the export capacity of new systems at 60% of installed peak output unless a smart metering system (iMSys) is installed. The law amends Section 51 of the Renewable Energy Act (EEG), the Metering Point Operation Act (MsbG), and the Energy Industry Act (EnWG) simultaneously. It applies to all systems commissioned since end of February 2025 and does not retroactively affect systems commissioned before that date.

Q2. How many hours per year are affected by negative electricity pricing in Germany?

In 2024, Germany recorded 457 hours of negative electricity pricing, as per official figures cited by PV Tech. The majority of these hours coincided with peak solar generation periods, specifically midday on clear days, weekends, and public holidays when industrial demand is lower and solar output is highest. In May 2025 alone, 129 negative price hours were recorded in a single month as Germany's summer solar season began, per S&P Global Commodity Insights. The number of negative pricing hours is expected to grow as Germany's installed solar capacity continues to increase toward its 215 GW target by 2030. EPCs should use 400 to 500 hours per year as a conservative planning assumption when modelling feed-in income under the Solar Peak Act.

Q3. Is the 60% export cap permanent, or does it go away after a certain period?

The 60% export cap is permanent for the operating life of the system if no smart metering system (iMSys) is installed. It does not expire after a number of years, and it does not lift when smart meter penetration increases nationally. It is a condition attached to the specific system at the time of commissioning. The only way to remove the 60% cap from an already-commissioned system is to have an iMSys installed. For systems above 7 kWp, the grid operator is legally required to install an iMSys, so the cap does not apply to larger installations. For systems between 2 and 7 kWp, the installation of iMSys is the owner's choice. EPCs must present this clearly before commissioning, not after.

Q4. Does the Solar Peak Act apply to systems commissioned before February 2025?

No. The Solarspitzengesetz applies only to systems commissioned after February 25, 2025. Systems commissioned before that date continue to receive their locked-in EEG feed-in tariff for the full 20-year support period, including during negative price periods, under the rules that applied at the time of their commissioning. However, owners of pre-February 2025 systems can voluntarily switch to the new framework. As an incentive, voluntary switchers receive a feed-in tariff increase of €0.006 per kWh. This voluntary switch may be worth considering for existing system owners who have installed battery storage and HEMS, since optimising around self-consumption and positive-price export periods can outperform the guaranteed tariff even with the negative-price suspension applied.

Q5. What is an iMSys and what does it cost to install in Germany?

An iMSys (intelligentes Messsystem, or smart metering system) is a certified digital meter with a gateway that records energy flows in 15-minute intervals and communicates with the grid operator in real time. Under the Solar Peak Act, installing an iMSys on a new PV system above 2 kWp removes the 60% export cap and ensures that feed-in hours lost during negative price periods are counted and added to the end of the 20-year EEG support period. Installation costs approximately €100. The ongoing operational fee, charged by the metering point operator (Messstellenbetreiber), is approximately €30 per year. For systems above 7 kWp, the Messstellenbetreiber is legally required to install an iMSys regardless of whether the system owner requests it. For systems between 2 and 7 kWp, the owner requests installation and bears the annual fee.

Q6. How should a German solar EPC change their financial model and proposal for post-February 2025 systems?

Three specific changes are required. First, remove any pre-February 2025 20-year financial model that assumes full feed-in compensation for all export hours. Model feed-in income with a 3 to 5 percent reduction to account for negative-price periods, or use 400 to 500 zero-income hours per year as the planning assumption. Second, include the iMSys choice explicitly in the proposal: show the client the financial difference between a system with iMSys (full export, lost hours recovered, €30 per year) and without (60% export cap, no recovery). Third, lead the financial case with self-consumption savings at the full retail electricity price of 28 to 32 cents per kWh rather than with feed-in income at 7 to 8 cents per kWh. Self-consumption is currently four times more valuable than export in Germany. The proposal that correctly frames this will close more convincingly than one that still leads with feed-in tariff income as the headline return.

Sources

• PV Tech, February 17, 2025 - pv-tech.org - Germany passes Solarspitzengesetz; 457 negative pricing hours in 2024; 60% export cap without smart meter confirmed
• PV Magazine, February 17, 2025 - pv-magazine.com - Solarspitzengesetz details: 20-year period extension with iMSys, voluntary switch incentive of €0.006/kWh, effective date confirmed
• PV Magazine, August 4, 2025 - pv-magazine.com - Current EEG rates: €0.0786/kWh (partial feed-in up to 10 kW), €0.1247/kWh (full feed-in up to 10 kW), August 2025 degression
• S&P Global Commodity Insights, June 10, 2025 - spglobal.com - 129 negative pricing hours in May 2025; solar capture price below €20/MWh; negative hourly prices trigger EEG payment halts
• Enjoyelec, April 2, 2025 - enjoyelec.net - Financial modelling: three scenarios; €372 annual savings optimised vs unoptimised; €7,447 over 20 years
• PVPro Solar, October 2025 - pvprosolar.de - iMSys mandatory from 7 kWp; installation cost €100; annual operational fee €30; retail electricity 28 to 32 ct/kWh3E.eu - 3e.eu - Netzpaket and Solar Peak Act practical guide; avoided network tariffs phase-out; Bundesnetzagentur grid operator notification confirmed