PV Repowering 2026: How Industrial Companies Are Modernizing Their Existing Plants and Selling Them to Investors
Excerpt
Existing systems on industrial and commercial roofs built between 2010 and 2017 will reach the point in 2026 where photovoltaic repowering becomes economically viable: Modern TOPCon solar modules deliver 70 to 150 percent more power on the same roof area than the old array. Furthermore, Solar Package 1 has, since May 2024, unlocked the ability to replace modules on rooftop systems while retaining feed-in tariffs—and institutional investors are currently paying 8 to 12 times EBITDA multiples for repowered industrial assets. Those who repower and sell now will capture the full value difference between the old and new generations.
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PV repowering means removing old PV modules and, if necessary, inverters from the existing system and replacing them with modern TOPCon or HJT solar modules—typically increasing the installed capacity by 70 to 150 percent on the same industrial roof or ground-mounted system area. For companies with older systems built in 2010 or earlier, 2026 is the economic sweet spot: Solar Package 1 allows for the replacement of outdated components while retaining feed-in tariffs (roof-mounted systems subject to EU state aid approval), investors pay 8–12× EBITDA for clean existing assets, and the final 1.5 years under the classic EEG regime before the CfD requirement takes effect on July 17, 2027, present a one-time sales window. For investors rather than owners: In the Logic Energy model, you participate in repowered photovoltaic systems through the inverter revenue-sharing model—with a base return of 6 to 10 percent per year and a term of 20 to 40 years. Learn more in the PV Investment Pillar.
Table of Contents
What is PV repowering—and why is it worth repowering photovoltaic systems in 2026?
PV Modules Then vs. Now: The Technological Leap in Repowering
Solar Package I and EEG Feed-in Tariffs: When Does the Right to Feed-in Tariffs Remain in Effect?
Cost-Effectiveness: The Costs and Benefits of Repowering a PV System
What Investors Will Pay for Repowered Solar Power Plants in 2026
The Six-Phase Repowering Process: From the Structural Analysis Report to Closing
Sell or Operate It Yourself? A Strategic Decision Following Photovoltaic Repowering
This article is intended for industrial companies and investors who wish to modernize existing photovoltaic systems or sell them as assets following repowering. You will learn why 2026 is the economic window of opportunity for photovoltaic repowering, what technical value gains the new generation of modules brings, and how the process—from the structural engineering report to closing—is structured. The article summarizes the legal framework from the EEG 2023 and Solar Package I, CAPEX ranges, buyer profiles, and the Logic Energy model with fixed financing, a roof bridging system, and inverter revenue sharing.
What is PV repowering—and why is it worth repowering photovoltaic systems in 2026?
Photovoltaic repowering refers to the modernization of existing PV systems by replacing outdated components, such as solar modules or inverters, to improve the system’s output and efficiency. 2026 is the economic sweet spot: photovoltaic systems that are 8 to 15 years old will benefit from a new generation of modules that deliver between 70 and 150 percent more power on the same roof area.
Repowering, revamping, retrofit, expansion — the four terms clearly distinguished
Repowering must be distinguished from three related terms that are often confused in contracts and insurance matters:
Revamping: Restoring the original rated power following degradation or defects—same kWp, higher electricity yield thanks to more efficient components. The PV³ project on an industrial roof in Philippsburg, documented by pv magazine, illustrates this: 96,000 old thin-film solar modules were replaced with 16,000 modern crystalline modules; the rated power remained at 7.4 MWp—while power output increased by about 35 percent.
Retrofit / Repair: Replacement of defective individual components (e.g., a failed inverter, damaged modules). No structural changes.
Expansion: Adding new modules to previously unused roof areas. The additional capacity will be subject to the EEG rate in effect at the time of the expansion, while the existing capacity will continue to receive its original feed-in tariff.
Repowering, in the narrow sense, refers to the full or partial replacement of a system— while retaining the feed-in tariff—that preserves the existing system’s EEG feed-in tariff entitlement while significantly increasing its installed capacity. Within the EEG cluster, this complements the logic behind the declining feed-in tariff in 2026: When new feed-in rates decrease, maintaining the old tariff base while simultaneously increasing capacity acts as a double lever.
An Overview of the Technical and Economic Benefits of Repowering
Repowering photovoltaic systems involves replacing outdated components, such as solar modules and inverters, with modern technology. This can significantly increase the system’s efficiency and electricity output without requiring a complete new installation. In addition to modules and inverters, substructures, cabling, and monitoring systems can also be replaced—depending on the condition of the existing system, either as a partial repowering or as a complete replacement of the central components. Replacing the modules brings energy output in line with today’s technical capabilities and ensures the system’s longevity for the next 20 to 30 years. Economically, this creates three key benefits: higher installed capacity per square meter of roof area, higher specific electricity yield due to the improved low-light performance of modern TOPCon modules, and lower annual degradation compared to older systems from 2010 to 2015.
Why 2026 Is the Target Year for Older Facilities
There are three reasons why 2026 is the right year to modernize existing systems: First, the traditional EEG feed-in tariff regime will end with the mandatory CfD requirement taking effect on July 17, 2027. Second, following the elimination of the Chinese export rebate on April 1, 2026, module prices are set to rise by 10 to 15 percent. Third, in 2026, the first photovoltaic systems from the 2010–2014 PV boom—with their existing technology—will face a new generation of modules that simply produce twice as much. This opens up a clearly defined window of opportunity for industry, municipalities, and commercial operators.
PV Modules Then vs. Now: The Technological Leap in Repowering
Solar modules from the 2010–2015 industrial-scale boom typically deliver 230 to 280 watts-peak with a module efficiency of 14 to 17 percent. Current TOPCon and HJT technologies from the 2025–2026 model years achieve 440 to 500 watts peak with an efficiency of 21 to 24 percent. On the same roof area, this means double the power output—and, thanks to higher low-light performance, 30 to 50 percent more annual electricity yield.
Efficiency Leap: 2010 vs. 2026 in Numbers
Efficiency Trends as a Reality in Industrial Plants, in Numbers:
| Component | Industrial Facility 2010–2014 | Repowering 2026 | Jump |
|---|---|---|---|
| Module Efficiency | 14–17% | 21.5–24.8% | +50–75% |
| Module Rated Power | 230–280 Wp | 440–500 Wp | +80–115% |
| Cell Technology | Multicrystalline, BSF | TOPCon (~80% market share), HJT, back-contact | Generational Transition |
| Inverter Efficiency (Euro) | 95–96% | 98–99% (including hybrid inverters) | +2–3 pp |
| Warranty Period: Service | 20–25 years (linear) | 25–30 years (TOPCon) | +5–10 years |
| Yield per square meter of roof area | 125–165 kWh/m²/year | 220–290 kWh/m²/year | +70 to +130% |
| Sources: Fraunhofer ISE — Photovoltaics Report (as of October 31, 2025) · TaiyangNews — Cell & Module Technology Trends 2025 · ITRPV Roadmap 2025 · BSW-Solar Price Monitor Q1 2026. | |||
Specific Calculation Example: 500-kWp Industrial Roof
Specifically, for a typical industrial roof, this means: Anyone who installed a 500-kWp PV system in 2010—consisting of approximately 2,170 modules at 230 Wp each on about 3,200 m² of roof area—can, upon repowering in 2026, install approximately 2,500 PV modules at 450 Wp each on the same area —1.125 MWp, effectively doubling the output. WIWIN reports that theWaldböckelheim solar parksaw its output increase fivefold, from 790 kWp to 4.1 MWp, on 3.5 hectares—the ground-mounted system built in 2009was completely dismantled and replaced with significantly more powerful solar technology.
Three Economic Effects of Changing Modules
What does this mean economically? Three effects are at play. First, installed capacity is increasing. Second, the specific power output per kWp is rising by 5 to 10 percent due to improved low-light performance and bifacial modules. Third, degradation is decreasing: While modern TOPCon solar modules degrade at a rate of 0.4 percent per year,Tier 2 modules from 2010 oftendegradedat a rate of 0.7 to 0.9 percent per year—a direct driver of thephotovoltaic system’senergy efficiencyover its entire remaining lifespan.
Solar Package I and EEG Feed-in Tariffs: When Does the Right to Feed-in Tariffs Remain in Effect?
Under the EEG 2023, repowering of ground-mounted solar plants that qualifies for feed-in tariffs has been possible since January 1, 2023, without the requirement that the plant be defective. Solar Package 1 (Federal Law Gazette 2024 I No. 151, promulgated May 15, 2024, effective May 16, 2024) extended these regulations to rooftop systems for the first time—though subject to approval under EU state aid law. Anyone planning for 2026 should check the status of the EU notification with the EEG|KWKG Clearinghouse before replacing the modules.
EEG Feed-in Tariffs & Repowering: An Overview of the Legal Framework
An overview of the key guidelines:
| System type | Cutoff Date | Legal basis | Current Status |
|---|---|---|---|
| Ground-mounted solar arrays | 01.01.2023 | EEG 2023, Sections 38b, 48 | Active – no defect-related cause |
| Roof-mounted systems (industrial) | 16.05.2024 | Solar Package I — Section 38b(2) of the EEG, as amended | EU notification is in progress |
| EEG Feed-in Tariff Rate Extension | February 1–July 31, 2026 | BNetzA, Section 49 of the EEG 2023 | 7.78 ct/kWh (partial feed-in ≤ 10 kWp) |
| Direct Marketing Requirement | unchanged | § 21 EEG 2023 | For installed capacity of 100 kWp or more |
| CfD Requirement (Contracts for Difference) | 17.07.2027 | Art. 19d of Regulation (EU) 2024/1747 | 100 kW and up – no German law yet |
| EEG subsidy approval is set to expire | 31.12.2026 | European Commission | Sales window for repowered plants |
| Sources: Section 38b of the EEG 2023, as amended on May 15, 2024 · BNetzA — EEG Feed-in Tariffs · Solar Package 1, Federal Law Gazette 2024 I No. 151 · Article 19d of Regulation (EU) 2024/1747. | |||
Maintain the high pay scale; introduce new compensation for additional work
The economic crux: A 500-kWp photovoltaic system installed on an industrial roof in 2010 is still eligible for EEG feed-in tariffs through 2030. At the time, this feed-in tariff rate was significantly higher than today’s rate of 7.78 ct/kWh. With repowering that preserves feed-in tariffs, the old rate for the originally installed capacity remains in effect—the expansion operates under the current EEG feed-in tariff entitlement, via a PPA, or through direct marketing. This allows you to combine the old, higher rate for the existing portion with new market revenues for the additional capacity.
Repowering for Over-20-Year-Old Plants: A Fresh Start for the 20-Year Subsidy Program
Repowering can also make a decisive difference for systems over 20 years old that are no longer eligible for the statutory feed-in tariff after 20 years: Instead of entering post-EEG operation at merely the annual market value of solar power, the roof is retrofitted with modern technology—and the system enters a new subsidy cycle with a full 20-year subsidy period. In each case, this requires notification to the grid operator and registration in the Market Master Data Register in accordance with the obligations under the EEG and MaStRV.
Important: A complete, detailed breakdown of the EEG tariffs and feed-in rates can be found in the EEG Feed-in Pillar 2026; this article focuses on the repowering perspective. The regulatory asymmetry in 2026 is clear: Those who combine the old EEG regime for the existing portion with modern technology and PPA marketing for the expansion will secure a blended rate that the CfD reform will no longer structurally allow as of July 2027.
Cost-Effectiveness: The Costs and Benefits of Repowering a PV System
Turnkey repowering of an industrial rooftop system will cost between 600 and 1,100 euros per kilowatt-peak in 2026—with large-scale systems over 1 MWp costing around 600 to 750 €/kWp. According to Fraunhofer ISE data, the LCOE of a repowered industrial rooftop photovoltaic system ranges from 5.7 to 8.8 cents per kilowatt-hour, which is significantly lower than the industrial electricity price. When sold after modernization, clean existing assets fetch 1,000 to 1,400 €/kWp—a multiple of the residual value of the unmodernized old system.
CAPEX Range for Repowering in 2026 by Plant Size
The CAPEX range for the investment by facility size:
| System size | Repowering CAPEX 2026 | Sale Price After Repowering (Asset Deal) | Value Leverage Compared to the Existing "As-Is" System |
|---|---|---|---|
| 100–500 kWp rooftop system | 900–1,100 €/kWp | 800–1,200 €/kWp | 3–5× |
| 500 kWp – 1 MWp Roof | 750–950 €/kWp | $950–$1,300 per kWp | 4–6× |
| 1–10 MWp Roof/Ground-Mounted | 650–850 €/kWp | 1,000–1,400 €/kWp | 5–7× |
| > 10 MWp ground-mounted | 600–750 €/kWp | 1,100–1,450 €/kWp | institutional investors |
| Sources: Fraunhofer ISE — Photovoltaics Report (10/2025) · BSW-Solar — Price Monitor (Q1 2026) · Information provided by mediplan Helm e.K. based on current market observations for Q1 2026. Return figures are based on historical data and do not guarantee future results. | |||
Four Options for the Existing 500-kWp System
What are our projections for a 500-kWp industrial rooftop system installed in 2010 with 4 years remaining under the EEG?
Option A – Continue operating the existing plant as is: approx. 28 ct/kWh historical EEG tariff × 450,000 kWh × 4 years = approximately 500,000 € in remaining revenue. Thereafter, the post-EEG market with the annual market value for solar (2025: 4.508 ct/kWh) – the value is structurally declining.
Option B – Sale of the existing system “as-is”: discounted residual value, ranging from €50,000 to €90,000 depending on the condition of the modules. The buyer assumes the residual risk and maintenance.
Option C – In-house repowering and self-generation: CAPEX of approximately €950,000 when doubling capacity to 1 MWp; electricity cost savings of €200 to €400 per MWh for industrial consumption. Maximizing self-consumption reduces dependence on the feed-in tariff.
Option D – Repowering and Sale to an Investor: CAPEX of approximately €950,000 is fully recouped through the proceeds from the sale; asset value after repowering ~€1.1 to 1.4 million. Added value: €150,000 to 450,000 plus cash generated, plus an optional on-site PPA for discounted electricity for self-consumption.
Tax Incentive: Combining Section 7g of the Income Tax Act (EStG) with Repowering
The profitability analysis hinges on the balance between the existing tariff structure and the new module configuration. From a tax perspective, repowering combines with traditional tools such as the investment deduction and special depreciation under Section 7g of the German Income Tax Act (EStG), as well as declining-balance depreciation—we describe the exact mechanics in detail in the article on “Saving on Photovoltaic Taxes in 2026.” With proper structuring, a large portion of the repowering CAPEX can be claimed for tax purposes as early as the first and second years.
LCOE vs. Industrial Electricity Price: The Crucial Spread
To put the LCOE level into perspective: In 2026, the levelized cost of electricity (LCOE) for photovoltaic systems will range between 5.7 and 8.8 ct/kWh for commercial rooftop installations over 30 kWp in southern Germany. A repowered solar system thus operates at costs that are significantly below the industrial electricity price: According to the BDEW electricity price analysis for January 2026, new contracts for small to medium-sized industrial companies will pay an average of 16.0 ct/kWh net in 2026, while medium-sized and large industrial companies will pay 14.4 to 15.9 ct/kWh—following a decrease of 1.6 ct/kWh thanks to electricity tax relief and transmission grid fee subsidies. This spread between the industrial electricity price and the repowered LCOE is the investment case—and at the same time, the key advantage for any business owner who wants to make their energy supply predictable in the long term.
What Investors Will Pay for Repowered Solar Power Plants in 2026
Institutional buyers—infrastructure funds, IPPs, and family offices—will pay between 8 and 12 times EBITDA for existing clean German solar assets in 2026. On a €/kWp basis, repowered industrial plants with a good remaining EEG term or PPA hedging fetch between 1,000 and 1,400 €/kWp. Buyers’ expected unlevered returns range from 5 to 8 percent per year, rising to 8 to 10 percent with battery storage co-location.
Four Buyer Groups for Repowered Photovoltaic Systems
Who will be the buyers of photovoltaic systems in the German market in 2026?
| Buyer Group | Examples | Minimum investment amount | Expected Return |
|---|---|---|---|
| Infrastructure & Renewable Energy Funds | Aquila Capital, CEE Group (Repowering Fund RF9, up to €1.6 billion), HEP Energy | 5–10 MWp | 5–8% unleveraged IRR |
| Independent Power Producers | Encavis (KKR/Viessmann since 2024), ENERPARC, Statkraft DE, Tion Renewables | 10 MWp+ | 6–8% IRR |
| Municipal Utilities & Energy Providers | EnBW, Pfalzwerke, MVV/JUWI, EnviaM, Mainova | 1–5 MWp | 5–7% IRR |
| Family Offices & Direct Investors | Inverter Revenue Sharing: Logic Energy, Milk the Sun, Solar Direktinvest | 200 kWp – 5 MWp | 6–10% per annum (base) |
| Sources: Capcora M&A Advisory 2024/25 · CEE Group RF9 press release, December 2025 · KKR/Encavis acquisition, March 2024 · Helm Group portfolio data, 2024. Return figures are based on historical data and are not a guarantee of future results. | |||
Three Market Signals: KKR/Encavis, CEE Group, WIWIN
Three actual transaction signals underscore the market’s strength: First, in March 2024, KKR, together with Viessmann, acquired Encavis AG —a publicly traded IPP with an operational portfolio of approximately 2.2 GW of solar and onshore wind across ten European countries, in a transaction valued at approximately €2.8 billion. This is clear confirmation that institutional investors view German solar assets as long-term infrastructure. Second, in December 2025, the CEE Group closed a club deal financing of up to 1.6 billion euros for its RF9 repowering fund—with the explicit goal of leveraging an existing portfolio of 457 MW to approximately 1.1 GW. According to White & Case deal documentation, the international banking consortium comprising CIBC, ING Bank, KfW IPEX-Bank, SMBC, SEB, and UniCredit underscores the bankability of the repowering concept. Third, WIWIN reports the completion of a 4.1-MWp repowering project at an existing solar park in Waldböckelheim that went into operation in 2009—a fivefold increase in capacity from 790 kWp to 4.1 MWp on 3.5 hectares, financed through citizen crowd-investing. This demonstrates that the semi-institutional market is also embracing repowered photovoltaic assets.
Due Diligence Requirements for Institutional Buyers
What do institutional buyers expect during due diligence? A technical expert report (TÜV, DNV, Enertis), a performance ratio above 80 percent, a complete EL imaging analysis of the PV modules, reliable documentation of the remaining EEG term, and, ideally, a PPA with a term of 10 to 15 years. Warranties: at least 10 years remaining on the module performance warranty (modern TOPCon solar modules now come with a 25- to 30-year performance warranty from the date of commissioning), inverters with a 10-year product warranty and a 5-year extended warranty, and a mounting system with a 20-year warranty.
Investors who join the Logic Energy model take the opposite approach: Instead of acquiring a repowered plant as an asset, they participate in an industrial plant designed and built by Logic Energy through the inverter revenue-sharing program—with a base return of 6 to 10 percent per year and a term of 20 to 40 years. Anyone starting their own PV investment can find the complete model description there.
The Six-Phase Repowering Process: From the Structural Analysis Report to Closing
A complete industrial roof repowering project, followed by a sale to an institutional investor, typically takes 12 to 18 months. The process consists of six phases: assessment, EPC selection, permitting, dismantling and module resale, installation and commissioning of the modernized photovoltaic system, and the marketing process, including a data room and a bidding process.
Six-Phase Model: From Initial Assessment to Closing
| Phase | Period | Duration | Activities |
|---|---|---|---|
| 1. Assessment & Appraisal | Months 1–2 | 8 weeks | Technical Inventory · EL Testing of Modules · 12-Month Performance Analysis · Structural Analysis of the Roof · Documentation of Remaining EEG Term · Discounted Cash Flow Valuation |
| 2. Design & EPC Selection | Months 2–4 | 8 weeks | Determine the repowering option (partial/full) · Issue a request for proposals to 3–5 EPC contractors · Select based on price, warranties, references, and construction time |
| 3. Approval & Funding | Months 4–6 | 8 weeks | Market Master Data Registry Update · Coordination with the Grid Operator · Building Permit/Notice in Accordance with State Building Codes · KfW 270 or Commercial Bank Financing · Project Financing via an SPV, if applicable |
| 4. Dismantling & Module Sales | Months 6–7 | 4 weeks | Dismantling of Existing Modules · Categorization: Second Life vs. Recycling · Sale of Intact Modules via Marketplaces · Proof of Disposal in Accordance with the WEEE Directive |
| 5. Installation & Commissioning | Months 7–9 | 8 weeks | Installation of modern TOPCon modules · Inverters (including hybrid inverters with a battery storage interface) · New wiring, if necessary · Grid connection compliant with VDE-AR-N 4105 · Expert inspection · Fire protection compliant with VdS standards |
| 6. Marketing & Sales | Months 9–18 | 36 weeks | Engage an M&A advisor · Set up a data room · Bidding process with 4–6 buyers · 2–3 binding offers · Closing as an asset or share deal |
| Sources: Logic Energy’s own framework based on practical projects by the Helm Group · pv magazine — PV³ Philippsburg Documentation 2025. | |||
Phase 1 in Practice: EL Test, Performance Ratio, Structural Analysis Report
What really needs to be checked in Phase 1? A complete EL (electroluminescence) image analysis of the solar modules reveals microcracks and degradation patterns that are not detected during a standard visual inspection. The 12-month performance ratio analysis shows how much the system deviates from its original target curve—repowering is usually economically viable when the loss reaches seven percentage points or more. A structural analysis report is mandatory because, although modern PV modules are lighter per kWp, they are often heavier per module and installed in a different configuration. On older systems with industrial roofs from the 1980s and 1990s, reinforcement measures may be necessary—this is where Logic Energy’s proprietary roof bridging system becomes a key differentiator.
Phase 6 in Practice: M&A Advisors and Data Room Quality
In Phase 6, the quality of the data room is of paramount importance. Institutional buyers want a complete technical due diligence report, P50/P75/P90 yield forecasts from an independent appraiser, all lease agreements, EPC warranty certificates, insurance policies, and EEG feed-in tariff notices in a structured format. Those who engage an experienced M&A advisor such as Capcora, KPMG Renewables, or JLL Energy during this phase typically achieve sale prices that are 10 to 20 percent higher than those achieved through a direct bilateral sale.
Risks: Structural Engineering, Insurance, EU State Aid Law
Industrial PV repowering involves five recurring sources of risk: roof structural integrity in older industrial buildings, stricter insurance requirements effective in 2024, the EU state aid proceedings regarding Solar Package I, potential fire safety requirements, and the reform of the negative price regulation under the Solar Peak Act. Addressing these five points before the project begins can prevent 90 percent of conflicts during the construction phase.
An Overview of Five Risk Areas
| Risk Area | Description | Rating | Countermeasure |
|---|---|---|---|
| Roof Structural Analysis | The existing roof may not be designed to accommodate a different load distribution | medium | Phase 1 Structural Engineering Reassessment · Logic-Energy Roof Bridging System for Industrial Roofs with Point Load Capacity |
| Insurability | Property and casualty insurers (Allianz, Ergo, R+V, VHV) have been tightening their requirements since 2024/25 | medium | VdS-compliant fire protection · Arc fault detection (AFCI) in the inverter · Glass-glass modules for industrial buildings larger than 2,000 m² |
| EU State Aid Proceedings | Solar Package 1 Repowering: Roof Project Subject to Approval | medium | Consult the EEG-KWKG Clearing House in advance · If necessary, structure the repowering project in such a way that the existing feed-in tariff is guaranteed to remain in place |
| Solar Peak Act | Systems with a capacity of 2 kWp or more will not receive compensation when electricity prices are negative, effective February 25, 2025 | medium | Planning Repowering with Battery Storage Co-location · Grandfathering provisions are generally maintained for module-only replacements—check on a case-by-case basis |
| CfD Requirement Effective July 2027 | Renewable Energy Feed-in Tariff to Be Transitioned to Bilateral Differential Contracts | high as of July 17, 2027 | Complete the repowering by mid-2027; document the commissioning |
| Rise in Module Prices | Chinese export discount eliminated as of April 1, 2026 – modules +10 to 15% | medium | Protect module quotas from further price increases |
| Sources: EEG|KWKG Clearing House — Legal Issue 100 (Repowering) · VdS Fire Safety Guidelines for Property Insurers 2024/25 · Solar Peak Act, Federal Law Gazette 2025 I No. 51 · Art. 19d of Regulation (EU) 2024/1747 · Grant Thornton — Analysis of the Solar Peak Act. | |||
Roof bridging system for industrial roofs with localized load-bearing capacity
A particular strength when it comes to existing industrial roofs: The Helm Group has developed its own roof bridging system that makes roof areas with localized load-bearing capacity suitable for full-surface PV installation. A base plate with trapezoidal profiles rests on the load-bearing supports and bridges the non-load-bearing gaps. Roofs that other EPC providers reject due to insufficient load-bearing capacity can be repowered in this way—which is often the decisive bottleneck for older industrial buildings from the 1980s and 1990s, making this system a game-changer for many industrial customers looking to pursue photovoltaic repowering.
For information on negative electricity prices and their impact on existing installations, please refer to the Cluster article “The Solar Peak Law for Investors,” which describes the legal mechanisms for grandfathering in detail.
Sell or Operate It Yourself? A Strategic Decision Following Photovoltaic Repowering
Four strategic arguments in favor of selling the repowered photovoltaic plant in 2026 rather than having the industrial company operate it itself are: an asset-light strategy, cash generation of 1,000 to 1,400 €/kWp, an on-site PPA as a dual lever, and a valuation uplift resulting from repowering prior to the sale. For a 2-MWp plant, this translates to a liquidity release of 2.0 to 2.8 million euros for the core business.
A Direct Comparison of Selling vs. Operating the Business Yourself
What are the specific reasons for selling?
| Criterion | Sale Following Repowering | Operate it yourself |
|---|---|---|
| Capital Commitment | Cash generated: 1,000–1,400 €/kWp · Reinvestment in core business | Significant capital tied up for 20–30 years |
| Operational Risk | Transition to specialized operators · O&M and maintenance outsourced | Self-Management, Direct-to-Consumer Relationship, EEG Billing |
| Cost of self-generated electricity | On-site PPA: 5.5–7.5 ct/kWh (vs. industrial electricity: ~14–16 ct/kWh) | Self-consumption at an LCOE of ~5.7–8.8 ct/kWh |
| Balance Sheet | Asset-light, off-balance-sheet · ESG story remains intact via PPA | Fixed Assets, Depreciation, Insurance on the Company's Own Balance Sheet |
| Structuring | Asset Deal or Share Deal via an SPV · M&A Advisor | No structuring required |
| Value Added from Repowering | Full valuation uplift realized (typically 20–35%) | Value added remains on the balance sheet as a "hidden reserve" |
| Sources: Helm Group’s own model calculations based on Q1 2026 · BDEW Electricity Price Analysis, January 2026 · Capcora M&A Practical Experience 2024/25 · Fraunhofer ISE LCOE Study. Return figures are based on historical data and do not guarantee future results. | ||
Three Sales Methods: Asset Deal, Share Deal, Sale-and-Leaseback
Structurally, there are two sales options: An asset deal transfers individual assets and contracts to the buyer—a cleaner approach for smaller, individual properties, but time-consuming due to the many individual assignments. The share deal transfers 100 percent of the shares in a project company (typically a GmbH & Co. KG) that owns the facility—a single purchase agreement, with all contracts continuing as is. For larger photovoltaic systems of 2 MWp or more, the share deal is the standard approach because lease agreements, EPC guarantees, maintenance contracts, and the EEG feed-in tariff notice are all transferred at once.
Sale-and-leaseback is the third option: The industrial company sells the PV system to an investor or a leasing company and leases it back for 20 to 30 years. This frees up capital without interrupting the power supply—the system no longer appears on the company’s balance sheet, but self-consumption and energy generation remain available under PPA terms.
The Logic Energy Repowering Model for Industrial Companies
For industrial customers, Logic Energy brings all four stages of the value chain together under one roof: technical and energy-economic assessment of existing installations, EPC repowering using the company’s proprietary roof bridging system, fixed financing secured before construction begins through mediplan Helm e.K. with personal liability on the part of the owners—and the subsequent marketing to institutional investors or family office buyers. This allows existing plants to be transformed from “residual-value assets” into marketable renewable infrastructure within 12 to 18 months.
Five structural differences compared to traditional repowering EPCs
Five structural factors set Logic Energy apart from other repowering EPCs:
Active acquisition of existing systems starting at 200 kWp
First: We actively seek out sites and existing systems—mediplan Helm e.K. maintains a systematic acquisition process for commercial and industrial photovoltaic systems starting at 200 kWp. Owners of existing systems planning a repowering project receive a free initial assessment of the system’s economic viability and sales potential.
Financing Secured Before Construction Begins
Second: The financing for the investment is secured before construction begins. Unlike traditional EPC providers, who leave financing up to the owner, mediplan Helm e.K. arranges the complete financing package for investors—ensuring that the repowering project does not fail due to a gap in interim financing.
In-house Roof Bridging System
Third point: Our proprietary roof bridging system. Many industrial roofs from the 1980s and 1990s are load-bearing only at specific points over the supports—the spaces in between cannot support the weight of the modules. Traditional EPCs reject such roofs. Our base plate with trapezoidal profiles rests on the load-bearing points and bridges the rest—making the entire roof suitable for PV installation.
Personal Liability of Owners Pursuant to Sections 1, 17, and 19 of the German Commercial Code (HGB)
Fourth: Personal liability of the owner. The contracting party for direct PV investments and for the acquisition of existing plants is mediplan Helm e.K.—a registered business entity with unlimited personal liability of the owner pursuant to Sections 1, 17, and 19 of the German Commercial Code (HGB). For both industrial sellers and investors, this is a substantial sign of trust compared to structures based solely on a GmbH.
Inverter Revenue Sharing as an Investment Model
Fifth: Inverter revenue sharing as an investment model. Anyone who does not want to sell a repowered system but instead wants to keep it as an investment—or anyone who wants to invest in repowered photovoltaic systems without owning an existing system themselves—can participate through the inverter revenue-sharing model, which has a term of 20 to 40 years. The minimum investment is 100,000 euros. Details about the model can be found on the “Become a PV Investor” page.
Investors (i.e., buyers, not owners) looking for solar power investments will find a comprehensive overview of investment types, return structures, and tax incentives in the PV Investment Pillar.
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Are you the owner of an industrial PV system installed between 2010 and 2017 and wondering whether repowering is a worthwhile investment? Or are you an investor interested in participating in repowered photovoltaic systems? In a no-obligation initial consultation, we’ll determine which approach offers the greatest economic benefit for your situation—including an initial assessment of your existing system or a customized investment structure based on inverter revenue sharing. With fixed financing secured before construction begins, personal liability coverage from mediplan Helm e.K., and our in-house roof bridging system for industrial roofs that other providers reject.
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This article is intended solely for general informational purposes and does not constitute investment, tax, or legal advice. Return figures are based on historical data and are not a guarantee of future results. The regulatory landscape—particularly regarding EU state aid approval for Solar Package 1, the CfD reform effective July 17, 2027, and the mechanics of the Solar Peak Act—may change at short notice. For your specific situation, please consult a licensed financial or tax advisor as well as the EEG|KWKG Clearing House for legally sound information. The contracting party for direct PV investments and the acquisition of existing plants through Logic Energy is mediplan Helm e.K. (a registered merchant with personal liability of the owner pursuant to Sections 1, 17, and 19 of the German Commercial Code (HGB)). As of May 2026.
FAQ
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PV repowering refers to the replacement of key components—primarily solar modules and inverters—in an existing industrial photovoltaic system with the goal of significantly increasing power output and energy yields. In 2026, it will typically be possible to install 70 to 150 percent more kilowatt-peak on the same roof area, because modern TOPCon modules deliver 440 to 500 watt-peak, whereas modules from 2010 had only 230 to 280 watt-peak. Under Solar Package 1, the replacement is possible while retaining feed-in tariffs, subject toapproval under EU state aid law.
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For ground-mounted systems, module replacement while retaining feed-in tariffs has been possible since the EEG 2023 (effective January 1, 2023) without requiring a defect. For rooftop systems, the same rule was introduced with Solar Package 1 effective May 16, 2024, but is subject to approval under EU state aid law. Existing feed-in tariffs for the original capacity generally remain in effect; any increase in capacity is remunerated at the currently valid EEG tariff or via a PPA or direct marketing. Specific feed-in tariffs for 2026 are listed in the EEG Feed-in Tariff Pillar. Individual applicability must be verified by the EEG|KWKG Clearing House.
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Turnkey repowering of an industrial rooftop system will cost between 600 and 1,100 euros per kilowatt-peak in 2026. For systems ranging from 100 to 500 kWp, prices typically range from 900 to 1,100 €/kWp; for systems of 1 MWp or more, prices are around 750 €/kWp; and for large-scale systems exceeding 10 MWp, prices range from 600 to 750 €/kWp. CAPEX includes PV modules, inverters, cabling, monitoring, and, if necessary, structural adjustments. The remaining term of the EEG feed-in tariff is secured through the tariff-preserving repowering mechanism under Solar Package 1.
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Four buyer groups dominate the market: infrastructure and renewable energy funds such as Aquila Capital, CEE Group, and HEP Energy; independent power producers such as Encavis (owned by KKR/Viessmann since 2024), ENERPARC, Statkraft Deutschland, and TionRenewables; municipal utilities, local governments, and energy suppliers such as EnBW, Pfalzwerke, and MVV; as well as family offices and direct investors via marketplaces and Logic Energy’s own inverter revenue-sharing model. Minimum sizes range from 200 kWp (family offices) to 10 MWp (institutional buyers). Return figures are based on historical data and are not a guarantee of future results.
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Industrial companies can combine traditional tax instruments when repowering: the investment deduction under Section 7g of the German Income Tax Act (EStG), special depreciation under Section 7g(5) EStG, and declining-balance depreciation. This allows a significant portion of the repowering CAPEX to be treated for tax purposes as early as the first two years. The exact mechanics, conditions, and model calculations are detailed in the article “Saving on Photovoltaic Taxes in 2026.” A tax advisor should verify the applicability of these measures on a case-by-case basis .
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Three factors determine the timing. First: If your plant’s performance ratio deviates by more than 7 percentage points from the original design value over a 12-month period, repowering is economically viable. Second: If the remaining term of the EEG is at least 4 years, the mechanism for maintaining feed-in tariffs is worthwhile. Third: The traditional EEG regime remains in effect until July 2027—after that, the CfD requirement applies to new installations of 100 kW or more. Those who start in 2026 and complete the project in 2027will benefit from the last generation of the traditional EEG regime and the current valuation multiple.
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Functioning solar modules with a minimum output of 200 watts-peak can be sold on the second-life market—prices range from 5 to 15 cents per watt-peak, depending on age and condition. Marketplaces such as pvXchange, SecondSol, and 2ndlifesolar inspect and market used modules. Defective modules or those that can no longer be sold are sent for recycling through PV CYCLE or equivalent collection organizations—the material recovery rate exceeds 95 percent for aluminum, glass, and copper, and is increasingly high for silicon and silver as well. Disposal certificates in accordance with the WEEE Directive are mandatory.
References
Fraunhofer ISE — Photovoltaics Report — Module Efficiency, System Prices, TOPCon Market Shares, as of October 31, 2025
Fraunhofer ISE — Levelized Cost of Electricity for Renewable Energy (LCOE Study) — LCOE for industrial rooftops: 5.7–8.8 ct/kWh, as of July 2024
Fraunhofer ISE — Recent Facts about Photovoltaics in Germany — Current market data, degradation rates, as of August 18, 2025
TaiyangNews — Cell & Module Technology Trends 2025 — TOPCon market share ~80%, HJT, back-contact technologies
ITRPV — International Technology Roadmap for Photovoltaics 2025 — Efficiency Roadmap, n-type wafers with a 70% market share
BSW-Solar — Price Monitor / Industry Statistics — System Prices for Industrial Roofs, as of Q1 2026
BDEW — Electricity Price Analysis, January 2026 (PDF) — Industrial electricity price for new contracts: 16.0 ct/kWh, as of January 12, 2026
BDEW — Electricity Price Analysis Overview Page — Continuously Updated Electricity Prices for Households & Industry
Federal Network Agency — EEG Subsidies and Feed-in Tariffs for Solar Power Systems — EEG Feed-in Tariffs February 1–July 31, 2026 (7.78 ct/kWh for partial feed-in up to 10 kWp)
Federal Network Agency — Archived EEG Feed-in Tariffs — Rates to be Applied for Solar Power Plants from August 2025 through January 2026
EUR-Lex — Regulation (EU) 2024/1747 — Electricity Market Reform, Art. 19d on the CfD requirement effective July 17, 2027, effective July 16, 2024
EUR-Lex — Regulation (EU) 2024/1747 (PDF, Official Journal) — Full text from the Official Journal
gesetze-im-internet.de — Section 38b EEG 2023 — Module Replacement While Retaining Feed-in Tariff, Version May 15, 2024
gesetze-im-internet.de — EEG 2023 (Full Text) — Renewable Energy Act 2023 with Solar Package 1 Amendments
gesetze-im-internet.de — Section 7g of the Income Tax Act (EStG) — 50% investment deduction, 40% special depreciation
Federal Law Gazette — Solar Package 1 (BGBl. 2024 I No. 151) — Act Amending the Renewable Energy Sources Act (EEG), promulgated May 15, 2024, effective May 16, 2024
EEG|KWKG Clearing House — Solar Package I (Legislative Process) — Solar Package 1 Procedural Documentation and Entry into Force
EEG|KWKG Clearing House — Legal Issue 100: Expansion and Repowering — Repowering While Retaining Feed-in Tariff Payments, Subject to Approval Under EU State Aid Law
EEG|KWKG Clearing House — Legal Issue 141: PV Module Replacement and Feed-in Tariff — Retention of the Commissioning Date and Feed-in Tariff Amount
Bundestag — Printed Paper 20/8657 (Solar Package 1 Bill) — Explanatory Memorandum on the Repowering Regulation for Rooftop Systems
Grant Thornton — Economic Impact of the Solar Peak Act — Solar Peak Act, May 2025: New Compensation Rules for Negative Prices
BSW-Solar — FAQ on the Solar Peak Act — Grandfathering, voluntary switch with +0.6 ct/kWh
CEE Group — Press Release: RF9 Repowering Fund (€1.6 billion) — Existing portfolio: 457 MW → 1.1 GW, 29 plants, December 2025
White & Case — Legal Counsel to the RF9 Banking Consortium — Syndicated financing by CIBC, ING, KfW IPEX, SMBC, SEB, and UniCredit, December 2025
KKR — Acquisition of Encavis AG — KKR/Viessmann investor agreement with Encavis, transaction value ~€2.8 billion, March 2024
pv magazine — Repowering and Revamping on the Rise (PV³ Philippsburg, CEE) — 7.4 MWp industrial rooftop in Philippsburg, 96,000 thin-film modules versus 16,000 crystalline modules, yield +35%, December 2025
WIWIN — Waldböckelheim Solar Park Repowering 4.1 MWp — Fivefold increase in capacity (790 kWp → 4.1 MWp), 3.5 ha, commissioning in December 2024
German Solar Industry Association (BSW-Solar) — Industry and Market Data on Photovoltaics in Germany
Federal Association for New Energy (bne) — Position Papers on Repowering, Estimation of Open-Space Potential
German Solar Energy Promotion Association (SFV) — Repowering — Practical Description: Solar Package 1—Repowering of Rooftop Systems
Helm Group / Logic Energy — Portfolio Data 2024 (Inverter Revenue-Sharing Model, 6–10% p.a. base return)