1.1 The three radiant energy weathering procedures described in these test methods are intended to determine the effects of extended outdoor exposure-induced stress that may occur during service life of photovoltaic modules. 1.1.1 Because most accelerated weathering devices are not large enough to accept full-sized photovoltaic modules, the simulated weathering test procedures may be suitable only for smaller test modules. The construction of smaller test modules should be as close in design and function as possible to full-size modules. 1.2 The three solar weathering test methods are as follows: 1.2.1 Procedure A -Natural sunlight, real-time exposure testing, 1.2.2 Procedure B -Accelerated exposure testing concentrated natural sunlight, and 1.2.3 Procedure C -Accelerated exposure testing using simulated sunlight. 1.3 The test methods do not provide for weathering studies on individual components of photovoltaic modules. 1.4 There is no similar or equivalent ISO Standard. 1.5 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use.

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4.1 The useful life of photovoltaic modules deployed in marine applications (such as floating aids-to-navigation) may depend on the ability to withstand repeated exposure to salt atmosphere, immersion in seawater, and the temperature changes associated with seawater splash falling on modules operating in sunlight. The effects of these exposures may be physical or electrical changes in the module, or both.4.2 This test method describes a procedure for positioning the test specimen, conducting a cyclical combined pressure, immersion, and temperature (PIT) test, and reporting the results. It also references methods for conducting module electrical performance and insulation integrity tests.4.3 Data generated by this test method may be used to evaluate and compare the effects of a simulated marine environment on test specimens. This test method requires recording of visible effects as well as electrical performance.4.3.1 Effects on modules may vary from none to significant changes. Some physical changes in the module may be visible when there are no apparent electrical changes in the module. Similarly, electrical changes may occur with no visible changes in the module.1.1 This test method provides a procedure for determining the ability of photovoltaic modules to withstand repeated immersion or splash exposure by seawater as might be encountered when installed in a marine environment, such as a floating aid-to-navigation. A combined environmental cycling exposure with modules repeatedly submerged in simulated saltwater at varying temperatures and under repetitive pressurization provides an accelerated basis for evaluation of aging effects of a marine environment on module materials and construction.1.2 This test method defines photovoltaic module test specimens and requirements for positioning modules for test, references suitable methods for determining changes in electrical performance and characteristics, and specifies parameters which must be recorded and reported.1.3 This test method does not establish pass or fail levels. The determination of acceptable or unacceptable results is beyond the scope of this test method.1.4 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard.1.5 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety, health, and environmental practices and determine the applicability of regulatory limitations prior to use.1.6 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.

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5.1 Photovoltaic modules and components must be resistant to prolonged exposure to solar radiation, moisture and heat. Degradation of polymeric components, delamination at the encapsulant and other interfaces, and moisture ingress are among the degradation modes known to decrease the output of photovoltaic modules. IEC qualification standards for PV modules include tests intended to uncover whether solar ultraviolet radiation induced degradation may cause early-life failures. This practice provides general and specific guidance on performing tests that meet the requirements of the ultraviolet radiation conditioning exposures in the IEC qualification standards.4 Other protocols exist that may also conform to the IEC test requirements.5.2 In the qualification test sequence, this UV preconditioning exposure is conducted prior to the thermal cycling and humidity freeze tests. These tests were included to replicate a delamination failure observed in modules.55.3 IEC exposure methods should not be considered as long-term weathering tests. Exposure to moisture in the form of condensation or water spray is not a requirement of the UV exposure tests in IEC PV module qualification standards. Inclusion of moisture is typically a consideration in weathering tests.5.4 Variation in test results may be expected when operating conditions are varied within the acceptable limits of this standard. In particular, reciprocity of degradation among varying irradiance levels should not be assumed. Consequently, no reference to this practice should be made without an accompanying report prepared in accordance with Section 9 that describes the specific operating conditions used.5.5 Correlation between this practice and long term performance of PV modules in real-world installations has not been determined. Although experience has shown these methods are effective in screening for unstable materials and systems, it is unknown at this time if degradation due to prolonged solar ultraviolet exposure can be replicated by extending the time and energy dosage of the exposures described in this practice. The most effective use of this practice is as a comparative tool for evaluating materials and systems. Consequently, the use of controls or reference materials of known performance is recommended; refer to Practice G151, Section 6.2.4.1.1 This practice covers specific procedures and test conditions for performing ultraviolet conditioning exposures on photovoltaic modules or mini-modules using fluorescent ultraviolet lamps in accordance with Practices G151 and G154. This practice covers test conditions that meet the requirements for UV preconditioning in initial qualification tests of photovoltaic modules or mini-modules as published in International Electrotechnical Commission (IEC) standards.1.2 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard.1.3 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety, health, and environmental practices and determine the applicability of regulatory limitations prior to use.1.4 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.

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4.1 With the rapid expansion of the commercial photovoltaic market and the various standards and independent certification entities evolving, a consensus standard practice for the ICOMP process is needed to bring consistency to the market.4.2 Investors and insurance companies need consistency of product and standards to reduce costs of capital and underwriting. Use of a consensus standard practice is expected to improve consistency and reduce risk for investors.4.3 Photovoltaic systems operate in harsh environments that are not typical for electrical equipment and generally inconsistent with electrical contractor experience. Documented processes are needed to ensure performance and durability of the systems over the long operating life.4.4 The goal of this practice is to implement processes to improve safety and reliability, reduce lifecycle costs (commonly referred to as Levelized Cost of Energy or LCOE), and encourage the development of feedback loops for continuous improvement of results.4.5 This practice may be applied during any or all phases of the PV System Lifecycle (refer to Section 5). A record of the activities carried out according to this practice shall be included in the Report (refer to Section 8).1.1 This practice details the minimum requirements for installation, commissioning, operations, and maintenance processes to ensure safe and reliable power generation for the expected life of the photovoltaic system. Specifically dealing with commercial photovoltaic installations, this practice covers a broad spectrum of designs and applications and is focused on the proper process to ensure quality.1.2 This practice does not cover the electrical aspects of installation found in existing and national codes and does not replace or supersede details of electrical installation covered by the same. The practice does address the integration of best practices into design and construction.1.3 This practice shall not dictate specific design criteria or favor any product or technology.1.4 This practice shall be focused on the proper, documented process required to build and operate a quality PV plant as defined in Section 3.1.5 Integration of best practices shall be relevant to this standard and promote a mechanism for rapid evolution and reaction to changes or events. Conformity assessment for PV power plants is being developed through the IEC System for Certification to Standards Relating to Equipment for Use in Renewable Energy Applications (IECRE System). Sandia Labs has developed several model documents that may be adopted as acceptable consensus standards through other standards development organizations.1.6 The standard is divided into three key areas:1.6.1 Design, engineering, and construction of the PV plant. Systems should be designed with operation and maintenance (O&M) in mind. Further standards should be developed for building integrated or building mounted systems, modules with embedded power electronics, lightweight flexible modules, or other specific components.1.6.2 Commissioning, testing, and approval for power generation (Utility Witness Testing). Standards for owner acceptance will also be addressed.1.6.3 O&M of the PV plant including performance monitoring, periodic inspection, preventive maintenance, and periodic re-commissioning.1.7 Safety and hazard considerations unique to this application, such as worker fall protection, electrical exposure, accessibility of modules, and roof clearance (around the perimeter of the array) are addressed by other codes, standards, or authorities having jurisdiction.1.8 This practice provides guidelines for minimum processes required and must be used in conjunction with applicable codes and standards, government regulations, manufacturer requirements, and best practices.1.9 This practice is not intended to replace or supersede any other applicable local codes, standards or Licensed Design Professional instructions for a given installation.1.10 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety, health, and environmental practices and determine the applicability of regulatory limitations prior to use.1.11 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.

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1.1 This specification specifies the recommended physical characteristics of the steel blades required for the surface cut test described in ANSI/UL 1703 (Section 24) and IEC 61730-2 (Paragraph 10.3).1.2 ANSI/UL 1703 and IEC 61730-2 are standards for photovoltaic module safety testing.1.3 This standard provides additional fabrication details for the surface cut test blades that are not provided in ANSI/UL 1703 or IEC 61730-2. Surface cut test blades that have out-of-tolerance corner radii or burrs are known to cause erroneous test results, either passes or failures.1.4 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard.1.5 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety, health, and environmental practices and determine the applicability of regulatory limitations prior to use.1.6 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.

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4.1 In many geographic areas, there is concern about the effect of falling hail upon photovoltaic modules. This test method may be used to determine the ability of photovoltaic modules to withstand the impact forces of hailstones. In this test method, the ability of a photovoltaic module to withstand hail impact is related to its tested ability to withstand impact from ice balls. The effects of impact may be either physical or electrical degradation of the module.4.2 This test method describes a standard procedure for mounting the test specimen, conducting the impact test, and reporting the effects.4.2.1 The procedures for mounting the test specimen are provided to assure that modules are tested in a configuration that relates to their use in a photovoltaic array.4.2.2 Six or more impact locations are chosen to represent vulnerable sites on modules and general locations are listed in Table 1. Only a single impact is specified at each of the impact locations.4.2.3 Resultant speed is used to simulate the speed that may be reached by hail accompanied by wind. The resultant speed used in this test method is determined by vector addition of horizontal wind velocity plus vertical ice ball terminal velocity.4.2.4 Ice balls are used in this test method to simulate hailstones. Hailstones are variable in properties such as shape, density, and frangibility (for fracture characteristics, see Ref (10) in Practice E822). These properties affect factors such as the duration and magnitude of the impulsive force acting on the module and the area over which the impulse is distributed. Ice balls (with a density, frangibility, and terminal velocity near the range of hailstones) are the nearest hailstone approximation known at this time. Ice balls generally are harder and denser than hailstones; therefore, an ice ball simulates the worst case hailstone. Perhaps the major difference between ice balls and hailstones is that hailstones are more variable than ice balls. Ice balls can be uniformly and repeatedly manufactured to assure a projectile with known properties.4.2.5 Ice balls are directed normal to the surface of a test specimen, which transfers the greatest kinetic energy to the test specimen, unlike a non-normal impact at a glancing angle.4.3 Data generated using this test method may be used for the following: (1) to evaluate impact resistance of a module, (2) to compare the impact resistance of several modules, (3) to provide a common basis for selection of modules for use in various geographic areas, or (4) to evaluate changes in impact resistance of modules due to other environmental factors, such as weathering.4.3.1 This test method requires analysis of visual effects, as well as electrical measurements. Visual effects are generally more sensitive than the electrical measurements; therefore, the absolute values for voltage and current are not critical, but repeatable conditions for before and after tests are required for determining electrical changes.4.3.2 A range of observable effects may be produced by impacting various types of photovoltaic modules. Physical effects on modules may vary from no effect to penetration by the ice ball. Some physical changes in the module may be visible when there is no apparent electrical degradation of the module.4.3.3 Electrical changes may vary from no effect to no output. All effects of the impacts must be described in the report so that an estimate of their significance can be made.4.4 This test method does not specify the size or velocity of ice balls or maximum number of impacts to be used in making the test. These determinations will be based on frequency and severity of expected hail occurrences and the intent of the testing.4.4.1 If the testing is being performed to evaluate impact resistance of a single module, or several modules, it may be desirable to repeat the test using several sizes and velocities of ice balls. In this manner, the different effects of various sizes and velocities of ice balls may be determined. However, no point shall be impacted more than once (see 7.10).4.4.2 The size and frequency of hail varies significantly among various geographic areas. If testing is being performed to evaluate modules intended for use in a specific geographic area, the ice ball size should correspond to the level of hail impact resistance required for that area. Information on hail size and frequency can be found in Appendix X1 of Practice E822 and footnotes 3 and 4 of this test method, or may be available from local historical weather records.4.4.3 When testing modules that are designed to be in a stowed position during hail storms, additional impact locations should be chosen accordingly.4.5 The hail impact resistance of modules may change as the materials are exposed to various environmental factors. This test method may be used to evaluate degradation by comparison of hail impact resistance data measured before and after exposure to other such environmental factors.1.1 This test method provides a procedure for determining the ability of photovoltaic modules to withstand impact forces of falling hail. Propelled ice balls are used to simulate falling hailstones.1.2 This test method defines test specimens and methods for mounting specimens, specifies impact locations on each test specimen, provides an equation for determining the velocity of any size ice ball, provides a method for impacting the test specimens with ice balls, provides a method for determining changes in electrical performance, and specifies parameters that must be recorded and reported.1.3 This test method does not establish pass or fail levels. The determination of acceptable or unacceptable levels of ice ball impact resistance is beyond the scope of this test method.1.4 The size of the ice ball to be used in conducting this test is not specified. This test method can be used with various sizes of ice balls.1.5 This test method may be applied to concentrator and nonconcentrator modules.1.6 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard.1.7 This standard does not purport to address all of the safety problems, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety, health, and environmental practices and determine the applicability of regulatory limitations prior to use. For specific precautionary statements, refer to 5.1, Section 6, Note 8, and Note 9.1.8 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.

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1.1 This test method is intended to be used for calibration and characterization of primary terrestrial, silicon photovoltaic reference cells to the global reference spectral irradiance distribution defined by Tables E892. The recommended physical requirements for these reference cells are described in Specification E1040. Reference cells are principally used in the determination of the electrical performance of a photovoltaic device. 1.2 Primary global reference cells are calibrated outdoors in natural sunlight by reference to a pyranometer that is used to measure the global irradiance. 1.3 This test method applies only to the calibration of a photovoltaic cell which demonstrates a linear short-circuit current versus irradiance characteristic over its intended range of use, as defined in Test Method E1143. 1.4 This test method applies only to the calibration of single- or poly-crystalline silicon reference cells that have been fabricated with a single photovoltaic junction. 1.5 There is no similar or equivalent ISO standard. 1.6 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety and health practices and determine the applicability of regulatory limitations prior to use.

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This specification describes the physical requirements for primary and secondary nonconcentrator terrestrial phorovoltaic reference cells based on small-cell package design and module-package design. These requirements include those for product marking, reference cell material, window, configuration, electrical connectors, and temperature sensor.1.1 This specification describes the physical requirements for primary and secondary terrestrial nonconcentrator photovoltaic reference cells. A reference cell is defined as a device that meets the requirements of this specification and is calibrated in accordance with Test Method E1125 or Test Method E1362.1.2 Reference cells are used in the determination of the electrical performance of photovoltaic devices, as stated in Test Methods E948 and E1036.1.3 Two reference cell physical specifications are described:1.3.1 Small-Cell Package Design—A small, durable package with a low thermal mass, wide optical field-of-view, and standardized dimensions intended for photovoltaic devices up to 20 by 20 mm, and1.3.2 Module-Package Design—A package intended to simulate the optical and thermal properties of a photovoltaic module design, but electric connections are made to only one photovoltaic cell in order to eliminate problems with calibrating series and parallel connections of cells. Physical dimensions are not standardized.1.4 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard.1.5 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety, health, and environmental practices and determine the applicability of regulatory limitations prior to use.1.6 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.

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4.1 The design of a photovoltaic module or system intended to provide safe conversion of the sun's radiant energy into useful electricity must take into consideration the possibility of partial shadowing of the module(s) during operation. This test method describes a procedure for verifying that the design and construction of the module provides adequate protection against the potential harmful effects of hot spots during normal installation and use.4.2 This test method describes a procedure for determining the ability of the module to provide protection from internal defects which could cause loss of electrical insulation or combustion hazards.4.3 Hot spot heating occurs in a module when its operating current exceeds the reduced short-circuit current (ISC) of a shadowed or faulty cell or group of cells. When such a condition occurs, the affected cell or group of cells is forced into reverse bias and must dissipate power, which can cause overheating.NOTE 1: The correct use of bypass diodes can prevent hot spot damage from occurring.4.4 Fig. 1 illustrates the hot spot effect in a module of a series string of cells, one of which, cell Y, is partially shadowed. The amount of electrical power dissipated in Y is equal to the product of the module current and the reverse voltage developed across Y. For any irradiance level, when the reverse voltage across Y is equal to the voltage generated by the remaining (s-1) cells in the module, power dissipation is at a maximum when the module is short-circuited. This is shown in Fig. 1 by the shaded rectangle constructed at the intersection of the reverse I-V characteristic of Y with the image of the forward I-V characteristic of the (s-1) cells.FIG. 1 Hot Spot Effect4.5 Bypass diodes, if present, as shown in Fig. 2, begin conducting when a series-connected string in a module is in reverse bias, thereby limiting the power dissipation in the reduced-output cell.FIG. 2 Bypass Diode EffectNOTE 2: If the module does not contain bypass diodes, check the manufacturer’s instructions to see if a maximum number of series modules is recommended before installing bypass diodes. If the maximum number of modules recommended is greater than one, the hot spot test should be performed with that number of modules in series. For convenience, a constant current power supply may be substituted for the additional modules to maintain the specified current.4.6 The reverse characteristics of solar cells can vary considerably. Cells can have either high shunt resistance where the reverse performance is voltage-limited or have low shunt resistance where the reverse performance is current-limited. Each of these types of cells can suffer hot spot problems, but in different ways.4.6.1 Low Shunt Resistance Cells: 4.6.1.1 The worst case shadowing conditions occur when the whole cell (or a large fraction) is shadowed.4.6.1.2 Often low shunt resistance cells are this way because of localized shunts. In this case hot spot heating occurs because a large amount of current flows in a small area. Because this is a localized phenomenon, there is a great deal of scatter in performance of this type of cell. Cells with the lowest shunt resistance have a high likelihood of operating at excessively high temperatures when reverse biased.4.6.1.3 Because the heating is localized, hot spot failures of low shunt resistance cells occur quickly.4.6.2 High Shunt Resistance Cells: 4.6.2.1 The worst-case shadowing conditions occur when a small fraction of the cell is shadowed.4.6.2.2 High shunt resistance cells limit the reverse current flow of the circuit and therefore heat up. The cell with the highest shunt resistance will have the highest power dissipation.4.6.2.3 Because the heating is uniform over the whole area of the cell, it can take a long time for the cell to heat to the point of causing damage.4.6.2.4 High shunt resistance cells define the need for bypass diodes in the module’s circuit, and their performance characteristics determine the number of cells that can be protected by each diode.4.7 The major technical issue is how to identify the highest and lowest shunt resistance cells and then how to determine the worst-case shadowing for those cells. If the bypass diodes are removable, cells with localized shunts can be identified by reverse biasing the cell string and using an IR camera to observe hot spots. If the module circuit is accessible the current flow through the shadowed cell can be monitored directly. However, many PV modules do not have removable diodes or accessible electric circuits. Therefore a non-intrusive method is needed that can be utilized on those modules.4.8 The selected approach is based on taking a set of I-V curves for a module with each cell shadowed in turn. Fig. 3 shows the resultant set of I-V curves for a sample module. The curve with the highest leakage current at the point where the diode turns on was taken when the cell with the lowest shunt resistance was shadowed. The curve with the lowest leakage current at the point where the diode turns on was taken when the cell with the highest shunt resistance was shadowed.FIG. 3 Module I-V Characteristics with Different Cells Totally Shadowed4.9 If the module to be tested has parallel strings, each string must be tested separately.4.10 This test method may be specified as part of a series of qualification tests including performance measurements and demonstration of functional requirements. It is the responsibility of the user of this test method to specify the minimum acceptance criteria for physical or electrical degradation.1.1 This test method provides a procedure to determine the ability of a photovoltaic (PV) module to endure the long-term effects of periodic “hot spot” heating associated with common fault conditions such as severely cracked or mismatched cells, single-point open circuit failures (for example, interconnect failures), partial (or nonuniform) shadowing, or soiling. Such effects typically include solder melting or deterioration of the encapsulation, but in severe cases could progress to combustion of the PV module and surrounding materials.1.2 There are two ways that cells can cause a hot spot problem: either by having a high resistance so that there is a large resistance in the circuit, or by having a low resistance area (shunt) such that there is a high current flow in a localized region. This test method selects cells of both types to be stressed.1.3 This test method does not establish pass or fail levels. The determination of acceptable or unacceptable results is beyond the scope of this test method.1.4 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard.1.5 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety, health, and environmental practices and determine the applicability of regulatory limitations prior to use.1.6 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.

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This specification provides the performance requirements and parameters used for classifying both pulsed and steady state solar simulators intended for indoor testing of photovoltaic devices (solar cells or modules), according to their spectral match to a reference spectral irradiance, non-uniformity of spatial irradiance, and temporal instability of irradiance. The classification of a solar simulator is based on the size of the test plane, and does not provide any information about electrical measurement errors that are related to photovoltaic performance measurements obtained with a classified solar simulator.1.1 This classification provides means for assessing the suitability of solar simulators for indoor electrical performance testing of photovoltaic cells and modules, that is, for measurement current-voltage curves under artificial illumination.1.2 Solar simulators are classified according to their ability to reproduce a reference spectral irradiance distribution (see Tables G138 and E490), the uniformity of total irradiance across the test plane, and the stability of total irradiance over time.1.3 A solar simulator usually consists of three major components: (1) light source(s) and associated power supplies; (2) optics and filters required to modify the irradiance at the test plane; and (3) controls to operate the simulator, including irradiance adjustment.1.4 This classification is applicable to both pulsed and steady-state solar simulators.1.5 Many solar simulators also include integral data acquisition systems for photovoltaic performance testing; these data acquisition systems are outside of the scope of this classification.1.6 Light sources for weathering, durability, or conditioning of photovoltaic devices are outside of the scope of this classification.1.7 This classification is not applicable to solar simulators intended for testing photovoltaic concentrator devices.1.8 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard.1.9 The following precautionary caveat pertains only to the hazards portion, Section 6, of this classification. This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety, health, and environmental practices and determine the applicability of regulatory limitations prior to use.1.10 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.

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5.1 The spectral responsivity of a photovoltaic device is necessary for computing spectral mismatch parameter (see Test Method E973). Spectral mismatch is used in Test Method E948 to measure the performance of photovoltaic cells in simulated sunlight, in Test Methods E1036 to measure the performance of photovoltaic modules and arrays, in Test Method E1125 to calibrate photovoltaic primary reference cells using a tabular spectrum, and in Test Method E1362 to calibrate photovoltaic secondary reference cells. The spectral mismatch parameter can be computed using absolute or relative spectral responsivity data.5.2 This test method measures the differential spectral responsivity of a photovoltaic device. The procedure requires the use of white-light bias to enable the user to evaluate the dependence of the differential spectral responsivity on the intensity of light reaching the device. When such dependence exists, the overall spectral responsivity should be equivalent to the differential spectral responsivity at a light bias level somewhere between zero and the intended operating conditions of the device. Depending on the linearity response of the DUT over the intensity range up to the intended operating conditions, it may not be necessary to set up a very high light bias level.5.3 The spectral responsivity of a photovoltaic device is useful for understanding device performance and material characteristics.5.4 The procedure described herein is appropriate for use in either research and development applications or in product quality control by manufacturers.5.5 The reference photodetector’s calibration must be traceable to SI units through a National Institute of Standards and Technology (NIST) spectral responsivity scale or other relevant radiometric scale.3 ,4 The calibration mode of the photodetector (irradiance or power) will affect the procedures used and the kinds of measurements that can be performed.5.6 This test method does not address issues of sample stability.5.7 Using results obtained by this test method and additional measurements including reflectance versus wavelength, one can compute the internal quantum efficiency of a device. These measurements are beyond the scope of this test method.5.8 This test method is intended for use with a single-junction photovoltaic cell. It can also be used to measure the spectral responsivity of a single junction within a series-connected, multiple-junction photovoltaic device if electrical contact can be made to the individual junction(s) of interest.5.9 With additional procedures (see Test Methods E2236), one can determine the spectral responsivity of individual junctions within series-connected, multiple-junction, photovoltaic devices when electrical contact can only be made to the entire device’s two terminals.5.10 Using forward biasing techniques5, it is possible to extend the procedure in this test method to measure the spectral responsivity of individual series-connected cells within photovoltaic modules. These techniques are beyond the scope of this test method.1.1 This test method is to be used to determine either the absolute or relative spectral responsivity response of a single-junction photovoltaic device.1.2 Because quantum efficiency is directly related to spectral responsivity, this test method may be used to determine the quantum efficiency of a single-junction photovoltaic device (see 10.10).1.3 This test method requires the use of a bias light.1.4 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard.1.5 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety, health, and environmental practices and determine the applicability of regulatory limitations prior to use.1.6 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.

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6.1 The primary goal of this practice is to extract representative samples from PV modules for TCLP toxicity testing purposes in order to receive unbiased, comparable and repeatable toxicity test results from independent TCLP testing laboratories.6.2 Solar photovoltaic (PV) modules in the United States and the world reaching end-of-life due to failure, underperformance or breakage due to extreme weather have to be recycled or otherwise safely disposed of following the Resource Conservation and Recovery Act (RCRA) regulation [United States, Resource Conservation and Recovery Act. Pub.L. 94–580, October 1976]. For end-of-life PV modules, the U.S. Environmental Protection Agency (EPA) Method 1311 (TCLP) is used for waste characterization based on leaching potential under simulated landfill conditions.6.3 Commercial PV modules contain compounds and alloys of various metals (for example, Ag, Al, Cd, Cu, Ga, In, Ni, Pb, Se, Sn, Te, Zn) which are used in semiconductor compounds and electrical contacts.5 Modules that pass the EPA Method 1311 TCLP test, and state protocols (if applicable), can be disposed of in a regular landfill. Otherwise, they are classified as hazardous waste and must go through a more onerous and expensive disposal process. Currently, there is no national or international standard, nor a standardized protocol available for removal of test samples from PV modules for toxicity testing per the EPA Method 1311 standard.6.4 The validity of the toxicity test results heavily depends on the location of extracted samples in the module, specifically within the laminate area, and the particle size of the extracted samples. Therefore, it is critical that the sample extraction procedure be properly designed to avoid biased or otherwise inaccurate toxicity test results.6.5 The development and application of a homogeneous and representative sampling standard will help utilities and manufacturers to limit the number of variables and to obtain repeatable test results.1.1 The purpose of this practice is to describe a representative and repeatable sample preparation methodology to conduct toxicity testing on solar photovoltaic (PV) modules for use with EPA Test Method 1311: Toxicity Characteristic Leaching Procedure (TCLP).1.2 This practice refers to the extraction and preparation of PV module samples by EPA Method 1311, the testing for eight (8) distinct metals – mercury (by Method 7470A), arsenic, barium, cadmium, chromium, lead, selenium and silver (by Method 6010C) as well as the analysis and interpretation of the test results on a module level.1.3 This practice applies to only (1) standard crystalline silicon (c-Si) modules, multi and mono-crystalline silicon with aluminum back surface field (Al-BSF) cell technology and (2) cadmium telluride (CdTe) PV modules.1.4 Other and newer PV technologies and module architectures, for example, passivated emitter and rear cell (PERC), interdigitated back contact (IBC), hetero-junction technology (HJT), multiwire, half cut, shingled etc., have not been evaluated with this practice, although the concept and practice can be easily extended and applied to other technologies following the conceptual approach presented in this document.1.5 The sample extraction/removal methodology applied in this practice is the waterjet cutting sampling method. Sample extraction with mechanical cutting has been extensively evaluated but the variability of TCLP test results based on the mechanical cut samples tend to be much higher (30 %) than that of the waterjet cut samples (8 %).2 Therefore, the mechanical cut method is not presented in this practice.1.6 Only the laminate area of the PV module is considered for TCLP testing, as other possible module parts, such as aluminum frame, junction box and cables contain recyclable materials that are already well-documented and are not specific to the PV modules.1.7 The material gravimetric density (g/cm3) throughout the laminate area is considered constant.1.8 This practice was developed to be consistent with three fundamental requirements:1.8.1 Sample pieces with particle size not to exceed the allowed size limit of EPA 1311 standard which is 9.5 mm,1.8.2 The particle size used in this practice as sample piece is consistent with the median particle size expected in landfill disposal2, and1.8.3 An assumption that each laminate sample piece will result in 100 % glass coverage area, due to the presence of bonding encapsulant layers once it is broken in the landfill.1.9 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard.1.10 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety, health, and environmental practices and determine the applicability of regulatory limitations prior to use.1.11 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.

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1.1 This terminology pertains to photovoltaic (radiant-to-electrical energy conversion) device performance measurements and is not a comprehensive list of terminology for photovoltaics in general.1.2 Additional terms used in this terminology and of interest to solar energy may be found in Terminology E 772.

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5.1 It is the intent of these procedures to provide recognized methods for testing and reporting the electrical performance of photovoltaic modules and arrays. 5.2 The test results may be used for comparison of different modules or arrays among a group of similar items that might be encountered in testing a group of modules or arrays from a single source. They also may be used to compare diverse designs, such as products from different manufacturers. Repeated measurements of the same module or array may be used for the study of changes in device performance. 5.3 Measurements may be made over a range of test conditions. The measurement data are numerically translated from the test conditions to standard RC, to nominal operating conditions, or to optional user-specified reporting conditions. Recommended RC are defined in Table 1. 5.3.1 If the test conditions are such that the device temperature is within ±2°C of the RC temperature and the total irradiance is within ±5 % of the RC irradiance, the numerical translation consists of a correction to the measured device current based on the total irradiance during the I-V measurement. 5.3.2 If the provision in 5.3.1 is not met, performance at RC is obtained from four separate I-V measurements at temperature and irradiance conditions that bracket the desired RC using a bilinear interpolation method.4 5.3.2.1 There are a variety of methods that may be used to bracket the temperature and irradiance. One method involves cooling the module under test below the reference temperature and making repeated measurements of the I-V characteristics as the module warms up. The irradiance of pulsed light sources may be adjusted by using neutral density mesh filters of varying transmittance. If the distance between the simulator and the test plane can be varied then this adjustment can be used to change the irradiance. In natural sunlight, the irradiance will change with the time of day or if the solar incidence angle is adjusted. 5.4 These test methods are based on two requirements. 5.4.1 First, the reference cell (or module, see 1.1.1 and 4.3.4) is selected so that its spectral response is considered to be close to the module or array to be tested. 5.4.2 Second, the spectral response of a representative cell and the spectral distribution of the irradiance source must be known. The calibration constant of the reference cell is then corrected to account for the difference between the actual and the reference spectral irradiance distributions using the spectral mismatch parameter, which is defined in Test Method E973. 5.5 Terrestrial reference cells are calibrated with respect to a reference spectral irradiance distribution, for example, Tables G173. 5.6 A reference cell made and calibrated as described in 4.3 will indicate the total irradiance incident on a module or array whose spectral response is close to that of the reference cell. 5.7 With the performance data determined in accordance with these test methods, it becomes possible to predict module or array performance from measurements under any test light source in terms of any reference spectral irradiance distribution. 5.8 The reference conditions of 5.3.1 must be met if the measured I-V curve exhibits “kinks” or multiple inflection points. 1.1 These test methods cover the electrical performance of photovoltaic modules and arrays under natural or simulated sunlight using a calibrated reference cell. 1.1.1 These test methods allow a reference module to be used instead of a reference cell provided the reference module has been calibrated using these test methods against a calibrated reference cell. 1.2 Measurements under a variety of conditions are allowed; results are reported under a select set of reporting conditions (RC) to facilitate comparison of results. 1.3 These test methods apply only to nonconcentrator terrestrial modules and arrays. 1.4 The performance parameters determined by these test methods apply only at the time of the test, and imply no past or future performance level. 1.5 These test methods apply to photovoltaic modules and arrays that do not contain series-connected photovoltaic multijunction devices; such module and arrays should be tested according to Test Methods E2236. 1.6 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard. 1.7 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety, health, and environmental practices and determine the applicability of regulatory limitations prior to use. 1.8 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.

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5.1 This test method provides a procedure for testing and reporting the electrical performance of photovoltaic cells.5.2 The test results may be used for comparison of cells among a group of similar cells or to compare diverse designs, such as different manufacturers' products. Repeated measurements of the same cell may be used to study changes in device performance.5.3 This test method determines the electrical performance of a photovoltaic cell at a single instant of time and the results do no imply any past or future performance.5.4 This test method requires a linear reference cell calibrated with respect to an appropriate reference spectral irradiance distribution, such as Tables E490, or G173. It is the responsibility of the user to determine which reference spectral irradiance distribution is appropriate for a particular application.1.1 This test method covers the determination of the electrical performance of a photovoltaic cell under simulated sunlight by means of a calibrated reference cell procedure.1.2 Electrical performance measurements are reported with respect to a select set of standard reporting conditions (SRC) (see Table 1) or to user-specified reporting conditions. In either case, the chosen reporting conditions are abbreviated as RC.1.2.1 The RC include the cell temperature, the total irradiance, and the reference spectral irradiance distribution.1.3 This test method is applicable only to photovoltaic cells with a linear short-circuit current versus total irradiance response up to and including the total irradiance used in the measurement.1.4 The cell parameters determined by this test method apply only at the time of test, and imply no past or future performance level.1.5 The values stated in SI units are to be regarded as standard. No other units of measurement are included in this standard.1.6 This standard does not purport to address all of the safety concerns, if any, associated with its use. It is the responsibility of the user of this standard to establish appropriate safety, health, and environmental practices and determine the applicability of regulatory limitations prior to use.1.7 This international standard was developed in accordance with internationally recognized principles on standardization established in the Decision on Principles for the Development of International Standards, Guides and Recommendations issued by the World Trade Organization Technical Barriers to Trade (TBT) Committee.

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