Italy's solar market is shrinking in 2025: Why are small-scale systems losing ground while utility-scale systems are growing?
Excerpt
Italy’s solar market is shrinking —for the first time since 2020. With 6.4 GW of newly connected PV capacity, Italy’s expansion in 2025 was five percent below the previous year’s level and 660 MW short of the PNIEC target (Italia Solare, February 7, 2026). For Italy’s energy transition, this marks a break from the acceleration seen in recent years; at first glance, it is bad news for investors with exposure to Italy. Upon closer inspection, however, it becomes clear that the overall decline masks one of the most structurally exciting shifts in the European energy sector. German direct investors looking at the country today see a different market than in 2022 or 2023—smaller in size but more concentrated in value. We examine this market analysis in the following report, focusing on data, strategy, and forecasts for 2026.
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In short: Italy’s solar market will shrink in 2025 for the first time since 2020 —to 6.4 GW of new capacity (–5%), with cumulative capacity reaching 43.5 GW by the end of 2025 and 44.95 GW as of March 31, 2026 (Italia Solare/Terna Q1 2026). Behind these aggregate figures lies a structural polarization in the Italian solar energy market: residential installations are plummeting (–32%), the commercial mid-market (C&I) is declining (–26%), while utility-scale projects ≥ 1 MW are growing by +15% and account for 53% of all newly installed megawatts. For German investors, this means: Italy remains attractive in 2026—but selectively, with a focus on approved large-scale plants in southern Italy, secured revenue streams, and early pipeline securing. In 2026, large-scale Italian plants will structurally achieve higher realized electricity prices than comparable plants in Germany—the mechanics of this European spread are explained in our Schisma analysis of the European solar market.
Table of Contents
Key figures for 2025: –5% overall, with three different rates of decline
DL Bollette 21/2026: Three Measures That Are Reshaping the Market
Why the residential segment is slumping: the Superbonus hangover
The C&I sector: caught between a wait-and-see approach and recovery
The five most significant risks from an investor's perspective
Key figures for 2025: –5% overall, with three different rates of decline
Italy’s solar market reached a gross installed capacity of approximately 6.4 GW in 2025—a 5% decline from the previous year and the first contraction in five years. However, this aggregate figure masks three completely different trends: residential installations and the mid-sized commercial sector are collapsing, while utility-scale projects ≥ 1 MW are growing at a double-digit rate. From an investor’s perspective, it is not the headline that matters, but the underlying segment breakdown in the Italian solar energy market.
Italia Solare published the report on February 7, 2026, based on Terna’s Gaudì registry. According to the report, Italy’s cumulative PV capacity stood at 43.5 GW across 2.09 million installations at the end of 2025—and had already grown to approximately 44.95 GW across 2.2 million installations by Q1 2026—meaning that while installed solar capacity grew, the annual rate of expansion did not. The amount of solar power fed into the grid is higher than ever before in absolute terms; what is shrinking is the rate of growth. Solar power generation reached 44.3 TWh (+25% compared to 2024)—and thus, for the first time, exceeded hydropower. As a result, solar energy became Italy’s leading renewable power source in 2025, and the Italian solar energy market is demonstrating a level of maturity that is evident in the latest report from Italia Solare.
However, the real message of the report lies in the distribution of the new construction:
| Segment | 2024 (MW) | 2025 (MW) | Change | Share in 2025 |
|---|---|---|---|---|
| Residential < 20 kW | ~ 1.901 | ~ 1.281 | – 32 % | 20 % |
| C&I 20 kW – 1 MW | 2.194 | 1.744 | – 26 % | 27 % |
| Utility-scale ≥ 1 MW | 2.910 | 3.412 | + 15 % | 53 % |
| Italy as a whole | ~ 6.800 | 6.437 | – 5 % | 100 % |
| Methodik-Hinweis: Italia Solare nennt für den Residential-Rückgang je nach Cut-off (< 12 kW vs. < 20 kW) –24 % bzw. –32 %; wir nutzen den Headline-Wert. Terna „nuove attivazioni" weist 5,62 GW aus. | ||||
Particularly striking: The fourth quarter of 2025 alone accounted for 2.4 GW of new capacity—37% of the annual total. Large-scale plants over 10 MW connected 1,031 MW to the grid in Q4, more than in the previous three quarters combined (688 MW). This is no coincidence, but rather the result of permits processed from previous years—and a harbinger of what will drive market demand in 2026. Accordingly, the forecast by Italian industry associations for 2026 anticipates new capacity of around 6 GW or slightly more, with a significantly shifted segment structure.
Q1 2026 confirms and reinforces the trend: 1,439 MW of new capacity (+0.5% compared to Q1 2025) with 18% fewer new installations — meaning Italy is building fewer, but larger, projects. Residential remains in decline at 287–313 MW (–13 to –16% YoY), the C&I mid-range recovers by +23 to +32% depending on size class, and the mid-scale segment (1–10 MW) delivers 482 MW (+42% YoY) across 161 plants. Noteworthy: Utility-scale ≥10 MW fell to 154 MW in Q1 2026 (4 plants, –55%)—the large Q4 2025 commissioning projects were cannibalized, and the mid-scale segment is taking the lead for now. Solar power generation rose by +19.2% YoY in Q1 2026 (Terna, 04/2026). The Italian market is thus developing at two speeds—structurally narrower, but dynamic again in the mid-scale segment for the first time in years.
DL Bollette 21/2026: Three Measures That Are Reshaping the Market
On April 18, 2026, Decree-Law 21/2026 was published as Law No. 49/2026 in the Official Gazette No. 90—marking the most far-reaching policy intervention in Italy to date since the expiration of the Superbonus. Three key elements are crucial for investors with exposure to Italy.
Spalma-incentivi 2.0 requires existing Conto-Energia facilities >20 kW to make a choice by May 31, 2026. Three options are available: a 15% tariff reduction in exchange for a 3-month contract extension (Option A), a 30% tariff reduction in exchange for a 6-month extension (Option B), or a complete withdrawal from remaining subsidies in exchange for a payout of 90% of the discounted residual value in 10 annual installments starting in 2028 (Option C). Option C is limited to a maximum of 10 GW of cumulative capacity and is to be allocated via a GSE downward auction by June 30, 2027; a prerequisite is complete repowering by December 31, 2030, with doubled expected production. Industry analysts (Studio Advant Nctm, Elemens) expect a low uptake rate—the economic case does not add up for most existing operators. GSE interim figures are not expected to be published until after May 31, 2026.
The Virtual Saturation Reform addresses the backlog in the pipeline caused by multiple virtual applications, a problem that has been a source of complaint for years. In the future, Terna must publish the maximum available connection capacity per grid area on the T.E.R.R.A. portal on a quarterly basis; ARERA has 180 days (deadline approx. October 17, 2026) to define new open-season procedures for connection slots. The most stringent clause: Existing STMG connection solutions without a validated authorization title automatically lose their validity. Italia Solare and the Alleanza per il Fotovoltaico have filed an objection to this—the final discretion now lies with ARERA.
PPA Premium: Acquirente Unico will pay a 15% premium on the spread between the market price and the contract price for long-term PPAs going forward—an incentive designed to support the post-Conto Energia profitability of Italian solar farms and mitigate PUN volatility.
What does this mean for German direct investors? Three things. First: Existing plants receiving Conto Energia subsidies will be on the market for sale in 2026—repowering projects with an exit option will increasingly appear on the market by the end of September 2026. Second: The Saturazione reform is an opportunity for a clean RtB pipeline because it filters out virtual competition—and a risk for project developers without authorization titles. Third: The PPA market is politically supported, which improves the bankability of long-term power purchase agreements in Italy.
Why the residential segment is slumping: the Superbonus hangover
The decline in the residential market from 2.26 GW (2023) to approximately 1.28 GW (2025)—a 43% drop over two years—is a direct result of the phase-out of the 110% Superbonus. For several years, the 110% Superbonus was the most important incentive for the Italian residential building market and thus also the central source of financing for private rooftop PV systems; its gradual phase-out has undermined this financing. Without government subsidies and without the option of credit assignment (“cessione del credito”), small rooftop systems are less financially viable for Italian households, and replacement programs have not yet taken hold to any significant extent.
The timeline is revealing. The Superbonus was launched in 2020 with a tax credit rate of 110%, combined with a mechanism for direct tax credit transfer. By 2022, the incentive had driven the residential PV market to historic highs; more than half of all residential systems at that time were financed through the program. In February 2023, the Meloni government halted the Cessione del Credito with Decree Law 11/2023—thus removing the actual driver of growth, even though the nominal rate remained in effect until the end of 2025. In 2024, it dropped to 70%, in 2025 to 65%, and as of 2026, standalone PV has effectively reached 0% subsidy. ENEA estimates the cumulative cost to the state of the program at just under 131 billion euros as of the end of February 2026.
| Year | Aliquota | Key point | Residential Expansion |
|---|---|---|---|
| 2020 | 110 % | Start (DL 34/2020) | ~ 0.4 GW |
| 2022 | 110 % | Record year | ~ 1.1 GW |
| 2023 | 90 % | Stop the Assignment of Claims (Decree-Law 11/2023) | 2.26 GW (peak) |
| 2024 | 70 % | DL 39/2024 confirms the definitive end | ~ 1.6 GW |
| 2025 | 65 % | Cap of €48,000, max. €2,400/kWp | ~ 1.28 GW |
| 2026 | 0 % | Standalone PV systems are no longer eligible for subsidies | Q1: –13% to –16% YoY |
| Total government expenditure on the Superbonus through February 2026: approximately €131 billion (ENEA). | |||
To make matters worse, ARERA’s Resolution 78/2025, effective September 26, 2025, closed the “Scambio sul Posto” system—a form of net metering that particularly benefited smaller solar installations—to new installations. The replacement programs have not yet had a broad impact: The national “Reddito Energetico” for low-income households was exhausted within hours to days in both 2024 and 2025, and as of April 16, 2026, the 2026 call for applications has not yet been opened. Italia-Solare President Paolo Rocco Viscontini summed up the mood in the industry in February 2026 with the words:“meno benessere, meno competitività.”
The replacement program, Conto Termico 3.0, does little to ease the strain on the residential PV market either: On March 3, 2026, the GSE was forced to shut down the PortalTermico within a matter of days due to a €1.3 billion volume of applications—against an annual budget of €900 million. When it was reactivated on April 13, 2026, restrictions were in place, and the program is not open to residential-only PV projects anyway—funding is only available in combination with the replacement of air conditioning systems with electric heat pumps. The expected funding stopgap is thus still missing.
For German investors, the residential segment in Italy isn't the relevant one anyway. The data is important because it explains the headline contraction—but it says nothing about the profitability of Italy's large-scale project pipeline.
The C&I sector: caught between a wait-and-see approach and recovery
The commercial mid-range segment between 20 kW and 1 MW declined by 26% in 2025—to 1.74 GW. The main reason is not a lack of economic viability, but rather a strategic wait-and-see approach: Italian companies have postponed investments because numerous subsidy announcements were pending in the background, and PUN electricity prices normalized to around €115/MWh in 2025—which reduces the value of self-consumption compared to the crisis years of 2022/23.
Italia Solare puts it bluntly: “Such changes could result from the stop-and-go nature of the market caused by the announcement of numerous calls for proposals.” Specifically, this means: The Transizione 5.0 tax credit, the Iperammortamento under the 2026 Budget Law, and several PNRR-funded programs have prompted Italian companies to postpone investments—even if their PV projects were not directly dependent on them. These developments have noticeably dampened short-term demand from companies for commercial solar systems. Added to this are the CCI requirement for systems over 100 kW (ARERA Resolution 385/2025, approximately +15% in project costs), bottlenecks at the Italian grid operator Terna in northern Italy, and increasingly restrictive regional policies in Lombardy, Emilia-Romagna, and Veneto.
However, Q1 2026 is now showing signs of recovery—and thus a turnaround in commercial demand: installations between 20 and 200 kW grew by 32% compared to Q1 2025, while the 200 kW–1 MW segment grew by 23%. C&I in Italy is poised for a small-to-medium-sized business renaissance in 2026—driven by higher industrial electricity prices, exhausted energy efficiency levers, and the realization by many companies that waiting any longer will be more expensive than building.
Utility-scale ≥ 1 MW: the only growing segment
Utility-scale plants with a capacity of 1 MW or more grew by 15% in 2025 to reach 3.41 GW, accounting for 53% of Italy’s PV capacity additions for the first time. This growth is not driven by a single wave of subsidies, but rather by the processing of permits that had been backlogged for years and the consolidation of large project pipelines among international project developers.
The Q4 2025 phenomenon is particularly telling here: Large-scale plants over 10 MW alone accounted for 1,031 MW of new capacity in the fourth quarter—more than in the previous three quarters combined. Examples of large-scale projects that went into operation in 2024/25 or are currently under construction provide a sense of the scale and range of players involved—including several agri-PV systems. Agri-PV refers to the simultaneous use of agricultural land for solar energy generation and agricultural production, with solar modules mounted at a height or arranged vertically to allow for agricultural use beneath them.
| Project | Operator | Performance | Region | Status |
|---|---|---|---|---|
| Tarquinia Agrivoltaics | Enel Green Power | 170 MW | Lazio | In operation |
| Fénix | Iberdrola / ib vogt | 245 MW + 60 MW | Eastern Sicily | Under construction |
| Mazara del Vallo Agri-PV | Engie | 66 MWp | Sicily | In operation (PPA with Amazon) |
| Solecaldo Aidone | Edison | 41 MWp | Sicily | In operation |
| Sun Project | European Energy | 250 MWp | Sicily | Ready to Build |
| Foggia | European Energy | 103 MW | Apulia | In operation |
But the real story lies in the pipeline. As of March 31, 2026, Terna reported 3,670 PV connection applications totaling 144 GW, of which 46.49 GW have already been approved—and of that amount, only 9.34 GW are “ready-to-build” (+0.7 GW MoM). The total RES pipeline for all technologies fell to 322.67 GW as of the same date—a significant decline from the ~348 GW recorded in the summer of 2024, reflecting the ongoing cleanup of duplicate applications. Notable in the pipeline mix: Data center connection applications, totaling 82.63 GW across 480 applications, now account for the majority of consumer connection requests—Italy is becoming a battleground for hyperscaler loads, intensifying competition for grid connections among large-scale PV plants. The ratio of approved to RtB applications is thus 20%; industry insiders estimate the actual annual conversion rate from approval to commissioning to be less than 30%.
The projected solar capacity in the pipeline is therefore enormous, but the amount of solar power that can actually be generated is significantly more limited. Italy thus has a pipeline of Italian solar parks that will provide several years of construction work—but only a small fraction will actually be realized. Securing the pipeline early and maintaining a clearly documented permit status therefore become the actual value-added factors and the core of the investment strategy for institutional and private direct investors.
Added to this is a massive gap between targets and actual performance, as outlined in the updated Italian National Energy and Climate Plan (PNIEC, as of 2024): Italy has set a solar target of approximately 79 GW of cumulative solar capacity for 2030. With 43.5 GW in place by the end of 2025, this implies a required annual expansion of about 8 GW through 2030. In reality, however, only 6.4 GW was achieved in 2025. This gap is the economic driving force behind Italy’s 2026 procurement policy—and at the same time an indication that political pressure to activate the pipeline over the next 24 months is more likely to increase than decrease.
By 2025, Italy had transitioned from a feed-in tariff market to an auction and PPA market. We cover the exact mechanics of this transition—the new Italian tendering procedures, the Italian storage incentive program, and the ongoing electricity market reform—in our comprehensive market analysis on PV investment in Italy in 2026.
Sicily +81%, Lazio –39%: Italy's internal divide
Within Italy, the solar market has become drastically polarized by region in 2025: Sicily grew by +81%, Lazio fell by –39%, and Lombardy by –19%. The south is gaining ground, while the north and center are losing it—and for investors, this is not a random distribution, but rather a reflection of irradiance data, lease prices, regional policy, and the maturity of the respective project pipelines.
Sicily is the prime example: 142,000 installations, 3.53 GW of cumulative capacity by the end of 2025, and—according to CNR data—the region with the highest net PV electricity generation in the country for the first time in 2025. With full-load hours ranging between 1,450 and 1,530 kWh/kWp per year, solar yield is about 30% higher than in the Po Valley in northern Italy. Added to this are lower lease and land costs and a regional administration that—unlike some northern Italian regions—does not systematically hinder large-scale projects. Sicily’s ready-to-build pipeline currently comprises 4.17 GW across 64 projects; while Apulia leads in approved capacity with 16.78 GW, it has fewer projects in the final construction-ready stage.
| Region | Year-over-year growth in 2025 | Ready-to-Build (MW) | Relevance to investors |
|---|---|---|---|
| Sicily | + 81 % | 4.170 | Top Location 2026 |
| Basilicata | + 31 % | 490 | Southern Cluster |
| Apulia | + 24 % | 1.950 | Peak demand (16.78 GW) |
| Calabria | + 21 % | — N/A | Southern Cluster |
| Lazio | – 39 % | 1.300 | Base effect following the major wave of 2024 |
| Lombardy | – 19 % | — N/A | Restrictive regional policy |
| Emilia-Romagna | – 10 % | — N/A | Restrictive regional policy |
Lazio’s –39% is a base effect following an unusually strong wave of large-scale projects in 2024 (including Tarquinia, Montalto di Castro, and other projects). Lombardy and Emilia-Romagna, on the other hand, are suffering from an increasing number of municipal and regional restrictions: protection zones, minimum distances, and “aree non idonee” have effectively halted approvals for Italian solar parks.
In addition, a nationwide regulatory framework has been in effect since May 2024: Under Decree Law 63/2024 (“Agriculture Decree”), the construction of conventional solar power plants on fertile farmland in Italy is prohibited by law; in contrast, agri-PV systems with proven dual use remain explicitly permitted and supported. This distinction structurally shifts the growth of large-scale installations to regions with sufficient uncultivated or dual-use land—and thus clearly to the south. Northern Italy remains the more challenging market for utility-scale projects—and this is expected to remain the case in 2026 as well.
Profitability for Investors: LCOE and IRR 2026
Italian utility-scale solar plants will offer unleveraged returns of 6% to 9% in 2026—with 70% debt financing and a DSCR of 1.3, returns of 10% to 13% are achievable. Key drivers include LCOEs between €40 and €55/MWh in southern Italy, excellent full-load hours (1,450–1,530 kWh/kWp), and stable revenue streams from Italian tendering processes and long-term PPAs.
In 2026, large-scale solar plants in Italy will structurally benefit from a higher realized selling price than plants in Western European markets with a higher share of solar power in the electricity mix. We provide a comprehensive analysis of the underlying market dynamics—who actually realizes what wholesale price and why European solar markets will diverge structurally in 2026—in our article on the European solar schism. Here, we focus on the Italian investor calculation itself.
| Key figure | Italy 2026 |
|---|---|
| PUN Index GME April 2026 (Week 17) Average | €109.12/MWh |
| LCOE for Utility-Scale Projects in Southern Italy | €40–55/MWh |
| LCOE for utility-scale projects in Northern Italy (estimated) | €55–70/MWh |
| Greenfield Utility-Scale Capital Expenditures | €700–900 per kWp |
| Full-load hours in Southern Italy | 1,450–1,530 kWh/kWp |
| Full-load hours in Northern Italy | 1,000–1,150 kWh/kWp |
| Unleveraged IRR (Utility Scale) | 6–9% |
| Leveraged IRR (70/30, DSCR 1.3) | 10–13% |
| We cover the European market value comparison (Italy ↔ Germany ↔ Spain) in the Schisma Analysis; the German remuneration and market value context is addressed in our EEG Analysis 2026. | |
The key takeaway for German direct investors: Southern Italy’s LCOE is at a similar level to that of Southern Germany—but the difference in full-load hours, at around 30%, acts as a structural return lever. If you compare a 50-MW project in Sicily with a comparable project in Bavaria, the LCOE is nearly identical—but the annual yield per installed kWp is significantly higher. This difference is the key factor for the location strategy of German investors with exposure to Italy and for the return forecast over a 20- to 25-year term.
The PUN remains volatile in 2026: In March 2026, it jumped to €143.40/MWh, and in April it fell to intraday lows of €89/MWh. This volatility is not merely market noise but structural—the concentration of solar production during midday hours is increasingly generating negative or near-zero prices, particularly in southern Italy. This is precisely why the PPA premium described in the 'DL Bollette 21/2026' section is strategically more valuable for investors with exposure to Italy in 2026 than any choice of subsidy: It stabilizes effective revenue and makes cash flow bankable.
On the module procurement front, the tide turned in the first quarter of 2026. After hitting a low in December 2025, module prices rose noticeably by April 2026—driven by Chinese tax policy and higher polysilicon prices. For Italian direct investors with fixed EPC contracts from the second half of 2025, this price rebound represents a structural margin advantage; for projects starting later, it’s important to keep a close eye on the market and secure EPC terms early.
The five most significant risks from an investor's perspective
Italy in 2026 is an attractive market, but not without its challenges: political risk, permit processing times, market price risk, curtailment, and refinancing are the five key issues that a direct investor with exposure to Italy must understand and have carefully addressed. None of these is a deal-breaker—but all have specific mitigation strategies that must be factored into the investment strategy.
| Risk | Severe | Mitigant |
|---|---|---|
| Political Risk — DL Bollette 21/2026 (now Law 49/2026) introduces Spalma incentives with a deadline of May 31, 2026, and the Virtual Saturation reform (for details, see the article on the significance of the Bollette Decree) | high | CfD hedge via an Italian tender process; selective pipeline selection |
| Permitting/construction timeline risk — Permitting process duration > 4 years, 144 GW connection queue | high | Focus on the ready-to-build pipeline; securing land and permits at an early stage |
| Market price risk — Concentration of solar generation during midday hours, spread erosion | medium | 10–20-Year PPA Hedge · Co-located BESS · 20-Year CfD |
| Curtailment — Aurora forecasts a sixfold increase by 2030 compared to 338 GWh in 2024 | medium | Co-located BESS · Italian Storage Toll Program |
| Refinancing — ECB key interest rate at 2.5%, high volume of Italian capital expenditure allocations in 2026 | medium | 20-year CfD = bankable; conservative DSCR structuring |
In the spring of 2026, political risk took concrete form with an Italian electricity price reform package—among other things, Italy intervened in the cost pass-through for gas-fired power plants and sparked a debate over retroactive subsidy cuts for existing facilities. We’ve broken down what this means in detail for PV investors in a separate article on the significance of the Decreto Bollette.
It suffices to note here that Italy has introduced four structural changes to the solar energy market over the past 36 months: the end of the Cessione del Credito program in February 2023, the expiration of the Superbonus, the closure of the Scambio sul Posto program in September 2025, and the mandatory CCI requirement for systems 100 kW and above. For the forecast over the next 12 months, this means: Distributed PV solar energy carries significant retroactive policy risk, while large Italian plants with CfD hedges are largely protected from this—especially if the underlying storage and tracking technologies are properly sized and the installed capacity continues to generate its model return even under curtailment pressure.
A Look at Germany: The Same Pattern
In the European rankings, Italy will also have ceded second place to France by 2025 (SolarPower Europe, EU Market Outlook 2025–2030, published December 11, 2025)—a sign that must be taken seriously in the context of the PNIEC gap. With 43.5 GW by the end of 2025, approximately 36 GW still remains to be added to reach the 2030 target of 79 GW; on its current trajectory, Italy will fall significantly short of this target, which increases political pressure to activate the pipeline over the next 24 months.
In 2025, Germany will exhibit exactly the same structural pattern as Italy: residential installations will decline, utility-scale projects will grow, and ground-mounted installations will surpass rooftop installations for the first time. The economic difference between the two markets—specifically, which market achieves what wholesale price—is a story in itself and is explored in our Schisma analysis.
In 2025, Germany will exhibit the same structural pattern as Italy: residential installations will decline, utility-scale installations will grow, and solar power will reach a historic turning point in the electricity mix for the first time. We analyze the detailed mechanics of this turning point in Germany’s electricity mix—how much PV surpassed which fossil fuel generators for the first time in 2025 and what consequences this has for the German electricity market—in our article on Photovoltaics vs. Lignite in 2025.
The German feed-in tariff will reach a historic low in 2026 and will drop once again on August 1, 2026—our analysis of the 2026 feed-in tariff examines the structural implications for German PV investors, our direct marketing overview covers the mechanics of German direct marketing, and our electricity price comparison between Italy, Germany, and European markets is covered in the Schisma article.
For German direct investors, the lesson is not “Italy instead of Germany.” Rather, by 2026, both countries will be focusing on large-scale solar power plants with secure revenue streams—and Italy additionally offers the structurally higher solar yield of southern Italy, thereby providing a different leverage effect in the Italian solar energy market. Installed solar capacity per capita in Southern Italy has now reached a level that is becoming structurally relevant even for German companies with ties to Italy, because the market size of the Southern Italian solar energy value chain is set to grow substantially over the next 24 months.
Are you wondering how a specific direct investment in an Italian or German solar power plant would be structured? On our overview page for solarpower investments,you’ll find the return parameters, the investment model, and the tax benefits available to German investors with a minimum investment of €100,000. Learn more about PV investments now →
Conclusion: A shrinking market, a growing investor segment
Italy’s solar market will shrink in 2025 for the first time in five years—but the decline is uneven. What is shrinking are government-subsidized residential systems and the wait-and-see commercial mid-market; what is growing are large-scale Italian systems of 1 MW or more in southern Italy, driven by long-term power purchase agreements and the gradual clearing of the permitting backlog. In the context of Europe and the investment strategy of German direct investors, this is a clearer—not a worse—market situation than during the boom years of 2022/23: The wheat is separating from the chaff, and the wheat—the ready-to-build pipeline in Sicily, Apulia, and Basilicata with awarded contracts or PPA hedges—is, with careful selection, economically better positioned in 2026 than the Italian mid-tier projects of previous years.
Two key takeaways: First, the headline figure of –5% is misleading—the relevant investor segment is growing by +15%. Second, the barrier to entry isn’t market size, but pipeline maturity: Companies that are active in Italy by 2026 will secure Approved or, better yet, RtB status—not just preliminary inquiries.
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Disclaimer: This article is intended solely for general informational purposes and does not constitute investment, tax, or legal advice. Return figures (6–10% p.a. on an unleveraged basis, up to 10–12% p.a. with tax leverage in Germany; 6–9% unleveraged / 10–13% leveraged in Italy utility-scale) are based on portfolio data from the Helm Group as well as public industry analyses for 2024–2026 and are not a guarantee of future returns. For your individual situation, please consult a licensed financial or tax advisor. As of May 2026.
The market is becoming more professional—project planning, securing land, and financing are key factors in determining returns. Logic Energy supports you from the very beginning.What utility-scale projects in Germany mean for investors: An overview of PV investment →
FAQ
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Italy's solar market is projected to shrink by 5% in 2025 to 6.4 GW of new capacity, as the residential segment slumped by about 32% due to the expiration of the 110% Superbonus, and the commercial mid-market segment declined by 26% due to announcements of new incentives and the normalization of the PUN system. Utility-scale projects (≥ 1 MW), on the other hand, grew by 15%.
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The growth segment is utility-scale projects starting at 1 MW: +15% to 3.41 GW by 2025, representing a 53% market share. Q1 2026 also shows a strong recovery in the mid-scale segment (1–10 MW) (+42% YoY). Large-scale Italian projects in 2026 will be driven by approved permits, Italian procurement procedures, and PPA structures.
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Regions in southern Italy—particularly Sicily (+81% capacity growth, 4.17 GW in the RtB pipeline), Apulia (16.78 GW approved), and Basilicata—offer the best combination of solar yield (1,450–1,530 kWh/kWp), pipeline maturity, and lower lease and land costs. Northern Italy is significantly more restrictive from a regulatory standpoint.
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The industry consensus is for unleveraged IRRs of 6% to 9% for well-structured utility-scale projects; with 70% debt and a DSCR of 1.3, returns of 10% to 13% are possible. Key drivers include an LCOE of €40–55/MWh in southern Italy, high full-load hours, and stable revenue bases from Italian tendering processes and long-term PPAs (Pexapark, Lighthief).
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Standalone PV will no longer be eligible for the Superbonus starting in 2026 (110% → 0% over five years). Direct effect: The residential market is shrinking. This is irrelevant for direct investors in large-scale projects—utility-scale projects do not depend on the Superbonus, but rather on Italian auction-based CFDs, PPAs, and spot market revenues. Indirectly, however, this is causing distortions in the Italian installation market.
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The Decreto Bollette (now Law 49/2026), which took effect in April 2026, includes three measures: Spalma-incentivi 2.0 requires existing Conto Energia plants to choose a subsidy option by May 31, 2026 (tariff reduction or exit in exchange for 90% NPV of remaining cash flows, max. 10 GW); the Saturazione Virtuale reform streamlines the connection pipeline through the automatic expiration of non-validated STMG solutions; and a 15% PPA Bacheca premium on the spread supports long-term power purchase agreements.
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As of March 31, 2026, Terna reported 144 GW in connection applications, 46.49 GW approved, and 9.34 GW ready-to-build. The actual conversion rate from "Approved" to "Commissioned" is less than 30%, making pipeline maturity and early securing key factors in value creation.
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Structurally similar: both countries are seeing a decline in residential demand and growth in utility-scale demand. The economic difference lies in the realized wholesale price per MWh generated, which varies significantly across European markets. We cover this comparison in full in our Schisma analysis of the European solar market.
Sources
Italia Solare — Photovoltaics 2025: First Decline Since 2020 (February 7, 2026)
QualEnergia — Italian photovoltaic capacity installed by the end of 2025: 43.5 GW
Solare B2B — Fotovoltaico Italia: 1,439 MW connected in Q1 2026 (April 14, 2026)
PV Tech — Italy Installed 1.4 GW of Solar PV in Q1 2026 (April 17, 2026)
pv magazine — Italy: PV grid connection requests reach 144 GW (April 16, 2026)
Italian Revenue Agency — 110% Superbonus Information Page
ENEA — Superbonus Data, Status as of February 2026 (Total cost: €131 billion)
Pexapark Q1 2026 PPA Market Update — Italian PPA Price Levels in 2026
Lighthief 2026 / Industry Indicators: IRR for Utility-Scale Projects in Italy
IRENA — Renewable Power Generation Costs (LCOE Benchmarks)
Logic Energy / mediplan Helm e. K. — Internal Project Cost Estimates 2026
pv magazine Italia — Terna Pipeline as of March 31, 2026: 144 GW of PV, 9.34 GW Ready-to-Build (April 15, 2026)
Solar B2B — Q1 2026 Detailed Segment Data (April 14, 2026)
Law No. 49/2026 of April 10, 2026 (Official Gazette No. 90/2026) — Conversion of Decree-Law No. 21/2026
ANIE Federation — FER 2025 Observatory: –8.2% total capacity growth (March 19, 2026)
SolarPower Europe — EU Market Outlook 2025–2030 (December 11, 2025)
