Bifacial photovoltaic (PV) modules have become standard in utility-scale solar projects. According to the International Technology Roadmap for Photovoltaic (ITRPV) 16th Edition (2025), bifacial modules account for approximately 90% of recent utility-scale module shipments. As deployment expands across regions, field data from different climates is improving understanding of operational performance.
Bifacial gain refers to the additional energy generated by rear-side irradiance relative to a comparable monofacial configuration. Field studies consistently identify ground reflectivity (albedo) as a key driver of bifacial gain, alongside mounting height and array geometry.
A 12-month field study conducted in Brazil (2025) reported average annual bifacial gains of 8.42% on light sand, 5.92% on white gravel, and 4.53% on darker gravel. These results indicate that bifacial performance varies significantly by site and surface conditions.
Research in West Africa shows that modifying ground surfaces using high-reflectivity membranes or treated aggregates can increase bifacial gains to above 14% under test conditions. Reported gains depend on surface maintenance, soiling rates, and long-term material degradation.
Bifacial modules are also deployed in non-standard system geometries.
Comparative studies in Ghana report bifacial gains of approximately 4–5% for floating PV systems, compared with 2–3% for nearby non-optimized land-based installations. The difference is attributed to diffuse reflection from water surfaces and lower operating temperatures.
Research published in Scientific Reports (2024), including work associated with the University of York, shows that vertical bifacial arrays exhibit two daily production peaks in the morning and evening. During these time periods, measured power output exceeded that of tilted monofacial reference systems by more than 20%. These results apply to specific time windows and do not represent annual energy yield increases.
Snow Management and Thermal Behaviour: In cold-climate installations such as Canada, snow accumulation can significantly reduce front-side output. Field observations indicate that bifacial systems often recover output more quickly after snowfall due to steeper mounting angles and continued rear-side irradiance, which partially offsets front-side losses. Tilt angle, wind exposure, and gravity remain the dominant drivers of snow shedding.
Field measurements suggest bifacial modules may operate slightly cooler than monofacial modules under favorable mounting conditions with good rear-side ventilation, though temperature differences are highly site-dependent. Bifacial systems can experience mismatch losses when rear-side illumination varies significantly across the array, though modern inverter technology and module design increasingly mitigate these effects.
Field data confirms that bifacial modules combined with single-axis tracking generally outperform fixed-tilt monofacial systems at utility scale. Reported total energy gains typically fall in the range of 15–20% relative to fixed-tilt monofacial baselines, depending on site characteristics.
Industry pricing data indicates that the cost premium for bifacial modules has declined substantially and is often in the range of USD 0.01–0.02 per watt in utility-scale procurement. As a result, technology selection is increasingly driven by site conditions and system design rather than module price differentials.
In India, bifacial systems are most effective in high-irradiance regions with favorable surface reflectivity, such as Rajasthan and Gujarat. The technology is also widely used in agrivoltaic projects, where elevated mounting structures (approximately 4–5 meters) improve rear-side exposure while allowing agricultural activity beneath the array.