WIND + SUN = POWER: Trends and Developments in the Electricity Sector

The recent quarters were characterized by strong expansion figures, profound regulatory adjustments, and an electricity market that is more dynamic than ever before, driven by new record values for negative prices, increasing flexibility needs, and growing competition in individual tenders.

The first part highlights the current development of renewable energies and battery storage, followed by a look at market prices and negative price hours. This is followed by a classification of the EEG tender results from the Federal Network Agency. Finally, an overview of current political developments is provided: from the EnWG amendment, the discussion on storage network fees and grid connection procedures, the industrial electricity price, and the planned power plant strategy. In short: this update shows how the market, regulation, and technology have shifted in recent months—and what this means for project developers, operators, investors, and marketers.¹

Development of RE Expansion / Battery Storage

Total domestic net electricity generation in 2025 amounted to 481 terawatt-hours (TWh) (2024: 471 TWh). Additionally, a net balance of 21 TWh was imported, around 5 TWh less than the previous year. Renewable energies (RE) accounted for 58.7% of total net electricity generation, remaining at the same percentage level as 2024, but recording an absolute increase of around 6 TWh. The RE share of public electricity generation (which, unlike total net electricity generation, does not include industrial and commercial self-generation and PV self-consumption) was 62% or 260.2 TWh (2024: 63% or 259.8 TWh), placing it at a comparable level to the previous year.²

Once again, wind energy was not only the most significant renewable energy source but also the most important energy source overall, with a share of 27.4% or 132 TWh of total net electricity generation. Due to weak wind conditions, particularly in the first half of 2025, electricity generation fell by approx. 4 TWh compared to 2024 (2024: 28.9% or 136 TWh). The records achieved by photovoltaics (PV) in monthly electricity generation are also reflected in the annual review: photovoltaics ranks second among renewable energy sources and key energy carriers, behind wind energy and ahead of gas and lignite. Photovoltaics accounted for 18.2% or 87.5 TWh of total net electricity generation (2024: 15.3% or 72 TWh); of which 17 TWh was self-consumption, representing an increase of 5 TWh compared to 2024.³

The installed PV capacity (DC) stood at 117.4 GW at the end of 2025, with a net expansion of 16.8 GW (2024: 17.4 GW). To reach the expansion target of 128 GW by the end of 2026, around 11 GW are still missing. At a comparable expansion rate, this target could be reached by the end of this year. Net expansion of wind energy amounted to 4.6 GW in 2025, significantly higher than the previous year’s figure of 2.6 GW. The installed net capacity reached 68.2 GW at the end of 2025; thus, about 16 GW remain to reach the interim target of 84 GW by the end of 2026.⁴

The battery storage systems recorded an expansion of 6.4 GWh or 4 GW (2024: 6.1 GWh or 4.3 GW). Thus, the total storage capacity at the end of 2025 amounted to 24.9 GWh with an installed capacity of 16.6 GW.³

In 2025, the share of renewable energies remained stable, while their absolute generation continued to rise. Photovoltaics grew particularly strongly, while wind energy faltered slightly due to weather conditions but is growing more strongly again in terms of expansion. Battery storage once again recorded a significant increase, strengthening system flexibility. It also remains to be seen how the Chinese tax benefits for PV exports, which will expire in April, will affect prices and supply chains and thus influence further PV expansion. For battery storage, a reduction in the tax export benefit from 9% to 6% applies initially before it is to be completely abolished from 2027.⁵

Developments in the Electricity Market

With 575 hours of negative prices, a new record was reached in 2025 (2024: 475). It is striking that, as in the previous year, most hours with negative prices occurred in the summer months—the period in which the most PV power is generated and fed into the public supply grid (see also Figure 1 below). While the annual solar market value in 2025 was 4.508 ct/kWh, further decreasing compared to the previous year (4.624 ct/kWh), the annual market value for onshore wind rose to 7.441 ct/kWh (2024: 6.293 ct/kWh). The average spot market price also increased (2025: 8.932 ct/kWh; 2024: 7.946 ct/kWh).⁶

Development of the average spot market price, market values, and the number of hours with negative prices (Source: own representation based on data from Netztransparenz.de⁷)

The occurrence of negative prices has an impact on the profitability, particularly of new PV and wind energy plants in subsidized direct marketing. The reason for this is that plant operators only receive a subsidy under the Renewable Energy Sources Act (EEG) for the amount of electricity fed in during times of non-negative prices. In the respective business case, the marketing volume should therefore also be taken into account—the amount of electricity that can be fed in during times of non-negative prices.

The PV marketing volume was 75% in 2025 and has thus fallen further (2024: 81%). In contrast, the onshore wind marketing volume was 90% (2024: 92%).⁸ The integration of storage or a “non-standard PV orientation” (e.g., vertical bifacial) can, for example, help to increase the marketing volume. Furthermore, direct marketing concepts in which the remuneration structure is based on the spot market rather than the market value can be economically advantageous when there is an increased number of hours with negative prices.

However, there are some indications that point toward a reduction in negative prices or an increase in the marketing volume (in the medium term). These include the Solar Peak Act introduced at the beginning of 2025 (no subsidies for new EEG plants when negative prices occur) and the increase in flexibilities (storage and demand-side flexibility).

Overview: Federal Network Agency Tenders for Receiving EEG Subsidies

Tenders for PV and Onshore Wind

The third and final EEG tender round for solar installations of the second segment (rooftop solar) on October 1, 2025, was slightly undersubscribed after the exclusion of inadmissible bids, similar to the tender in July. With a tendered volume of 282.7 MW, 121 bids with 280.8 MW were accepted. The average, volume-weighted award value was 9.66 ct/kWh, following the upward trend.⁹
The tender results of the third bidding date for solar installations of the first segment (ground-mounted solar) on December 1, 2025, are not yet available.¹⁰

On November 1, 2025, the fourth and final tender round for onshore wind turbines took place, which (as in the previous tenders) was heavily oversubscribed (8.16 GW bid volume submitted vs. 3.45 GW tendered volume). 415 out of 905 bids were accepted at an average volume-weighted award value of 6.06 ct/kWh, nearly 1 ct/kWh lower than at the beginning of the year. The majority of the projects are to be built in North Rhine-Westphalia and Lower Saxony.¹¹

The second date for the innovation tender 2025 took place on September 1 with nearly 486 MW of tendered capacity. 163 bids with a total bid volume of 2.18 GW were submitted, so the bidding round was heavily oversubscribed as before. The award went to 33 bids with 490 MW, which are plant combinations of PV and storage. The average, volume-weighted award value was 5.31 ct/kWh, significantly below the value of the last tender in May 2025 (6.15 ct/kWh).¹²

Table 1: Results of the latest 2025 EEG tender rounds of the Federal Network Agency (Source: Federal Network Agency¹³)

Summary: 2025 Tender Results

2025 was also an extremely dynamic tender year in the field of photovoltaics: in the first segment (ground-mounted solar), the year’s bidding dates were oversubscribed, so that the entire tendered volume could be successfully awarded.¹⁴ In the first date, the average, volume-weighted award value was 4.66 ct/kWh, continuing the downward trend of previous tenders. In the second tender, this value rose slightly (4.84 ct/kWh) and the highest awarded bid value was even 6.26 ct/kWh, the highest since mid-2023. It remains to be seen whether the decline in award values has been halted—the pending results of the December tender will provide more clarity here.¹⁵

In the second segment (rooftop solar), a different development emerged: in the tender rounds of June and October, the entire tendered volume was not awarded because the rounds were undersubscribed. In total, bids with approx. 781 MW received an award. The upward trend in award values also continued (average, volume-weighted award value: October 2024: 9.04 ct/kWh; October 2025: 9.66 ct/kWh.¹⁶ Due to the current high award values in the second segment, large PV rooftop systems can currently represent exceptionally good investment objects, although their “window of opportunity” is expected to close soon due to the upcoming EEG reform (see also the following explanations in the article). Further information can be found in the following article.

In 2025, over 14.4 GW of capacity was awarded in the onshore wind segment. Since all four tender rounds were significantly oversubscribed (with an increasing trend), the entire tendered auction volume was awarded by the Federal Network Agency (BNetzA). The strong competition in 2025 ensured that the average volume-weighted award value decreased with each subsequent tender and was 9% below the previous year’s value in an annual comparison. More than half of the awards in 2025 went to North Rhine-Westphalia (29%) and Lower Saxony (23%).¹⁷

In the innovation tender, the total awarded volume in 2025 was 977.4 MW, which slightly exceeds the volume tendered by the BNetzA. The significantly higher bid volume submitted illustrates the high level of competition in this segment, where the storage boom is also becoming apparent. This is also noticeable in the falling average, volume-weighted award values (annual comparison: 2024: 7.71 ct/kWh; 2025: 5.73 ct/kWh).¹⁸

New Maximum Values for 2026

In mid-December 2025, the BNetzA used its determination powers and announced the new maximum values for the 2026 tenders for onshore wind turbines and rooftop solar systems. Due to the strong competition in past tenders and the decrease in expected levelized costs of electricity, both maximum values were lowered: for tenders in the onshore wind sector to 7.25 ct/kWh (previously: 7.35 ct/kWh) and for the rooftop solar sector to 10.00 ct/kWh (previously: 10.40 ct/kWh). ¹⁹

No maximum values were set for solar installations of the first segment or innovation tenders, so the legal requirements apply here. Thus, the maximum value for ground-mounted solar systems is formed based on the last three tender rounds (maximum value depending on the results of the December tender). For the innovation tender, a new maximum value of 7.13 ct/kWh applies (previously: 9.00 ct/kWh).²⁰

Overview: Politics

EnWG Amendment November 2025

On November 13, 2025, the Bundestag adopted the federal government’s draft law to amend energy industry law to strengthen consumer protection in the energy sector (EnWG amendment).²¹

Several new regulations arise for the battery storage sector:

1. The new version of Section 118 (6) EnWG expands and specifies the network fee exemption for electricity storage: this only applies to those amounts of electricity that are fed back into the same network after intermediate storage. This means that battery storage systems can also benefit proportionally from the network fee exemption in the future if they only deliver part of the discharged electricity back to the grid. Via the reference to Section 21 EnFG in the same paragraph, this regulation applies accordingly also to bidirectionally used charging points of electric vehicles—but only if the electricity previously drawn from the grid is actually fed back into the grid later. In addition, further reporting obligations and requirements apply. Previously, owners of e-cars had to pay network fees twice—first when charging and then again when they had to recharge the battery after grid-serving feed-back.

2. With the Geothermal Acceleration Act, which came into force at the end of December 2025, the legislator also included explicit privileges for outlying areas in Section 35 (1) Nos. 11 and 12 BauGB. After initially looking like a very extensive outlying area privilege, the legislator has significantly backtracked with the recent regulations. The strict location restrictions are likely to lead to a race for available space, and in the end, few large-scale projects will benefit from the new outlying area privilege, while for most projects, feasibility is likely to continue to be considered only on the basis of corresponding urban development planning.

New developments also arise from the EnWG amendment of November 2025 regarding the explosive topic of customer installations:

3. With the regulation in Section 118 (7) EnWG the legislator is reacting to the considerable legal uncertainty surrounding customer installations following the decisions of the Court of Justice of the European Union (CJEU)²³ and the Federal Court of Justice (BGH).²⁴ In its decision, the CJEU found that the concept of customer installations regulated in the old version of the EnWG (Section 3 No. 24a EnWG old version) and the associated exception of the customer installation from the concept of the regulated distribution network contradicts European requirements. According to the case law of the CJEU, it is important for classification as a distribution network that a network serves the “transmission of electricity at high, medium, or low voltage intended for sale to wholesalers and end customers.”²⁵ Exceptions at the national level are only permissible if they are correspondingly provided for by the European Directive. According to the CJEU decision, the concept of the customer installation under Section 3 No. 24a EnWG old version does not meet these requirements.²⁶ The incompatibility of the national concept of the customer installation with the European Directives prompted the legislator to create the new Section 118 (7) EnWG. With this transitional regulation the regulatory requirements for energy supply networks will only apply to customer installations within the meaning of Section 3 Nos. 65 and 66 EnWG that were connected to an upstream network by December 23, 2025, starting from January 1, 2029. This transitional regulation is intended to “preserve the previous legal situation for existing installations for three years,” so that operators of existing installations are “not to be treated as network operators.”²⁷ However, the regulation provides no clarification of content. How customer installations are to be classified (regulatorily) in the future remains open. The central question of how to reconcile European law requirements with the previous national legal situation is bypassed by this approach of the legislator. What will apply in the future for existing and new installations is left open by the legislator. It is equally unclear to what extent the transitional regulation itself is to be assessed as compliant with the directive.²⁸ Further information can be found in our previous articles.

This immediately raises the question of how communal supply concepts can still be implemented in the future—and this is where the new Energy Sharing regulation comes in.

4. The new regulation on energy sharing came into force on June 1, 2026, and transposes EU requirements of Art. 15a of the amended Internal Electricity Market Directive (2024/1711 – Right to joint energy use) into German law (Section 42c EnWG). In the future, electricity from renewable energies or from an energy storage facility in which only energy from renewable energies is temporarily stored can be used collectively. The prerequisite for this is a supply contract between the plant operator and the supplied final consumers, which specifically regulates the scope of use, allocation key, and possible remuneration. However, classic supplier obligations such as residual electricity procurement or balancing group responsibility are waived—further supplier obligations (Sections 5 and 40 to 42 EnWG) are waived for households up to 30 kW or for multi-party buildings up to 100 kW.²⁹ Plant operators can be natural persons as well as partnerships with legal capacity or legal entities under private law whose all shareholders or members are final consumers or public institutions. Final consumers are natural persons as well as legal entities. The latter only if they are micro, small, or medium-sized enterprises (SMEs) and the plant operation does not predominantly serve a commercial or independent activity. The electricity may be taken by natural persons, SMEs, and public institutions. Distribution system operators are obliged to enable energy sharing technically—initially within their balancing area, and from June 2028 also across areas with adjacent networks. This requires smart meters and quarter-hourly measurement of generation and consumption. Reduced network fees are not yet provided for, and capacity limits are not explicitly defined in the law. It is to be expected that widespread use of energy sharing will initially fail to materialize. Reasons for this lie in the uneven smart meter rollout (national smart meter quota: 3.8%³⁰), lack of economic incentives such as the reduction of network fees (besides the possible electricity tax exemption for plants smaller than 2 MW and electricity consumption within a 4.5 km radius), new required processes, and better digitalization among network, metering point, and market actors.

Storage Network Fees & AgNes Process

In addition to the changes brought about by the EnWG amendment, another regulatory development is gaining importance that also affects operators and investors of large-scale battery storage: the planned realignment of the network fee system by the BNetzA.

In the publication of the orientation points on storage network fees dated January 16, 2026, the BNetzA sets out its current considerations for changing the previous network fee system for storage.³¹ With a view to the transitional regulation under Section 118 (6) sentence 1 EnWG—which provides for a privilege for storage with regard to network fees—the BNetzA refers to its deviation competence contained in Section 118 (6) sentence 12 EnWG and announces that it will “examine to what extent such protection of legitimate expectations exists, particularly in weighing it against the weighty economic arguments for equal treatment of all storage facilities put into operation..” The BNetzA also recognizes the need for planning security for project developers and investors.
In this regard, it states: “For the planning security of project developers and financiers of such projects, it is important to ensure clarity of a future fee system as early as possible and to provide for orderly transitional periods.” Against this background, it is advisable to closely follow the further steps in the AgNes process and to include the determination proposals emerging there in project and financing models at an early stage. ³²

Grid Connection Procedure for Battery Storage

With the amendment of the Power Plant Grid Connection Ordinance (KraftNAV) as of December 23, 2025, it was clarified in Section 1 (1) that battery storage within the meaning of Section 3 No. 36 EnWG expressly no longer falls under the ordinance (further information can also be found in the following article).³³

With their concept “Maturity Process for Grid Connections to the Transmission Grid” dated February 5, 2026, the German transmission system operators (TSOs) spoke out in favor of moving away from the priority principle (“first come, first served“). According to the TSOs’ proposal—subject to design by the BNetzA—the maturity process should take its place. This is intended to create a structured, transparent, and non-discriminatory process. The predictability and efficiency in the allocation of grid connections are to be increased. According to the TSOs’ proposal, four criteria will be relevant: land securing and permit status, technical plant and connection concept, capability of the petitioner, and grid and system benefit. The TSOs point out in their concept that the procedure they proposed still has to be confirmed by the BNetzA. Furthermore, they consider adjustments in the EnWG necessary for more legal certainty.³⁴

National Emissions Trading Started in Trading Phase

Since 2021, national emissions trading (nEHS) for the heating and transport sectors in Germany has supplemented European Emissions Trading 1 (EU-ETS 1), which was introduced back in 2005 and applies to emissions from power plants, industrial plants, and air and sea transport.³⁵ Emitters of CO₂ must purchase national emission certificates (nEZ) for every ton of CO₂ placed on the market. In 2025, revenues from the nEHS were around 16 billion euros.³⁶ During the introductory phase of the nEHS (2021–2025), there was a legally fixed price for the nEZ, which increased annually and most recently amounted to €55/nEZ (= 1 ton of CO₂). In 2026, a new trading phase begins in which the certificates will initially be auctioned within a price corridor (€55–65/nEZ) (auction phase). This will likely be followed in early November 2026 by a sales phase at a fixed price of €68/.³⁷ From 2027, the new European Emissions Trading 2 (EU-ETS 2) was supposed to largely replace the nEHS, but the start was postponed to 2028.³⁸ The CO₂ price makes the use of fossil fuels more expensive, which in turn makes switching to renewable alternatives more attractive and is thus intended to contribute to accelerating the energy transition.

Power Plant Strategy and Capacity Market

As a neutral institution, the BNetzA, in its latest report on electricity supply security, called for a need for 22–35 GW of controllable power plants and did not miss the opportunity to urge timely implementation of both regionally distributed power plants and grid expansion. Likewise, the BNetzA recognized that less (22 GW) reserve is necessary if the RE expansion proceeds as planned and that flexibility in generation and consumption can further reduce the need. Therefore, it is particularly relevant that due to the start of report preparation in 2024, the currently observable battery storage boom was not yet foreseeable. The study assumes an expansion of stationary, industrial battery storage of approx. 1 GW by 2035.³⁹ From today’s perspective (approx. 3 GW currently in operation⁴⁰ and a multiple planned by 2035 ⁴¹), the assessment of the need for reserve power plants would thus have to be significantly adjusted or reduced.

Without any recognizable derivation or justification, Federal Minister of Economics Reiche has now announced that by 2029, a total of 41 GW of reserve power plants are to be tendered over several tender rounds (2026: 12 GW; 2027: 21–26 GW; 2029: 3–8 GW). From 2026 to 2031, power plants to be newly built (including 10 GW of gas) will be tendered; the tender rounds thereafter are also planned for existing power plants. Decarbonization for the gas power plants is only planned for 4 GW gradually from 2040, before 2045. Refinancing is planned via the capacity market, which is yet to be defined and established. Currently, there is only an agreement between the federal government and the EU Commission, which does not yet have legal binding force.⁴²

The feedback is, as so often, mixed. The Federal Network Agency generally welcomes rapid implementation, which it had also called for itself. However, it also warns at the same time that implementation in 2026 will not happen as quickly as the Federal Ministry for Economic Affairs and Energy (BMWE) imagines and that the specific tender requirements must now be defined by the BMWE as quickly as possible. Associations and interest groups located in the conventional generation sector find the plan good, as expected, while battery, RE, and sustainability interest groups are rather displeased. Points of criticism are the unnecessarily high tender volume, the de-facto focus of the tender on a large number of gas power plants, the far too late decarbonization, and the resulting costs that are likely to be higher than necessary, which the general public must bear. Furthermore, there is a suspected non-compliance with EU law.⁴³

In our view, the procurement of necessary reserve power plants thus fits into a design that seems like clientelism, which will not significantly contribute to strengthening Germany as a business location or reducing dependence on fossil fuels and their suppliers.

Industrial Electricity Price

In November 2025, the BMWE presented the policy for an industrial electricity price. The action pursues the target of providing relief to companies with high electricity consumption that are in international competition and preventing them from migrating abroad. At the same time, the instrument is intended to provide an incentive to invest in climate-friendly technologies. A first draft of a funding guideline is available for the project, which has not yet been officially published (editorial deadline 09.02.2026).

Legal nature: The industrial electricity price is not a regulated end-customer price, but state aid (funding) granted as a non-repayable grant within the framework of a funding guideline; the basis under state aid law is the CISAF.

For relief, a reduction in electricity costs amounting to 50% of the reference price (but a maximum of 5 ct/kWh) is provided for 50% of annual consumption. However, a central condition is that companies use at least 50% of the granted aid for actions that contribute to cost reduction in the electricity system without increasing the use of fossil fuels.⁴⁴ Further information can be found in the following article.

Energy Transition Monitoring Report

At the beginning of December 2025, the independent expert commission on energy transition monitoring presented its annual report. The experts’ target is to evaluate the status of the energy transition and to point out options for action for a successful outcome. The metaphorical yellow energy transition traffic light indicates that the targets of the energy transition can still be achieved, but there is a need for committed political action in all areas. The commission chair highlighted supply security, grid infrastructure, and energy efficiency as particular challenges. Furthermore, several fields of action are to be focused on more strongly by politicians in the future: adapting the market design to the integration of renewable energies, splitting the German electricity price zone to strengthen local price signals, reducing fossil fuels such as natural gas, and efficiently promoting hydrogen, as well as consistency, efficiency, and better coordination of actions to promote the energy transition. Likewise, affordability for energy must not be neglected, as only then can broad acceptance among the population be ensured.⁴⁵ It remains to be seen whether the BMWE under Katharina Reiche will put the commission’s scientifically sound recommendations into practice or whether it will stick to its own ten key actions published in September 2025, which, in the view of several associations, are slowing down the energy transition.⁴⁶ We reported on this in our last article in October.

EEG Reform

The planned EEG reform and its design have been discussed in politics for some time. A new funding mechanism is planned, which is to be based on so-called Contracts-for-Difference (CfD): plant operators thus have revenue protection downwards—however, revenues above a certain threshold are skimmed off. The exact design is currently not yet clear. At the end of January 2026, Federal Environment Minister Schneider announced that the reform is now to be implemented accordingly quickly.⁴⁷

Conclusion

In conclusion, it remains to be noted that current energy policy continues to be characterized by high dynamics. The increasing importance of battery storage in our energy system is also reflected in the increasing regulation in this area. However, it is to be hoped that the remaining legal uncertainty, including regarding customer installations, will be addressed by politicians soon. The expansion figures also show that the energy transition is in full swing. However, the challenges associated with the increasing RE expansion make a restructuring of our electricity system necessary. In this context, the federal government is planning, among other things, the expansion of controllable power plants (power plant strategy) and the EEG amendment. The EEG reform remains eagerly awaited—the new funding mechanism, alongside electricity price development, will be decisive for how further RE expansion develops.

→ Read also our article from October 2025 from our series “WIND + SUN = POWER”: Trends and Developments in the Electricity Sector

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Sources and notes:

1 The series “WIND + SUN = POWER” is updated in every issue of E|nEws. This article refers to events in the period from October 7, 2025, to February 6, 2026.
2 Pie charts on electricity generation | Energy-Charts (Last access on Feb 3, 2025)
3 Bar charts on electricity generation | Energy-Charts (Last access on Feb 3, 2025)
4 Installed capacity | Energy-Charts (Last access on Feb 3, 2025)
5 China abolishes tax benefits for photovoltaic exports in April – pv magazine Germany (last access on Feb 6, 2026)
6 Net Transparency > Renewable Energies and Levies > EEG > Transparency Requirements > Market Premium > Market Value Overview (Last accessed on 2026-02-04) and calculation based on Net Transparency > Renewable Energies and Levies > EEG > Transparency Requirements > Market Premium > Spot Market Price according to § 3 No. 42a EEG (Last accessed on 2026-02-03).
7 Net Transparency > Renewable Energies and Levies > EEG > Transparency Requirements > Market Premium > Market Value Overview (Last accessed on 2026-02-04) and calculation based on Net Transparency > Renewable Energies and Levies > EEG > Transparency Requirements > Market Premium > Spot Market Price according to § 3 No. 42a EEG (Last accessed on 2026-02-03).
8 Calculation of the marketed volume: Quantity generated at non-negative prices / amount of electricity that could have been generated without curtailment etc.
Own calculation based on Net Transparency > Renewable Energies and Levies > EEG > Transparency Requirements > Market Premium > Spot Market Price according to § 3 No. 42a EEG (Last accessed on 2026-02-03), Net Transparency > Renewable Energies and Levies > EEG > Transparency Requirements > Market Premium > Online extrapolation of actual electricity generation from solar energy (Last accessed on 2026-02-03) and Net Transparency > Renewable Energies and Levies > EEG > Transparency Requirements > Market Premium > Online extrapolation of actual electricity generation from onshore wind energy (Last accessed on 2026-02-03).
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38 DEHSt – EU-ETS 2 Reporting Phase 2024 to 2026 – EU-ETS 2 Reporting Phase (2024-2026)
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43 Federal Ministry of Economics Apparently Plans Tender for 41 Gigawatts of Controllable Capacity by 2029 – pv magazine Germany (Last accessed on 2025-02-06).
44 Auf dem Weg zum Industriestrompreis: Der Förderrichtlinien-Entwurf im Überblick | RÖDL and Kommt jetzt der Durchbruch beim Industriestromreis? BMWE plant Strompreisentlastung für energieintensive Unternehmen | RÖDL .
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