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Pourquoi les modules de tuiles solaires sont avant tout des produits de construction, et ensuite des produits photovoltaïques.

Tuiles solaires pour toitures résidentielles
Les décisions qui déterminent la performance d'une tuile photovoltaïque intégrée au bâtiment (BIPV) pendant 30 ans sont prises dès les premières discussions de conception : technologie des cellules, spécifications du verre, encapsulant, emplacement de la boîte de jonction. Toute erreur à ce niveau peut s'avérer coûteuse à corriger une fois l'outillage finalisé. L'équipe d'ingénierie de Couleenergy accompagne les acheteurs depuis les premiers plans jusqu'à la production en série, en passant par le prototypage.

Solar roof tile modules are not simply small solar panels with a different shape. They are building products first, photovoltaic devices second. Every design decision — from cell architecture to edge sealing — must satisfy roofing performance requirements at the same time as electrical output targets. That is a very different engineering challenge from producing a standard rack-mounted module.

This guide is written for buyers, engineers, project developers and OEM clients who need practical, decision-ready information. We cover the full design stack: cell technology, module size, glass construction, encapsulant selection, junction box engineering, electrical design and certification. Where the field has evolved, we say so clearly. Where trade-offs are real, we name them.

What Makes a Solar Roof Tile Module Different

Conventional solar panels sit on top of a building. Solar roof tile modules become the building. That changes everything.

A BIPV roof tile must generate electricity, shed water, resist wind and snow, comply with fire regulations, and look like a premium roofing material — all for 25 to 30 years. IEC 63092 formalises this dual identity by treating BIPV modules as photovoltaic products that are simultaneously construction products, with separate requirements for the module level (Part 1) and the system integration level (Part 2).[1]

This means the designer cannot optimise only for watts. The roof tile must also be safe, durable and certifiable as a building component. Many first-time BIPV buyers underestimate this scope, and it is the most common reason projects stall.

Choosing the Right Cell Technology

Cell technology is the single most impactful decision in a roof tile module’s design. It determines efficiency, appearance, shade behaviour, manufacturing complexity and ultimately the product’s market positioning.

PERC: A Legacy Option for Budget-Driven Projects

PERC (Passivated Emitter Rear Contact) cells were the dominant global PV technology from 2017 to 2023. For buyers developing new BIPV roof tile products today, however, PERC comes with an important caveat: availability is tightening. Major manufacturers — LONGi, JinkoSolar, Trina Solar — have been actively phasing out PERC production lines since 2024, when TOPCon surpassed PERC as the world’s leading cell technology by volume for the first time. PERC’s global shipped module share fell from around 63% in 2023 to approximately 40–43% by 2024, and the decline is accelerating.[2]

Where PERC does make sense is for cost-sensitive projects with non-premium aesthetics requirements, or where existing cell inventory makes it viable. Commercial monocrystalline PERC module efficiency sits in the 20–22% range. Front-side busbars and ribbons are visible through the front glass — a significant aesthetic limitation for premium BIPV work. For new BIPV tile product development, most informed buyers will look beyond PERC at the outset.

TOPCon: The Current Volume Standard

N-type TOPCon (Tunnel Oxide Passivated Contact) is the dominant technology choice for mainstream solar roof tile production today. TOPCon’s market share exceeded that of PERC for the first time in 2024 and is projected to remain the leading c-Si architecture through the early 2030s.[2] Commercial module efficiency now spans 22–24.5%, with leading-generation products from premium manufacturers pushing the upper bound beyond where the technology stood just two years ago.[3] TOPCon also offers a better temperature coefficient than older P-type platforms — typically around −0.29 to −0.30%/°C — which is meaningful for south-facing roof surfaces that heat up significantly in summer.

TOPCon cells carry front-side metallisation, so they are not ideal for premium all-black aesthetics. For most residential and commercial BIPV applications, however, they represent an excellent balance of performance, availability and unit economics.

HJT: Premium Performance for Demanding Climates

Heterojunction Technology (HJT) combines crystalline silicon with amorphous thin-film layers to deliver outstanding performance in difficult conditions. At the module level, HJT mass-production efficiency now ranges from 22% for standard products to 24.5% for leading-edge products such as the Huasun Himalaya 760 HV, which delivers 760 W and 24.5% module efficiency.[4] Cell-level mass-production efficiency is higher, ranging from 24% to 26.5% for advanced producers.

HJT’s strongest advantages are its temperature coefficient (typically −0.24 to −0.26%/°C, the lowest of any commercial silicon architecture) and its bifaciality factor, which regularly exceeds 90% — compared to approximately 80–85% for TOPCon.[5] Both matter for rooftop applications: a lower temperature coefficient means output degrades less on hot summer days, and high bifaciality allows rear-surface light capture from light-coloured roof substrates.

The trade-off is manufacturing cost. HJT requires low-temperature silver pastes and more complex deposition processes than TOPCon. For premium BIPV projects in hot climates, where performance guarantees drive specification, HJT is a compelling choice. For mainstream volume production, the cost premium relative to TOPCon remains a real constraint.

Back-Contact Cells: The Best Fit for Premium Roof Tiles

Back-contact technologies — IBC (Interdigitated Back Contact), ABC (All Back Contact) and HPBC 2.0 — move all electrical contacts to the rear surface of the cell. No busbars. No ribbon lines. No front-side metallisation of any kind.

For solar roof tiles, this matters enormously. A back-contact cell produces a perfectly smooth, uniform black surface. This is not just aesthetically superior — it enables coloured and patterned glass layers to be applied over the cell without any interruption, making true architectural integration possible. It also eliminates front-surface shading losses from ribbon interconnects, contributing to higher effective power density in compact tile formats.

HPBC 2.0 (LONGi’s Hybrid Passivated Back Contact platform) achieves commercial module efficiency of 24.8% in mass production, with the Hi-MO X10 delivering up to 670 W.[6] The same platform holds the independently certified world record for crystalline silicon module efficiency at 25.4%, verified by the Fraunhofer Institute for Solar Energy Systems (Fraunhofer ISE) in Germany and confirmed on the NREL Champion Module Efficiency chart.[7] AIKO’s ABC Gen 3 (Neostar 3P series) achieves module efficiency at or above 25% — the first commercial silicon module format to cross that threshold at mass-production scale.[8]

These are meaningful numbers for compact roof tiles where every square centimetre of active area must work as hard as possible.

The honest trade-off: back-contact cells cost more and require more precise manufacturing than TOPCon. For high-end residential, heritage and architectural BIPV projects, that premium is well justified. For cost-driven projects with straightforward rooflines, TOPCon is the more practical answer.

A Note on CIGS Thin Film

CIGS (Copper Indium Gallium Selenide) thin-film cells offer flexibility that crystalline silicon cannot match. This makes them relevant for curved or non-planar tile profiles that rigid glass-glass laminates cannot accommodate. Efficiency is lower — typically 14–18% in BIPV applications — and power density is constrained. CIGS is a niche choice, but for complex roof geometries it is often the only viable path.

Cell Technology at a Glance

Technologie Efficacité du module
(Mass Production)		 Front Appearance Meilleure application
PERC (type P) 20–22% Busbars visible Budget-driven tiles; inventory-clearing projects
TOPCon (type N) 22–24.5% Busbars visible Mainstream residential and commercial tiles
HJT 22–24.5% Busbars visible Premium tiles; hot climates; long-warranty projects
HPBC 2.0 / ABC Gen 3 24.8–25%+ Pas de barres omnibus avant Premium all-black, architectural, colour BIPV tiles
CIGS thin film 14–18% Dark, flexible Curved and non-planar roof profiles

All figures reflect mass-production module efficiency. Cell-level efficiency is consistently higher due to inactive module area, interconnection losses and encapsulant absorption.

Module Size: Match the Roof System, Not Just the Cell Layout

Solar roof tiles come in many sizes. The most common production formats range from around 400 × 360 mm for small interlocking tiles up to 1,260 × 480 mm for larger format BIPV panels that still mimic traditional roofing.

Choosing the right module size is more subtle than it appears.

Small tiles (roughly 400–600 mm) offer genuine roofing integration. They interlock naturally with conventional clay or slate tiles and satisfy local planning regulations that require new roofs to match the character of existing streetscapes. They are also easier to handle during installation and simpler to replace if damaged.

The trade-off: more pieces per roof means more electrical connections, more junction boxes, more cable joints, and proportionally higher installation labour. Per-watt cost is typically higher for small tiles than large formats.

Larger format tiles (600–1,300 mm) reduce the number of connections and speed up installation. Cost per watt improves. But larger glass units require more structural care: wind and snow load calculations become more demanding, edge protection during transit matters more, and roof flatness tolerances are tighter.

⚠ Key Practitioner Insight

The optimal tile size is not determined by the PV laminate alone. It is set by the combination of tile overlap, batten spacing, cell layout, junction box clearance and local installation habits. A roof tile that is beautifully designed as a PV laminate can fail as a roofing product if the junction box sits where a roof batten runs.

Start with a complete drawing of the roofing system. Work backwards to the module size from there.

Tuiles solaires de toiture double vitrage entièrement noires, panneaux solaires à contact arrière personnalisés, production OEM/ODM
Dual-glass full black back contact (BC) PV modules, inquiry@couleenergy.com

Glass Construction: Why Dual-Glass Is Usually Not Optional

Most BIPV roof tile modules use a dual-glass (glass-glass) construction. This is not a premium upgrade — it is typically a technical requirement for the application.

A standard PV module uses a polymer backsheet. That backsheet cannot function as a roofing material. It does not shed water as effectively, does not achieve the fire resistance ratings that building codes require, and does not provide the structural rigidity that a roof tile needs when walked on during installation or maintenance.

Four Key Advantages of Dual-Glass Construction

Résistance à l'humidité

A glass-glass laminate with proper edge sealing creates a far more effective moisture barrier than a polymer backsheet. Moisture ingress accelerates delamination, cell corrosion and insulation failure.

Fire Performance

Glass does not burn. Glass-glass modules can achieve Class A fire ratings required under UL 790 / ASTM E108 for roofing applications in most markets.[11]

Structural Stability

The rigid glass sandwich maintains dimensional stability better under thermal cycling and mechanical load than single-glass constructions. For tiles at roof pitch angles with sustained wind loading, this matters through decades of service.

Long-Term Lifespan

Well-manufactured dual-glass modules with appropriate encapsulants are designed for service lives of 30 years or more with less than 20% power degradation — aligning with quality roof installation expectations.

Glass Specifications That Matter

For the front (top) glass: low-iron tempered solar glass with an anti-reflective (AR) coating is standard. AR coating raises light transmittance above 93%. Iron content should be 0.02% or below to maximise transparency. Thickness typically ranges from 2.5 mm to 3.2 mm, depending on tile size and structural requirements.

For the rear (back) glass: standard tempered glass without AR coating. Using thinner rear glass (2.0 mm vs 3.2 mm) is a common weight-reduction approach that does not materially compromise performance.

Pour curved tiles: hot-bent tempered glass or flexible thin glass below 1.5 mm enables non-planar profiles, though production complexity and cost increase substantially.

Glass edges on roof tiles should be seamed and chamfered to eliminate micro-cracks. These micro-cracks can propagate under repeated thermal cycling — a serious concern in a product expected to survive 30 years of rooftop temperature swings.

Encapsulant Selection: A Reliability Decision, Not a Commodity Choice

In a glass-glass roof tile module, encapsulant choice carries more weight than many buyers appreciate. The standard encapsulant across the wider PV industry is EVA (Ethylene Vinyl Acetate). EVA is low-cost and has a long track record in single-glass modules with polymer backsheets.

The problem with EVA in glass-glass structures is acetic acid release. As EVA degrades over time, it releases acetic acid. In a single-glass module with a backsheet, that acid diffuses out. In a sealed glass-glass structure, it has nowhere to go. It accumulates, corrodes cell metallisation and drives delamination. Independent durability testing by SoliTek found that glass-backsheet EVA modules showed degradation of −7.90% after 2,500 hours under damp heat, while glass-glass POE modules showed only −3.50% degradation after 3,500 hours under the same conditions.[9]

Recommended Specification for Glass-Glass Roof Tiles

Utiliser POE (Polyolefin Elastomer) or EPE (EVA-POE-EVA). POE produces no acetic acid, offers superior moisture resistance and provides excellent resistance to potential-induced degradation (PID). EPE combines POE’s barrier properties with the established adhesion of EVA outer layers.

Two important qualifications: first, for HJT and back-contact cells specifically, the fine metallisation structures are more moisture-sensitive, making POE virtually mandatory. Second, POE quality varies meaningfully between suppliers. Research from the University of New South Wales (January 2026) found that some lower-quality POE formulations can cause metallisation corrosion in TOPCon modules under extended damp heat conditions.[10] Specify POE or EPE from established, tier-1 encapsulant suppliers — this is not an area to compromise on procurement cost.

Junction Box Design: Where Many Projects Run Into Trouble

The junction box is often the last component buyers think about and one of the first to cause problems during installation or long-term service. For solar roof tiles, junction box design deserves early and detailed attention.

The fundamental challenge: a roof tile junction box must be low-profile, because it sits between the tile and the roof structure. It must be fully weatherproof, because it will face decades of rain and temperature cycling. It must be positioned correctly, because roof battens, overlap zones and cable routing paths leave very little room for error.

IP Rating

Roof tile junction boxes should carry at minimum IP67 certification, with IP68 preferred. IP68 means the enclosure can withstand continuous water immersion beyond 1 metre depth. Roof valleys, snow accumulation zones and areas subject to pressure washing create exactly these conditions over a 25 to 30-year service life. Silicone potting of the junction box cavity is the standard mechanism for achieving sustained IP68 performance.

Placement Questions to Resolve Before Design Is Locked

Before the first prototype is made, these questions should be answered definitively:

  • →Where does the tile overlap? The junction box cannot sit in the overlap zone.
  • →Where do the roof battens run? The box cannot conflict with batten positions.
  • →What is the maximum allowable height under the tile? Standard clearances are tighter than most first-time BIPV designers expect.
  • →Do cables exit vertically or horizontally? Horizontal exit reduces box height but requires lateral clearance.
  • →Will the junction box be accessible after installation? If not, the quality and reliability standard must be substantially higher.
  • →How will cables route from tile to tile without creating water ingress points?

Diodes de dérivation

Bypass diodes protect shaded cells from reverse-bias heating and hotspot formation. For most roof tile module configurations, at least one bypass diode per tile is required. The specific configuration — number of diodes, current rating, thermal dissipation — depends on cell count, string layout and the level of shading risk on the target roof.

One important circuit design note: shingle-interconnected tiles using a series-parallel matrix cell topology can reduce bypass diode dependence, because the matrix architecture allows current to flow around shaded cells without triggering a bypass path. This meaningfully improves partial-shade performance compared to conventional bypass-diode-only configurations.

Junction Box for Premium Glass-on-glass Solar Panels

Electrical Design: Think String First, Tile Second

Individual roof tiles produce modest voltages — typically 5 to 15 V per tile depending on cell count, interconnection method and tile format. The real electrical design challenge is at the string and system level.

Tiles are wired in series to reach the MPPT input range of the connected inverter or optimiser. The cumulative voltage of the string must stay within the system’s maximum voltage limits — 1,000 V for most IEC-governed markets, with tighter limits in some North American jurisdictions.

Roof shading complicates string design significantly. Chimneys, dormers, antennas, adjacent structures and seasonal shadow angles can affect individual tiles at different times. Three main approaches address this:

Diodes de dérivation

Provide baseline hotspot protection but do not recover output from shaded tiles — they simply disconnect them temporarily from the string.

Électronique de puissance au niveau du module (MLPE)

Microinverters or DC power optimisers at each tile or small group allow each unit to operate at its own maximum power point, recovering energy that bypass-diode-only designs would lose. The trade-off is added system cost and complexity.

Matrix Shingle Interconnection Topology

Distributes current paths across the cell array so that localised shading affects a smaller effective area, improving shade tolerance without additional power electronics.

For most residential BIPV projects with moderate shading complexity, a well-designed string layout with MLPE at the tile or group level is a practical and cost-effective solution.

Certification Requirements: Plan Early, Not After Tooling

BIPV roof tile modules face a more complex certification landscape than standard PV panels. They must simultaneously satisfy PV module standards and building product requirements. The exact combination depends on the target market.

Standard Scope
CEI 61215PV module design qualification and type approval
CEI 61730PV module safety qualification
IEC 63092-1 [1]BIPV module requirements as building products (international)
IEC 63092-2BIPV system integration requirements (international)
EN 50583-1 [12]BIPV module requirements (European; CPR 305/2011 for CE marking)
EN 50583-2BIPV system requirements (European)
UL 790 / ASTM E108 [11]Class A fire resistance for roof coverings (US market)
UL 61730US PV module safety equivalent
EN 13956Flexible sheet waterproofing (relevant for certain EU integrated tile designs)

Note on EN 50583 vs IEC 63092

EN 50583 is the European BIPV standard and directly informed IEC 63092 — the IEC standard’s own text states it “is based on EN 50583-1.” For CE marking under the EU Construction Products Regulation (CPR 305/2011), EN 50583-1 is the applicable standard in European markets.[12] Buyers targeting European distribution should confirm compliance with EN 50583, not only IEC 63092.

Certification requirements should be defined at the start of the project, not after tooling is complete. Glass tempering is permanent — holes and cut-outs cannot be added after the fact. If a structural test later requires a different fixing point, the glass tooling must be redesigned from scratch. That is an expensive and time-consuming lesson.

A Practical Design Checklist for Buyers

Before requesting a quotation or entering detailed engineering discussions, prepare the following:

Mechanical Information

  • Outer module dimensions
  • Visible active area dimensions
  • Overlap zone dimensions
  • Thickness and weight limits
  • Hole positions and sizes (if any)
  • Corner radius requirement
  • Roof fixing method
  • CAD drawing or 3D file if available

Electrical Targets

  • Target wattage per tile
  • Target voltage and current range
  • préférence pour la technologie cellulaire
  • Type de connecteur
  • Junction box position preference
  • Bypass diode requirement
  • System voltage limit
  • Inverter or optimiser compatibility

Matériels

  • Single glass or dual-glass
  • Glass thickness preference
  • All-black, coloured or transparent rear glass
  • Encapsulant preference (POE or EPE for glass-glass)
  • Frame or frameless

Market & Certification

  • Target country and applicable standards
  • Fire class requirement (Class A for most residential)
  • Wind and snow load parameters
  • Warranty expectation
  • Annual volume
  • Sample and pilot batch quantity

Points clés à retenir

  • ✓Solar roof tile modules are building products first. Every design decision must satisfy both roofing and electrical performance requirements simultaneously.[1]
  • ✓Back-contact cells (HPBC 2.0, ABC Gen 3) deliver the cleanest all-black aesthetics, the highest power density and the world-record certified module efficiency of 25.4% (HPBC 2.0, Fraunhofer ISE).[7] TOPCon offers a strong volume-production balance at up to 24.5% module efficiency.[3]
  • ✓PERC is a declining technology with tightening supply.[2] New BIPV tile development projects should default to TOPCon or back-contact from the outset.
  • ✓Dual-glass construction is the correct architecture for most BIPV roof tile applications. It provides better moisture resistance, fire performance and long-term dimensional stability than single-glass designs.
  • ✓Specify POE or EPE encapsulants in glass-glass laminates — from established tier-1 suppliers. EVA’s acetic acid release is a documented long-term reliability risk in sealed glass-glass structures.[9]
  • ✓The junction box is a critical design element. Placement, height, IP rating and cable routing must all be resolved before tooling — not after.
  • ✓Module size should be driven by the roofing system architecture, not by cell layout convenience alone.
  • ✓For European markets, confirm compliance with EN 50583-1, not only IEC 63092-1, for CE marking under CPR 305/2011.[12]
  • ✓Define certification targets at project start. Retrofit compliance after glass tooling is locked is expensive and time-consuming.

Questions fréquemment posées

What is the difference between a solar roof tile module and a standard solar panel?

A standard solar panel is mounted on top of a building structure. A solar roof tile module replaces part of the roof itself. It must therefore satisfy roofing requirements — waterproofing, fire safety, mechanical load, aesthetics — as well as electrical performance requirements. The design process and certification path are both considerably more complex.[1]

Which cell technology is best for solar roof tiles?

For premium all-black or architectural tiles, back-contact cells (IBC, ABC Gen 3, HPBC 2.0) are the strongest choice: they eliminate front-side busbars and deliver the highest module efficiency on the market.[6][7][8] For mainstream volume projects where cost and supply are primary considerations, N-type TOPCon offers a proven balance of performance and availability.[2][3] PERC is a declining option, appropriate mainly for very budget-constrained projects drawing on existing cell inventory.

Why do most solar roof tile modules use dual-glass construction?

Dual-glass construction replaces the polymer backsheet with a second layer of tempered glass. This improves moisture resistance, fire performance, structural rigidity and long-term lifespan — all of which matter more in a roofing application than in a standard rack-mounted installation. Most BIPV certifications, including IEC 63092-1 and EN 50583-1, are designed with glass-glass construction in mind.[1][12]

What IP rating should a solar roof tile junction box carry?

IP67 is the minimum for outdoor roofing applications. IP68 is preferred, as roof surfaces experience conditions — pooling water, snow melt, high-pressure cleaning — that can exceed IP67 test parameters over a 25 to 30-year service life. Silicone potting of the junction box cavity is the standard method for achieving IP68 reliability.

Can back-contact cells work in small tile modules?

Yes — and they are particularly well-suited to compact formats. Because back-contact cells deliver higher efficiency per unit area, they generate more watts from the limited active area available in small tiles.[6][8] Cell layout and string design require careful engineering, but this is standard practice for manufacturers with BC experience.

Work with a Team That Knows Both Sides

Designing a solar roof tile module that performs on the roof and in the market requires deep knowledge of both PV engineering and building integration. The design decisions described in this guide interact with each other. A cell technology choice affects the encapsulant requirement. The junction box position affects cable routing and the installation workflow. The glass specification affects weight, which affects the structural load calculation.

Getting these interactions right from the start saves significant time, tooling cost and testing expense.

Couleenergy specialises in back-contact and high-efficiency module development for BIPV, custom and OEM applications. Our engineering team works with buyers and developers from initial concept through prototype, pilot production and volume scale-up.

For project-specific guidance — including cell technology selection, module specification, roofing system coordination and certification planning — contact us directly.

We put engineers, not just sales teams, on the first call.

Couleenergy (Ningbo Coulee Tech Co., Ltd.) is a Zhejiang-based B2B manufacturer specialising in back-contact flexible and rigid modules, BIPV solutions, and custom OEM configurations for European and North American markets.

Références et notes de bas de page

[1] IEC 63092-1:2020 — Photovoltaics in buildings, Part 1: Requirements for building-integrated photovoltaic modules. Defines BIPV modules as PV products that simultaneously function as building products, with electrotechnical and building performance requirements. Part 2 (IEC 63092-2) covers system-level integration requirements.

https://webstore.iec.ch/en/publication/32158

[2] ITRPV 16th Edition — International Technology Roadmap for Photovoltaics (VDMA, April 2025). Confirms TOPCon surpassed PERC as the leading c-Si cell technology in 2024, with n-type wafers reaching 70% market share. Projects TOPCon dominance through the early 2030s.

https://vdma.eu/en/viewer/-/v2article/render/143159365

[3] Clean Energy Reviews — Most Efficient Solar Panels 2026 (March 2026). Annual ranking of commercial module efficiency by technology. Notes “increasingly optimised N-type TOPCon platforms exceeding 24%” and a “growing divide” between premium BC modules and advanced TOPCon products.

https://www.cleanenergyreviews.info/blog/most-efficient-solar-panels

[4] Huasun Energy press release — Himalaya 760 HV HJT module (November 2025). Introduces Huasun’s 760 W HJT module at 24.5% module efficiency with 2,000 V system voltage. As of publication, the highest-efficiency commercially available HJT module from a volume manufacturer.

https://www.prnewswire.com/news-releases/huasun-energy-launches-760-w-heterojunction-solar-module-with-2000-v-system-voltage-302627830.html

[5] The Green Watt — HJT Solar Panels: Efficiency, Temperature Coefficient, and Manufacturers (April 2026). Confirms commercial HJT cells at 24–26% cell efficiency; module efficiency at 22–24%; bifaciality factor 90–95%; temperature coefficient approximately −0.26%/°C. Discusses cell-to-module efficiency gap.

https://www.thegreenwatt.com/hjt/

[6] LONGi — Hi-MO X10 HPBC 2.0 module launch (February 2025). Confirms 24.8% mass-production module efficiency and 670 W maximum output for the Hi-MO X10 series, based on HPBC 2.0 back-contact cell technology using TaiRay N-type wafers.

https://www.longi.com/eu/news/hi-mo-x10-launch-italy/

[7] LONGi — World Record Crystalline Silicon Module Efficiency press release (October 2024). Announces Fraunhofer ISE (Germany) certification of 25.4% module efficiency for the HPBC 2.0 platform — the first time a Chinese manufacturer has held this record since 1988. Also confirmed on the NREL Champion Module Efficiency chart.

https://www.longi.com/us/news/2024-longi-new-world-record-crystalline-silicon-module-efficiency/

[8] PV Magazine — AIKO launches 545 W back-contact module with 25% efficiency (March 2026). Confirms AIKO’s ABC Gen 3 (Neostar 3P) achieves module efficiency above 25% in a 1,954 × 1,134 mm format, using a grid-free front surface and zero-gap cell layout.

https://www.pv-magazine.com/2026/03/11/aiko-launches-545-w-back-contact-solar-module-with-25-efficiency/

[9] SoliTek — EVA vs POE module durability research (manufacturer-conducted accelerated ageing tests). Extended damp-heat testing (85°C / 85% RH, beyond IEC 61215’s 1,000-hour minimum) showed glass-backsheet EVA modules degraded −7.90% after 2,500 hours, while glass-glass POE modules degraded only −3.50% after 3,500 hours. These findings are independently corroborated by peer-reviewed research (NCBI/Progress in Photovoltaics) confirming POE limits ionic migration and outperforms EVA in glass-glass damp-heat conditions. Primary source:

https://www.solitek.eu/en/news/soliteks-research-uncovers-groundbreaking-results
Secondary / editorial coverage: https://www.pveurope.eu/solar-modules/solar-modules-poe-encapsulated-pv-modules-particularly-durable

[10] PV-Tech / University of New South Wales — Solar module encapsulant materials and quality of construction affect damp heat performance (January 2026). UNSW research found that certain POE formulations can cause metallisation corrosion in TOPCon modules under extended damp heat conditions, underscoring the importance of encapsulant supplier quality.

https://www.pv-tech.org/unsw-solar-module-encapsulant-materials-quality-construction-affect-damp-heat-performance/

[11] Carlisle SynTec — UL Fire Classifications for Roofs: Class A, B, and C. Explains UL 790 / ASTM E108 as the standard test method for roof covering fire resistance; Class A represents the highest (severe) rating. Required under the International Building Code (IBC) for most commercial and residential roofing applications.

https://www.carlislesyntec.com/en/Resources/Media/Blog-Landing-Page/SpecTopics/2020/08/18/UL-Fire-Classifications

[12] Energy Flexibility EU — Standards for Building-Integrated Photovoltaics. Summarises EN 50583-1 (BIPV modules as construction products under EU CPR 305/2011 and Low Voltage Directive) and EN 50583-2 (BIPV systems), alongside IEC 63092-1 and IEC 63092-2. EN 50583 is the directly applicable standard for CE marking in European markets.

https://www.energyflexibility.org/standards-for-building-integrated-photovoltaics/

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