A new study titled ‘Closing the UV-Induced Photodegradation Gap Through Global Scale Modelling of Fixed Tilt and Tracking Photovoltaic Systems,’ has highlighted the growing impact of ultraviolet radiation on photovoltaic performance, warning that current industry testing standards may significantly underestimate long term degradation risks, particularly in high irradiation regions.
Ultraviolet radiation is known to accelerate wear at both cell and module level, reducing efficiency and shortening operational life. However, the study finds that widely used testing frameworks such as IEC 61215 photovoltaic module standard fail to replicate real world exposure conditions. In some regions, standard test doses of 15 kWh per m2 can be reached in less than 50 days, raising concerns about the adequacy of existing reliability benchmarks.
Researchers developed a high precision model to estimate UV radiation on tilted solar panels, incorporating solar position, atmospheric conditions and system design. The model demonstrated strong accuracy, with deviation below ±4.28% when compared with observed data and even lower bias of under 1.6% against simulation and radiometer measurements.
The findings show significant global variation in UV exposure, ranging from below 30 W per m2 in high latitude regions to above 80 W per m2 in arid zones. This variation has direct implications for system design and performance. Notably, single axis tracking systems consistently recorded higher UV exposure than fixed tilt installations, resulting in approximately double the degradation rates in arid and semi-arid climates.
The study also confirms that environmental conditions play a decisive role. Tropical, arid and semi-arid regions experience higher UV driven degradation due to a combination of elevated temperatures, strong irradiation and, in some cases, humidity effects. Even in dry regions, clearer skies and higher temperatures contribute to intensified UV stress on solar modules.
One of the most significant findings is that UV induced degradation alone can account for nearly 25% of total annual performance loss in monocrystalline silicon modules operating in high exposure environments. This could shorten system lifetimes by 7 to 10 years, increasing maintenance requirements and negatively affecting the levelized cost of electricity.
The research underscores that identical solar technologies deployed in different regions may perform very differently over time. As a result, the authors call for regionally adaptive testing protocols and more climate specific reliability assessments to better reflect actual operating conditions.
For developers, manufacturers and investors across high solar resource regions such as Africa, the implications are clear. Improved modelling of UV exposure and degradation will be critical for accurate lifetime forecasting, material selection and overall project bankability as the continent continues to scale up solar deployment.
Author: Bryan Groenendaal
February 26, 2026
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