Technical Report

NREL/TP-520-46569

September 2009

Development of an Outdoor

Concentrating Photovoltaic 

Module Testbed, Module Handling 

and Testing Procedures, and 

Initial Energy Production Results 

M. Muller
National Renewable Energy Laboratory

1617 Cole Boulevard, Golden, Colorado 80401-3393

303-275-3000 • www.nrel.gov

NREL is a national laboratory of the U.S. Department of Energy

Office of Energy Efficiency and Renewable Energy

Operated by the Alliance for Sustainable Energy, LLC

Contract No. DE-AC36-08-GO28308

Technical Report

NREL/TP-520-46569

September 2009

Development of an Outdoor

Concentrating Photovoltaic 

Module Testbed, Module Handling 

and Testing Procedures, and 

Initial Energy Production Results 

M. Muller

Prepared under Task No. PVD9.1410
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iii

Table of Contents

1.0 Introduction ..........................................................................................................................1 

2.0 High-Accuracy Two-Axis Tracking ....................................................................................1 

3.0 Tracking-Error Monitor .......................................................................................................3 

4.0 Data Acquisition System......................................................................................................5 

5.0 Module Handling and On-Sun Alignment Procedure ........................................................12 

6.0 CPV Testing Procedures and Standards ............................................................................15 

7.0 Module Energy Production ................................................................................................20 

8.0 Conclusions and Future Work ...........................................................................................22 

9.0 Acknowledgements ............................................................................................................23 

10.0 References ..........................................................................................................................23 

List of Figures

Figure 1. Tracking error with no control corrections (on June 29, 2008) .................................. 4 

Figure 2. Tracking error with control corrections (on June 30, 2009) ....................................... 5 

Figure 3. Discrepancy in I-V Pmax and PPT Pmax ........................................................................ 9 

Figure 4. April 2009 peak power tracking error (before algorithm change) ............................ 10 

Figure 5. April 2009 peak power tracking after algorithm change) ......................................... 11 

Figure 6. May 2009 peak power tracking error (after algorithm change) ................................ 11 

Figure 7. Sweep data, module previously aligned using a multimeter ..................................... 14 

Figure 8. Sweep data for module characterized in Fig. 7 after 0.1-degree trimming ............... 14 

Figure 9. Module efficiency vs. time of day (June 22, 2009) .................................................. 21 

Figure 10. DNI vs. time of day (June 22, 2009) ......................................................................... 22 

List of Tables

Table 1. Module Electrical Specifications Provided by CPV Companies ................................6 

Table 2. DAS Module Channel Specifications .........................................................................7 

Table 3. Auto-Range Capabilities of DAS Channel .................................................................7 

Table 4. Additional Measurements Built into Multi-Tracer .....................................................8 

Table 5. Instrumentation Attached to CPERT DAS .................................................................8 

Table 6. ASTM and ISFOC Data Restrictions and STCs .......................................................17 

Table 7. Variable Definitions and Specifications for Triple-Junctions Cells .........................18 

Table 8. Module Power Ratings Based on ISFOC and ASTM Procedures ............................19 

Table 9. Module kWh/kWh for Monthly Data Sets ................................................................21 
iv
1 

1.0 Introduction

In recent years, the concentrating photovoltaic (CPV) industry has rapidly expanded as many 

new companies have entered the market. Each company has a unique approach aimed at making 

CPV a reliable, low-cost alternative to traditional flat-plate photovoltaics (PV). As with other 

new technologies, a need arises to establish appropriate standards, testing requirements, and a 

better understanding of the technology itself. Solar Energy Technologies Program (SETP) 

money has been awarded to some of these manufacturers, and as a result, the Test and Evaluation 

group at the National Renewable Energy Laboratory (NREL) has been tasked with evaluating 

some of the associated deliverables. To achieve this task and fulfill the above needs, NREL’s 

Test and Evaluation group made plans to build a testbed for CPV. This report addresses the 

issues associated with building a CPV testbed and presents initial results from module testing. In 

particular, there is a focus on high-accuracy two-axis tracking, monitoring tracking error, CPV 

data acquisition, module handling and testing procedures, and standards development. Finally, 

initial power ratings and efficiency results are presented.

2.0 High-Accuracy Two-Axis Tracking

This project began with plans to refurbish an existing two-axis tracker at NREL’s Outdoor Test 

Facility (OTF) for use with CPV testing. As part of this process, many of the known CPV 

companies were contacted to understand what capabilities should be built into a CPV testbed at 

NREL. With regard to trackers, results indicate that high-concentration PV (HCPV) modules are

being prototyped with acceptance angles ranging from 0.5 to 2 degrees. The acceptance angle is 

commonly defined as the angle of tracking error beyond which module power will drop below 

90%–95% of the power produced at zero tracking error. Hereafter in this report, acceptance 

angle will use only the 95% value. It is typical for HCPV module power to fall rapidly to zero 

when the acceptance angle is exceeded. To isolate module performance from tracker 

performance, tracking error should be significantly less (ideally by an order of magnitude) than 

the given module’s acceptance angle. This requirement leads to a secondary requirement to 

include in the data acquisition system—a means for measuring tracking error.

Acceptance angles of 0.5 degree suggest a need for a tracking that is accurate to 0.05 degree. 

Although ideal, this accuracy is unlikely with the existing tracking structure and tracking 

controller. Specifications for the gear drive and onsite measurements confirm that the gear drive 

has a backlash of about 0.05 degree, leaving no room for controller error.

Sun-tracking control can typically be grouped into three classifications: open-loop control, 

closed-loop control, and a hybrid between the two. Open-loop control refers to a controller that 

has no feedback of the targeted variable. In this case, it means that the controller has no 

feedback from the sun as to its pointing error. Basic open-loop control for sun tracking relies on 
2 

a computation of the sun’s position based on time of day, latitude, and longitude. The computed 

sun position is translated into the drive-system movements that are needed to achieve on-sun 

status. The controller has feedback from encoders on the drive system to determine if motors or 

other components have moved as needed to correctly point at the sun. Pointing errors can result 

from errors due to pedestal tilt, drive-system inconsistencies, clock error, and/or encoder/limit 

switch positions. Most open-loop controllers provide a means to calibrate out or correct for the 

above errors. Weaknesses of open-loop control are that calibrations/corrections may not 

eliminate sufficient error and there are no automatic corrections for error factors that may change 

with time.

Closed-loop control has knowledge/feedback of the sun’s position from an appropriate sensor 

and therefore can constantly correct/calibrate itself. This direct feedback has the potential for 

very high-accuracy tracking when there is an unobstructed view of the sun. Feedback control 

has two major weaknesses for CPV. One, accurate tracking typically depends on the reliability 

of a single sensor. Two, all sun position sensors depend on a clear view of the sun. Clouds or 

overcast skies result in significant tracking error, and a delay time is necessary to find the sun 

when the sky becomes clear. Although this type of tracking could work from an energyproduction standpoint (CPV modules produce very little power when the sun is obstructed), it is 

not adequate for a CPV module research platform. It is very useful to analyze how a module 

performs under various solar conditions, and a complete data set can only be made available if 

the tracker is continuously pointing at the sun. 

A hybrid controller provides the best of open-loop and feedback control. The sun is followed 

throughout the day based on open-loop calculations and position encoders; but when the 

irradiance is high enough (clear-sky conditions), high-accuracy control is provided through sunposition feedback. The sun-position sensor is basically used to fine-tune or calibrate out the 

errors that can be a part of open-loop control. Anecdotal evidence suggests that CPV companies 

typically choose between open-loop and hybrid control based on the acceptance angle of their 

modules. 

 In early 2008, the market was explored for controllers that could be used on NREL’s tracker. 

Although Sandia National Laboratories did work in the late 1980s to help develop a flexible, 

high-accuracy controller that could be marketed in the $500 price range [1], the current market 

still offers very little in terms of tracking control. Based on Sandia’s research, an accurate openloop controller is available from Precision Solar Technologies in the $10,000 price range. Many 

tracker companies have developed controllers that come as part of the tracker package, but are 

not made for individual sale. Inexpensive programmable-logic controllers, microprocessors, 

motor drivers, sensors, and other components are readily available to build a high-accuracy 

controller; but this, of course, comes with high initial development costs. Discussions with small 

CPV startups indicate that they have had to deal with these challenges when investigating 

tracking control options. Some companies indicated that they had decided to build their own 
3 

controllers, whereas others had contracted with tracker companies to provide an entire package. 

Regardless of approach, there is little to no data or documentation in terms of tracking accuracy 

and long-term reliability. A project at Oak Ridge National Laboratory to develop indoor 

daylighting based on sun tracking encountered problems finding an off-the-shelf controller. Oak 

Ridge eventually decided to develop a controller to meet the project’s needs, and some efforts 

have been made by Oak Ridge to make the controller available [2].

An off-the-shelf hybrid controller was considered the best option for NREL’s testbed, but cost 

and lack of availability forced an investigation into other possibilities. The existing tracker had 

not been in operation for at least two years and no documentation could be found on its tracking 

performance. Therefore, a decision was made to use the existing controller to better characterize 

the hardware and structure before significant dollars were invested in a new controller. Handson experience and data collection would provide a true measure of the limitations of the existing 

structure, its drive system, and its controller. Fortunately, Advanced Thermal Systems, the 

original designer of the existing controller, is local to NREL and has been available to support 

efforts to bring the tracker back on line. The existing controller uses astronomical calculations to 

determine the sun’s position within 0.01 degree and provides corrections for pedestal tilt, drivesystem errors, clock drift, and a daily reset of encoder position. A target was set to achieve a 

tracking accuracy of 0.25 degree with existing hardware and to explore options to improve 

accuracy as the system was better characterized.

3.0 Tracking-Error Monitor

Quantitatively documenting a tracking accuracy of 0.25 degree requires some type of device for 

actively measuring tracking error. In addition, the tight acceptance angles of some CPV modules 

require an accurate tracking-error measurement to filter tracking inadequacies from module 

performance data. Based on these needs, we made an extensive search to find a tracking-error 

monitor (TEM) that was accurate to 0.05 degree and within the budget constraints of this project. 

As a whole, we found that this type of product is not readily available. In 2008, Green Mountain 

Engineering released a product that uses sun imaging to achieve the desired accuracy, but the 

product has a price tag near $10,000. Papers in the literature described a product by Inspira 

called SunDog [3]. Although the SunDog could have provided tracking-accuracy measurements, 

it did not appear as an item available to purchase. Communication with CPV companies 

indicated that many have had custom devices built for prototype testing. In the short-term, the 

search for a TEM led to a device built by Sandia that is described in Ref. [4]. Sandia was able to 

supply a monitor as described in the referenced report. The device was calibrated at Sandia and 

provides an accuracy of ±0.02 degree within a viewing angle ±1.8 degree for both azimuth and 

elevation measurements. Because Sandia was only able to provide one device and the tracking 

plane is large, we are considering having additional devices built that use off-the-shelf positionsensing detectors (PSDs) to measure the location of a projected sunspot—and hence, tracking 
4 

error. Our initial investigation suggests that PSDs can be purchased and built into a TEM for 

under $1,500. 

Additional TEMs will be used to better quantify the performance of NREL’s tracker. NREL’s 

two-axis tracker has a steel torque tube that extends four feet out on each side of its pedestal. 

This torque tube, via steel forks, supports two test planes that are roughly 11 feet by 10 feet. The 

test planes consist of an easily configurable 80/20TM aluminum structure and aluminum I-beams. 

These specifications emphasize that there is the potential for flexing of test plane due to differing 

rates of expansion/contraction between steel and aluminum and from the structure acting as a 

large sail in the wind. Although these forces were considered during design and installation, 

mounting TEMs at various points in the plane will quantify the effect that flexing has on tracking 

accuracy. Having spare monitors on hand will also make continuous measurement of tracking 

error possible even when a monitor needs to be taken down for calibration. There is also a future 

need for CPV system data to expand models such as PVWatts and the Solar Advisor Model. The 

majority of these systems will be mounted at locations outside NREL, and portable TEMs will be 

invaluable in the field testing to come. 

In May 2008, the tracker was brought back on line as CPERT (CPV Performance Energy Ratings 

Test-bed) and was calibrated to track the sun. The Sandia TEM was mounted to the tracker and 

the data it provided over several months were used to recalibrate and improve tracking accuracy. 

Figure 1 provides an initial plot of tracking accuracy with no controller corrections.

Figure 1. Tracking error with no control corrections (on June 29, 2008).

Over several months, control correction factors were adjusted to improve tracking accuracy to 

desired levels. Figure 2 shows that for almost the exact date a year later, the tracking error is 

well within ±0.15 degree (achieving the ±0.25 degree target) for both azimuth and elevation 

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5 

pointing. Although we think that tracking error could be further minimized, the process can be 

time consuming and perhaps unnecessary considering the tracking-error data can be used for 

filtering.

Figure 2. Tracking error with control corrections (on June 30, 2009).

It is also worth noting that NREL has become aware of a hybrid controller made by the Spanish 

company Suntrack. Initial investigations into Suntrack suggest that their controller would 

provide a good retrofit for the CPERT tracker. The cost is in the $1500 range and provides the 

potential to improve tracking accuracy immediately after install.

Future plans are to purchase this controller and replace the more than 25-year-old components 

currently being used. 

4.0 Data Acquisition System

Building a testbed for CPV modules requires coupling high-accuracy two-axis tracking with an 

appropriate data acquisition system (DAS). DAS design begins with considering what 

parameters need to be measured and how often they need to be measured. A desired data set for 

CPV modules includes voltage, current, power, and temperature for the module, coupled with 

tracking error, direct-normal irradiance (DNI), global-normal irradiance (GNI), ambient 

temperature, and wind speed. Although the meteorological parameters are fairly simple lowvoltage measurements, the electrical characteristics of the modules can get complicated. The 

project aims to characterize the short-term performance characteristics of various CPV 

technologies, as well as monitor degradation over longer periods of time. A multi-channel 

current-voltage (I-V) curve tracer that holds modules at peak power in between traces is an 

efficient means of meeting both these goals. 

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Use of a multi-tracer presents two challenges when working with CPV modules. First, the unit 

must be located in close proximity to the modules to minimize wire length as needed for 

measuring short-circuit current. The only realistic way to keep module wire lengths under 40 

feet was to locate the multi-tracer immediately next to the tracker pedestal. Most multi-tracers 

are located indoors—for protecting the unit and for using the large capacity of HVAC systems to 

regulate the temperature of the unit. In the case of CPERT, locating the unit outdoors and under 

the tracker meant building a small custom enclosure that would protect the unit from dust, rain, 

snow, and ice; provide the means of connecting to modules that are moving with the sun; and 

shed up to 3,200 watts of heat from modules under load. The second problem is that maximum 

power, voltage, and current must be specified for each channel of the unit. Because the CPV 

industry is young and rapidly changing, this requires establishing channel specifications for 

modules that are rapidly changing. The information obtained from the CPV manufacturers was 

used as a guide for setting channel specifications, and Table 1 summarizes some of the 

information from these companies.

Table 1. Module Electrical Specifications Provided by CPV Companies

Module Isc (A) Voc (V) Pmp (W) Isc x 1.3 Voc x 1.2 Pmp x 1.2

1 (existing) 0.59 152 75 0.77 182.4 90

2 (existing) 0.9 290 200 1.17 348 240

3 (existing) 1.1 140 120 1.43 168 144

4 (future) 2.2 250 510 2.86 300 612

5 (future) 5.6 50 255 7.28 60 306

6 (existing) 7.3 3.1 20 9.49 3.72 24

7 (existing) 8 60 320 10.4 72 384

8 (existing) 8 18 150 10.4 21.6 180

9 (future) 11.2 50 510 14.56 60 612

Most companies provide data for a DNI of 850 W/m2, although Golden, Colorado, can have DNI 

values as high as 1,100 W/m2. For this reason, Table 1 Includes short-circuit current (Isc) 

multiplied by 1.3 (1100/850), which was used as channel specifications were considered. Opencircuit voltage (Voc) has been multiplied by 1.2 to account for winter days, which can be 

significantly colder than standard test conditions yet will still have a high DNI. In summary, 

Table 1 shows the potential to have module electrical characteristics vary widely. The multitracer selected for the CPERT system is capped at 3,200 watts, which can be divided between 

1–16 channels. In a best effort to plan for modules such as those listed above, the specifications 

were established as given in Table 2. 
7 

Table 2. DAS Module Channel Specifications

Channel # Voltage

Max. (V)

Current

Max. (A)

Power

Max. (W)

Resistance Max.

@ Isc (ohms)

Max Volts

@Isc (%FS)

1 80 15 600 0.035 0.7%

2 80 15 400 0.045 0.8%

3 80 15 400 0.045 0.8%

4 80 15 400 0.045 0.8%

5 200 8 400 0.060 0.2%

6 250 5 400 0.055 0.1%

7 250 5 600 0.050 0.1%

The DAS channels are able to auto range as listed in Table 3. The powers selected give CPERT 

the capability to handle modules up to a size of about 2 square meters, whereas auto ranging 

provides the capability to test most of modules seen in Table 1.

Table 3. Auto-Range Capabilities of DAS Channel 

Measurements Range Common Mode Resolution Accuracy Temp Co.

Voltage @ 250 V F.S. (F.S. means “full scale”)

250 V ±250 V 7.6 mV 0.1% + 0.02% 50 ppm/°C

25 V ±250 V 760 μV 0.1% + 0.02% 50 ppm/°C

2.5 V ±250 V 76 μV 0.2% + 0.04% 50 ppm/°C

Voltage @ 200 V F.S.

200 V ±200 V 6.1 mV 0.1% + 0.02% 50 ppm/°C

20 V ±200 V 610 μV 0.1% + 0.02% 50 ppm/°C

2.0 V ±200 V 61 μV 0.2% + 0.04% 50 ppm/°C

Voltage @ 80 V F.S.

80 V ±80 V 2.5 mV 0.1% + 0.02% 50 ppm/°C

8.0 V ±80 V 250 μV 0.1% + 0.02% 50 ppm/°C

0.8 V ±80 V 25 μV 0.2% + 0.04% 50 ppm/°C

Current @ 15 A F.S.

15.0 A NA 460 μA 0.1% + 0.02% 50 ppm/°C

1.5 A NA 46 μA 0.2% + 0.04% 50 ppm/°C

Current @ 8 A F.S.

8.0 A NA 245 μA 0.1% + 0.02% 50 ppm/°C

0.8 A NA 25 μA 0.2% + 0.04% 50 ppm/°C

Current @ 5 A F.S.

5.0 A NA 150 μA 0.1% + 0.02% 50 ppm/°C

0.5 A NA 15 μA 0.2% + 0.04% 50 ppm/°C

General Purpose

±5 V ±5 V 150 μV 0.1% + 0.02% 50 ppm/°C

±500 mV ±5 V 15 μV 0.1% + 0.02% 50 ppm/°C

±50 mV ±5 V 1.5 μV 0.2% + 0.04% 50 ppm/°C

±5 mV ±5 V 0.15 μV 0.3% + 0.06% 50 ppm/°C
8 

The DAS has been in operation for nearly a year and thus far there have been no problems 

matching modules with available channels. It appears that the most likely problem with the DAS 

is going to be a shortage of channels, although the tracker will still have area for additional 

modules. With hindsight, the DAS may have been more accommodating if several of the 400-

watt channels had been split into two 200-watt channels or four 100-watt channels. Considering 

that all modules currently being tested are under 140 watts, it would have been possible to allot 

the DAS power to 10 to 12 channels and it may be retrofitted as such if deemed necessary.

The general-purpose channels and inputs for thermocouples that are listed in Table 4 provide a 

means of measuring and recording meteorological and temperature data along with module 

power characteristics.

Table 4. Additional Measurements Built into Multi-Tracer

Description # Inputs Notes

Module Temps 16 Type T thermocouple

Aux Temps 8 Type T thermocouple

General Purpose 8 ±5 V

Table 5 provides specifications for the equipment attached to the general-purpose channels. 

Additionally, a direct-normal spectroradiometer was installed at NREL’s Solar Radiation 

Research Lab (SRRL) and these data are available from SRRL’s data archives.

Table 5. Instrumentation Attached to CPERT DAS

Kipp & Zonen CHP1 pyrheliometer (DNI)

Sensitivity (±0.5%) 8.31 μV/Wm-2

Response time to reach 95% final value 5 s

Viewing angle 5 degrees

Required tracking accuracy ±0.5 degree

Kipp & Zonen CM11 pyranometer (GNI)

Sensitivity 5.1331 μV/Wm-2

Response time to reach 95% final value 5 s

Viewing angle 180 degrees

RM Young anemometer (Wind Sentry w/ voltage output)

Range 0–50 m/s

Output signal over wind-speed range 0–5 V

Threshold 1.1 m/s

Power requirement 8–24 VDC 5mA @ 12 VDC

Sandia Tracking-Error Monitor

Azimuth constant (K) 8.27

Elevation constant (K) 8.22

Accuracy provided from Sandia calibration ±0.02 degree

4 output signals 0–12 mV

Calculation for error in degrees K(a-b)/(a+b)

Field of view ±1.8 degrees
9 

T-type thermocouples are used to measure one to three temperatures for each module, ambient 

temperature, and the temperature of the DAS box. The DAS box temperature and the wind 

speed are part of the data set, but are both also used as inputs to tracker stow functions. The 

tracker controller has a built-in capability to stow based on circuits that are monitored for an 

open/closed condition. A relay opens/closes the given circuit based on a specified wind speed 

and a specified temperature, and this in turn triggers the tracker to stow at a predetermined 

position. The wind stow is to protect the tracker and modules, whereas the temperature stow is 

used to ensure the DAS system does not exceed its maximum operating temperature. In the 

event that primary temperature controls for DAS box fail, a stow of the tracker eliminates heat to 

the box that is being generated by CPV modules. 

The DAS software allows control of the interval for recording peak power tracking (PPT) data 

and for performing I-V sweeps and recording corresponding data. The PPT data are an average 

of the measurements taken over a specified interval, whereas the I-V data file records 

instantaneous measurements. Ideally, the PPT data provide a means to calculate the energy 

produced from a given module over a day, month, or longer interval, whereas the I-V data are 

useful for monitoring module performance, degradation, and troubleshooting failures. Currently, 

the DAS is set to sample PPT data every 5 seconds and average the data every minute, whereas 

I-V curves are taken every five minutes. The PPT data provide a very useful record of changing 

meteorological conditions; but unfortunately, module PPT electrical measurements have not 

been accurate enough to use in calculating energy output. The DAS monitors and records PPT 

measurements as specified, but the actual algorithm for holding modules at peak power has 

periodically demonstrated inaccuracies. In many instances and in some cases for entire days, the 

peak power point from PPT data has not aligned with that from the corresponding I-V curve. 

Figure 3 displays an I-V curve marked with its corresponding maximum power point (Pmax) and 

Pmax from the previous averaged minute of PPT. 

Figure 3. Discrepancy in I-V Pmax and PPT Pmax. 
10

PPT error is calculated by taking the difference between corresponding Pmax points, as 

exemplified in Fig. 3, and converting this to percent error. Due to limitations comparing 1-

minute average data with instantaneous data, peak power tracking error is only calculated when 

the DNI varied less than 2% in the 5 minutes prior to the IV curve. Figure 4 displays the peak 

power tracking error for one module/channel for data recorded in the first half of April. 

Figure 4. April 2009 peak power tracking error (before algorithm change)

Discussions with the DAS manufacture indicated that a step size used in the PPT algorithm may 

be causing problems. Generally speaking, the PPT algorithm uses a perturb-and-measure 

approach to find the peak power point. The initial perturbation is controlled by a preset step size 

that then shrinks as the algorithm hones in on the peak power point. If the initial step is too 

large, Voc could be reached and the algorithm would then start over. On the other side, if the step 

size becomes too small, finding Pmax can be lost in measurement noise. Regardless, in mid April, 

the manufacture made changes to the code to reduce the initial step size, and the primary results 

were promising. Figure 5 displays the PPT error for the same module/channel for the second 

half of April 2009 after the algorithm was changed. The maximum PPT error reduced from 52% 

to 5% and the standard deviation for the PPT error data also reduced from 12.4% to 3.2%. 
11

Figure 5. April 2009 peak power tracking error (after algorithm change).

To further monitor PPT, we examined data from both May and June 2009. The standard 

deviation of the PPT error was about 5% in May and 6% in June. Although this standard 

deviation is significantly lower than that of March and early April, it is still problematic for use 

in energy production calculations. Figure 6 presents the PPT error for May 2009, but it is also 

representative of the June 2009 data. In both months, high tracking errors (10%–35%) are seen 

in the morning, but low errors in the afternoon. 

Figure 6. May 2009 peak power tracking error (after algorithm change).

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Future plans are to continue to study the tracking-error data and to work with the DAS 

manufacturer to mitigate the problem. It is of particular interest to understand if there are any 

special considerations CPV presents in regard to PPT algorithms, because the effectiveness of 

grid-connected inverter operation may be impacted. As a result of these problems, the PPT data 

set is currently only used to provide meteorological information, whereas the I-V data set is used 

to study the electrical characteristics of modules under test.

5.0 Module Handling and On-Sun Alignment Procedures

The first two CPV modules (a test and a control) to be dedicated to the CPERT system arrived in 

February 2009. At that point, a module-handling plan had been discussed and was basically as 

follows: 

1) Inspect the module for visual defects or damage.

2) Consider points where water could enter the module if the tracker stowed in an upside-down 

position. Mitigate these possibilities with the permission of the manufacturer. (Not all 

trackers stow upside down.) 

3) Consider other possible failures that could occur due to not being mounted with 

manufacturer’s hardware and tracker. Mitigate concerns.

4) Match module electrical characteristics with a DAS channel.

5) Replace module connectors with MC2 connectors, if necessary.

6) Adjust 80/20TM mounting plane to accommodate module and fabricate any additional 

hardware needed for mounting. 

7) Wait for periods with a clear view of the sun to mount the module. 

8) Trim the tracker as needed to ensure less than 0.05 degree of tracking error.

9) Align the module with the sun using one of the following procedures: 

a. Attach a multimeter to the module and trim to achieve maximum Isc. 

 b. If the module has a sunspot and target, visually align. 

 c. After basic mount, run a tracker sweep while recording I-V curves.

10) Use electrical data and tracking error to determine if additional module trimming is needed. 

Trim and perform a verification tracker sweep.
13

With modules in hand, steps 1–6 can be followed with few problems, but once it is time to mount 

the module it gets more difficult. Weather patterns can change quickly in Colorado and 

experience has shown that it can take on the order of an hour to mount and align a module with 

the sun. Often, it was clear and sunny when mounting began; but by the time Isc measurements 

could be taken, clouds or haze had obstructed the sun. So far, it appears that most modules are 

not built with a sunspot and target to simplify alignment. In some cases, modules were roughly 

aligned to the sun, but a fine tuning of the alignment had to wait multiple weeks due to poor 

weather conditions. Using Isc maximization to fine-tune modules with acceptance angles less 

than 0.5 degree also proved to be very difficult. Attempts were made to hit the maximum Isc

within 2% for these modules, but tracker movement or slight changes in irradiance resulted in an 

Isc variation that was greater than 2%. After experience with several modules, the lessons 

learned point to the following steps for more accurately mounting and aligning a module: 

1) If possible with the given module size and weight, fabricate mounting brackets with three 

mounting bolts that are floating on springs. Simple turning of these bolts allows for tuning in 

azimuth or elevation. A particular module was delivered with holes for three-point mounting 

and this proved to speed the sun-alignment procedure and provide more accurate tuning. 

Unfortunately, not all modules facilitate this approach. 

2) Mount the module when there is available time. The accuracy of the tracker plane dictates a 

pointing accuracy of about 0.2 degree. Note in the data log that the module has not been 

accurately aligned if sun was not available. Fine tuning can be done more quickly when the 

sun appears now that initial mounting is complete. 

3) If the sun is only appearing for short periods each day, some fine tuning can be achieved by 

trimming to Isc measurements.

4) Accurate fine tuning can be achieved when clear skies are available for an hour or longer in 

the 4 hours surrounding solar noon. With narrow acceptance-angle modules, fine tuning should 

be done using tracker sweeps and measurements taken with the DAS. 

As mentioned in the last step for module mounting, tracker sweeps were found to be the most 

accurate method for aligning modules with the sun. It is worthwhile to provide additional details 

of this process and present some of the data that have been generated. The existing controller 

provides the ability to track off sun by a specified offset command for azimuth and/or elevation. 

The idea is to sweep through a range of azimuth and elevation tracking errors that is in the range 

of the module’s acceptance angle. This must be done within an hour time period that the 

irradiance is very stable (within two hours of solar noon and no clouds or haze). The faster the 

sweep can be performed and measured the better because this reduces variation in Isc due the 

time-dependent changes in DNI. For most modules, sweeping a sun-pointing error of ±1 degree 

in both azimuth and elevation is adequate for trimming a module. 
14

This process also provides a measurement of the module’s acceptance angle, but is limited to ±2 

degrees because the TEM no longer gives accurate measurement outside this range. The DAS is 

capable of taking I-V curves every minute; therefore, this is the shortest time interval that can be 

used to update the tracker offset as the sweep is performed. If the sweep is from -1 degree to 1 

degree in 0.1-degree increments, it then takes 21 minutes to perform a sweep in azimuth or in 

elevation. If this test sweep is performed under clear skies near solar noon, then the variation in 

DNI should be less than or equal to 1%. If it is necessary to shorten the sweep time, the tracking 

offset values can be more carefully chosen around the module’s acceptance angle. Figure 7 

displays the results from a sweep taken on a module that had been previously trimmed using Isc

measurements from a multimeter. The results indicate that the module has an acceptance angle 

of about ±0.25 degree, but that elevation alignment is off by about 0.1 degree. (For perspective, 

it only takes 24 seconds for the sun position to change by 0.1 degree.) 

Figure 7. Sweep data, module previously aligned using a multimeter.

The module presented in Fig. 7 was trimmed by an additional 0.1 degree and then another sweep 

was performed. The results of the second sweep are shown in Fig. 8. 

Figure 8. Sweep data for module characterized in Fig. 7 after 0.1-degree trimming. 
15

The second sweep confirms that the module is aligned to the sun with an acceptable accuracy. 

Results from other modules demonstrated similar results and so far the sweep procedure provides 

the best means to accurately align modules on sun. At this point the procedure requires manual 

inputs to the controller over the course of 45 minutes and then analysis of the data. Future work 

may consider taking steps to automate this sequence in the controller code. 

6.0 CPV Testing Procedures and Standards

As communication began with companies about sending CPV modules to NREL, discussions 

occurred as to what procedures would be followed for CPV testing. Because the CPV industry is 

so young, little precedent could be found. Typically, when a flat-plate module arrives, the 

measurements and characterization (M&C) group measures I-V curves under standard reference 

conditions, and a report is provided after indoor testing is completed for the module. In the case 

of CPV modules, indoor measurement protocols have not yet been established. Any CPV 

modules received by the M&C group have been mounted directly on a tracker, and I-V data have 

been taken over the course of a month or two. These data are then filtered to some degree before 

a performance report is generated using ASTM E 2527-06 to characterize module power. 

Although ASTM E 2527 can be used to rate CPV module power, at this time the CPV industry is 

far from consensus on standards for rating CPV for power or energy output. IEC 62108 (a 

qualification standard for CPV) does provide some reference to outdoor testing and a working 

group has been meeting regularly to develop an IEC standard for performance and energy 

ratings. 

It is worthwhile to examine the various standards being considered by the CPV industry and 

consider how data collected at NREL can aid this process. It is useful to consider how realistic it 

is to collect the data and follow the proposed procedures. On a more analytical level, the results 

generated by each procedure can be documented and compared against one another. 

A good starting point is to examine the outdoor testing called for in the IEC 62108 qualification 

standard. A side-by-side (control module and test module) I-V measurement is to be taken both 

before and after the test module has been subjected to stress testing. The objective is to see if the 

test module has dropped in power output relative to the control due to stress testing. This 

procedure calls for the following conditions to be met before and during the I-V test sequence:

• DNI > 700 W/m2 and DNI variation < 2% for any 5-minute interval

• No clouds/haze in a 45-degree angle around the sun 

• Wind < 6 m/s and no gusts >10 m/s in 10-minute interval before a measurement

• Module temperature variation < 2°C in any 1-minute interval

• Isc drop no more than 2% from maximum value due to misalignment. 
16

Although it may sound straight forward to mount two modules on a clear day and perform a 

couple I-V sweeps, experience at NREL has demonstrated that this can be time consuming to 

complete. First, as has been discussed in this report, aligning a module with the sun to within 

2% of the maximum Isc can require mounting the module and then commanding the tracker 

through an azimuth and elevation sweep. This procedure requires a mid-day time slot with clear 

skies for up to an hour. Depending on location and the time of year, this could take weeks to 

achieve. The same is true for waiting for the clear skies, low wind, and the stable temperature 

needed to take just two I-V curves.

This project is not currently geared toward qualification testing, but there is an interest in 

monitoring long-term degradation. In some cases, manufacturers are sending NREL both a test 

module and control module. In this event, plans are to use a similar, but alternative, procedure to 

that of IEC 62108. The test and control modules are mounted side-by-side by the procedure 

documented in the mounting section of this document. After successful mounting, the modules 

are left under the control of the DAS previously described. The modules are left on sun for 

about two weeks, of which at least one day has clear skies for at least one hour in a 4-hour period 

surrounding solar noon. The data are filtered to meet the DNI, wind, and temperature 

requirements. No visual observations or pictures are available to verify that there are no clouds 

within 45 degrees around the sun, but the data are rejected if the diffuse radiation (GNI-DNI) is 

greater than 140 W/m2

. The data remaining after filtering are used to calculate the relative 

power between modules. Multiple data points provide for multiple calculations that then are 

averaged. This procedure has currently been used when modules initially arrive at NREL, and 

plans are to repeat the procedure annually to separate on-sun degradation from degradation 

mechanisms that may occur in the dark. 

An additional procedure in IEC 62108 requires that a CPV module be on sun for 1,000 kWh/m2

of cumulative DNI, excluding time periods when the DNI is less than 600 W/m2. The test 

requires that the module be under load and tracking the sun. After the cumulative DNI is 

achieved, the module should have no major visual defects and power degradation should be no 

more than 7%. Modules are currently mounted on sun and are accumulating DNI hours on the 

CPERT testbed. It is still unknown as to how long this process will take and how module power 

should be defined to characterize the degradation. Future reports will document the average 

number of days needed to achieve 1,000 kWh/m2 of cumulative DNI at NREL and what methods 

are chosen to report power degradation. 

In late 2008, the IEC TC82 working group 7 (WG7) was considering several possibilities for 

power rating, but the consensus was to gather data before narrowing down the choices. In an 

effort to support WG7 efforts, NREL CPERT data are being used to compare ASTM E 2527 

with a procedure used at the Instituto de Sistemas Fotovoltaicos de Concentracion (ISFOC) in 

Spain. 
17

The ASTM procedure calls for measurement of DNI, ambient temperature (Tamb), wind speed 

(W), and Pmax (Pm) under specific conditions listed in Table 6. This set of measurements is to be 

repeated at least 20 times, and then a multiple linear regression is run on the data as given by 

Eq. 1, where a1 through a4 are the coefficients of the regression:

 . (Eq. 1)

If the standard error of the power estimate is greater than 3%, the data are rejected and the 

process is repeated. If the standard error is acceptable, the ASTM standard test conditions in 

Table 6 are substituted into Eq. 1 and the module power is calculated. 

The ISFOC procedure calls for measurement of DNI, heat-sink temperature, wind speed, and I-V 

curves under the specific conditions listed in Table 6 [5]. At least fifteen I-V curves are to be 

taken, and then each I-V data pair is to be translated to ISFOC standard test conditions given in 

Table 6. 

Table 6. ASTM and ISFOC Data Restrictions and STCs

ASTM E 2527 Standard test conditions ISFOC Standard test conditions

Ambient Temperature (20°C) Cell Temperature (60°C)

Wind Speed (4 m/s) Wind Speed (no requirement)

DNI (850 W/m2) DNI (850 W/m2)

ASTM E 2527 Data restrictions ISFOC Data restrictions

No visible clouds within 10 ̊ of sun No clouds immediately around sun

DNI >750 W/m2 DNI > 700 W/m2, also check for stability

Ambient temperature within 10°–30°C Thermal stabilization of module

Average wind speed for previous 5 minutes does 

not exceed 5 m/s

Average wind speed for previous 5 minutes does 

not exceed 3.3 m/s

Minimum of 20 data points Minimum of 15 I-V curves

Equations 2, 3, and 4 are used to translate the I-V data pairs to standard test conditions in Table 

6. Table 7 provides definitions for the variables used and also provides specifications for typical 

triple-junction cells. These triple-junction specifications are used in all NREL calculations 

regardless of module manufacturer. Although ISFOC’s procedure allows for making generalized 

assumptions for cell specifications, it is preferred that the manufacturer provide specifications for 

the cells being used [6]. 

 (Eq. 2) 

( ) max 21 3 amb +++= 4WaTaDNIaaDNIP

( )( )( )

[ ] 















+ −++ −































−×  − − − +=

cell measure

STC

cells ocggg measure

SCSCSC

STC cell measure SC measure SC measure SC measure

trans measure cells

T

T

VEEEN

III

TT IIIIII

VV N

,

,321

3,2,1,

, 1, 2, 3,

( ) 1

ln

297

(0257.0 )
18

 (Eq. 3) 

 (Eq. 4) 

Table 7. Variable Definitions and Specifications for Triple-Junctions Cells

Assuming triple-junction cells GaInP, GaAs, Ge with current densities12.3, 15, and 20 mA/cm2, 

respectively (assume spectral conditions are such that GaInP is the current-limiting junction)

STC Standard Test Conditions (See Table 6)

DNI Direct-normal irradiance measurement (W/m2)

DNISTC DNI at STC, which is 850 W/m2

Eg1 Bandgap for the top junction, assumed to be 1.85 eV

Eg2 Bandgap for the second junction, assumed to be 1.425 eV

Eg3 Bandgap for the third junction, assumed to be 0.66 eV

Itrans Translation of measured current to STC (A)

Imeasure Single current measurement from the I-V curve (A)

Isc,measure Short-circuit current from the measured I-V curve (A)

Isc,1 Isc for the top junction of the solar cell,  Isc,1=Isc,measure (A)

Isc,2 Isc for the 2nd junction of the solar cell,  Isc,2=Isc,measure( ) (A)

Isc,3 Isc for the 3rd junction of the solar cell,  Isc,3=Isc,measure( ) (A)

Ncells Number of cells in series for the module under test

Ptrans Translated power, which is the product of Itrans and Vtrans (W)

Rth,sys Thermal resistance between the heat sink and the cell ( ̊C/(W/m2))

Th-s Measured temperature of the heat sink or back plate of the module( ̊C)

TSTC Temperature of the cells at STC (60°C

Tcell,measure Cell temperature as calculated from a heat sink temperature measurement( ̊C)

Vtrans Translation of measured voltage to STC (V)

Vmeasure Single voltage measurement from the I-V curve (V)

Voc,measure Open-circuit voltage from the measured I-V curve (V)

It should also be noted that the procedure used at ISFOC is a method for rating CPV power at the 

system level; but in this report, it is being applied at the module level.

Both the ASTM and the ISFOC procedures presented some difficulties and neither was followed 

to exact specifications. In both cases, it is expected that measurements will be taken over a short 

period of time when an individual is present to verify there are clear skies around the sun. 

Although this is possible, it is labor intensive and deemed outside of the scope of this work. 

For all modules on the CPERT testbed, the DAS was connected and left to automatically collect 

data. As an alternative to visual verification of clear skies, filtering is applied to the data set. 

DNI

DNI II STC trans measure ∗=

Tcell,measure sh RDNIT th,sys − ⋅+=

junction current

junction current

1

2

junction current

junction current

1

3
19

The DNI is examined for the 5-minute period prior to execution of an I-V curve. If the DNI 

varies more than 2% during this period, the data point is filtered out. This is assumed to remove 

time periods when clouds are passing by the sun and also provides one of the checks on stability 

that the ISFOC procedure requires. In attempts to filter out hazy conditions, data are excluded if 

the diffuse radiation (GNI-DNI) is greater than 140 W/m2. Rather than using just 15 or 20 data 

points, the data set is analyzed in monthly blocks, which can easily be more than 1,000 points. A 

larger data set will provide a more statistically valid analysis assuming filtering ensures that the 

specified test conditions are met. We expect that the standard deviation will increase with the 

larger data set if there are other variables driving module power that are not included in the 

analysis. The data set has also been filtered to meet required DNI thresholds, caps on average 

wind speed, and the ASTM ambient temperature range. In addition, tracker pointing error was 

limited to 0.15 degree. The ISFOC procedure requires thermal stability of the module, but does 

not quantify this specification. Module temperature was restricted to a variation of 2 ̊C or less in 

the five minutes prior to an I-V curve. Table 8 displays the monthly power ratings, for both the 

ASTM and ISFOC method, for all CPV modules tested through June 2009. 

Table 8. Module Power Ratings Based on ISFOC and ASTM Procedures

Module # Method March April May June

Module 1 installed

late February

ISFOC* Power 110.5 W 111 W 105.4 W 96.3 W

% S.D. ** 5.47% 3.9% 4.6% 4.2% 

# of data 296 273 139 611

ASTM Power 108.2 W 110 W 108 W 97.9 W

%S.E. *** 5% 4.4% 4.6% 2.5%

# of data 264 344 235 737

Module 2 installed 

mid

March

ISFOC* Power 68.1 W 67.1 W 68.9 W 69.7 W

% S.D. ** 4.58% 5.66% 2.67% 3.9%

# of data 83 274 141 599

ASTM Power 69.5 W 68.2 W 69.5 W 71.3 W

%S.E. *** 1.9% 3.5% 2.1% 2.4%

# of data 111 339 227 734

Module 3  

installed May 

ASTM Power 77.2 W 78.4 W

%S.E. ** * 2.5% 2.9%

# of data 228 741

Module 4 ****

installed late May

ASTM Power 111 W 110 W

%S.E. ** * 1% 2.6%

# of data 112 702

* Only the peak power point of each I-V curve was translated to produce these results

** S.D. represents the standard deviation of power translations from the entire set of I-V curves

*** S.E. represents the standard error of the estimate of Pmax for the regression data set

**** ISFOC was not applied to these modules; the manufacturer did not supply Rth_sys 
20

Examining the data in Table 8, the two power rating procedures produce similar results. The 

greatest difference between the ratings for any one month is about 2.5%, and this is within the 

standard deviation of any of the comparative ratings. It should be noted that Module 1 was 

removed from testing after June as a result of at least one individual cell failure. Close 

investigation of the data suggests that the failure occurred in the second half of May. Module 2 

appears to increase in power from May to June, which coincides with an improved sun alignment 

(this increase is well within the standard deviation and may not be real). The ISFOC procedure 

was not applied to Modules 3 and 4 because the manufacturers could not provide a thermalresistance measurement for calculating cell temperature from heat-sink temperature. The 

difficultly in measuring or calculating cell temperature is one of the major weaknesses of the 

ISFOC method. The ASTM method requires no specific knowledge about the module being 

tested, and multiple linear regression is a valid statistical means to account for the relationship 

between the predictive variables and power output. Plans are to expand the comparison between 

ISFOC and ASTM to other modules by using Voc measurements to calculate cell temperature. 

Work will also be expanded to consider other procedures for power and energy ratings. In 

particular, the CPV community is considering a matrix method similar to that in the flat-plate 

standard, IEC 61853. This procedure creates a matrix that characterizes module performance at 

an array of irradiances and temperatures. Questions have been raised as to what ranges of 

temperatures and irradiances are valid for CPV. CPERT data over both winter and summer 

months will be used to consider these questions and report on challenges and strengths of the 

method. 

7.0 Module Energy Production

Four different CPV module technologies are currently on sun and under peak power tracking on 

the CPERT testbed. Power ratings at STC have been calculated for each module, but this falls 

short of determining how well the modules are performing. Ultimately, energy production must 

be considered and a simple way to do that is to calculate the ratio of energy produced to the 

energy incident on the modules in the form of direct-normal irradiance. Although it would be 

best to report kWh/kWh data from the 1-minute averaged PPT data, due to the problems reported 

earlier in regard to PPT, the results are generated from the I-V data. I-V curves are taken every 

five minutes and only when DNI is above 250 W/m2

. I-V curve data were removed if sunpointing error was greater than 0.2 degree and if the DNI changed more than 10 W/m2 while I-V 

curves were being recorded. Monthly efficiencies are reported for all modules in Table 9 as 

calculated by taking the ratio of kWh produced to DNI kWh incident on the module.
21

Table 9. Module kWh/kWh for Monthly Data Sets

Monthly module efficiency

March April May June

Module 1 0.162 0.158 0.152 0.139

Module 2 0.24 0.239 0.239 0.244

Module 3 0.219 0.225

Module 4 0.221 0.219

In addition to monthly efficiencies tabulated in Table 9, Fig. 9 displays the efficiency trend over 

the course of a sunny day. Figure 10 represents the DNI that accompanies the efficiencies shown 

in Fig. 9. 

Figure 9. Module efficiency vs. time of day (June 22, 2009).

This particular day suggests that several of the modules are less efficient during the mid-day 

hours. Future work will examine this trend more closely for larger data sets and will look for 

correlations between efficiency and temperature, spectral conditions, and other possible 

variables.

5

10

15

20

25

30

5 7 9 11 13 15 17 19

Aperture efficiency

Hour of Day June 22nd

Module1 Module2 Module3 Module4
22

Figure 10. DNI vs. time of day (June 22, 2009).

8.0 Conclusions and Future Work

This report attempts to address the various aspects of setting up a CPV testbed and procedures 

for handling and testing CPV modules. We suggest that a CPV testbed requires a sun-tracking 

accuracy of at least ±0.25 degree, but ±0.05 degree is ideal. Tracking controllers associated with 

high-accuracy tracking are discussed. We argue that a CPV testbed must also have a TEM for 

verification of tracking accuracy and for data validation and filtering. DAS requirements are 

developed and presented in the context of current and future CPV modules. We developed a 

procedure for accurately aligning CPV modules on NREL’s tracker.

Two power rating methods are evaluated using data from two modules. Although the methods 

follow very different procedures and present separate challenges, they both provide similar 

power ratings for each module. The monthly energy efficiency is reported for four different 

module technologies. The lowest monthly efficiency is 14%, whereas the highest is 24%. We 

note that the lowest monthly efficiency came from a module that was subsequently removed 

from testing due to a failure at the cell level. Instantaneous module efficiency is plotted over a 

sunny day, and two of the four modules show a nearly 2% drop in efficiency for the mid-day 

hours. The peak instantaneous efficiencies range from 15% to 26% for the four modules. Other 

than the verified cell failure in Module 1, we see no statistically significant degradation.

Future work is proposed for both the CPV testbed and in the test and evaluation of CPV 

modules. We are considering retrofitting the tracker with a hybrid controller to reduce tracking 

error to the ±0.05 degree range. Additional tracking-error monitors are planned to better 

characterize flex in the test plane and for monitoring tracking accuracy in the field. Ongoing 

collaboration is occurring with the DAS manufacturer to improve peak power tracking accuracy. 

200

300

400

500

600

700

800

900

1000

1100

5 7 9 11 13 15 17 19

DNI W/m2

Hour of Day June 22nd
23

CPV standards development is being following and module data will be used to evaluate the 

matrix method for power ratings, as well as continued evaluation of the methods listed in this 

report. Efficiency variations need to be closely analyzed, and SRRL data sets can be used to 

examine possible spectral effects on modules with triple-junction cells. Additional module 

technologies need to be deployed on CPERT, and all modules will be monitored for long-term 

degradation. 

9.0 Acknowledgements

Appreciation is extended to Jose Rodriguez for his help in building the CPERT testbed and his 

continued support with PV module testing. Acknowledgements also go to Bill Marion and Sarah 

Kurtz for their ongoing advice and assistance with CPV work. Special thanks to Gary Galbraith 

for his expertise provided regarding tracking-error monitors, Chris Deline for his help with 

electronic control circuitry, and Joe DelCueto for his experience with multi-tracers. This work 

was supported by the U.S. Department of Energy under Contract No. DE-AC36-08GO28308 

with the National Renewable Energy Laboratory. 

10.0 References

1. A. Maish, The Solartrak Solar Array Tracking Controller, Sandia Report, SAND90-

1471, 1991. 

2. C. Ward, C. Maxey, B. Evans, and M. Lapsa, “Versatile Two-Axis Open-Loop Solar 

Tracker Controller,” ASES 2008. 

3. I. Luque-Heredia, R. Cervantes, and G. Quemere, “A Sun Tracking Error Monitor for 

Photovoltaic Concentrators,” 4th IEEE World Conference on Photovoltaic Energy 

Conversion, 2006.

4. G. Galbraith, Development and Evaluation of a Tracking Error Monitor for Solar 

Trackers, Sandia Report, SAND88-7025, 1988. 

5. M. Martinez, F. Sanchez, J. Pachon, and P. Banda, “CPV Systems Rating, Results and 

Lessons Learned at ISFOC,” ICSC-5, 2008. 

6. ISFOC, “Specifications of General Conditions for the Call for Tenders for Concentration 

Photovoltaic Solar Plants at IFOC,” 2007. 
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Development of an Outdoor Concentrating Photovoltaic Module 

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14. ABSTRACT (Maximum 200 Words)

In recent years, the concentrating photovoltaic (CPV) industry has rapidly expanded as many new companies have 

entered the market. Each company has a unique approach aimed at making CPV a reliable, low-cost alternative to 

traditional flat-plate photovoltaics. As with other new technologies, a need arises to establish appropriate standards, 

testing requirements, and a better understanding of the technology itself. Solar Energy Technologies Program 

money has been awarded to some of these manufacturers, and as a result, the Test and Evaluation group at the 

National Renewable Energy Laboratory (NREL) has been tasked with evaluating some of the associated 

deliverables. To achieve this task and fulfill the above needs, NREL’s Test and Evaluation group made plans to build 

a testbed for CPV. This report addresses the issues associated with building a CPV testbed and presents initial 

results from module testing. In particular, there is a focus on high-accuracy two-axis tracking, monitoring tracking 

error, CPV data acquisition, module handling and testing procedures, and standards development. Finally, initial 

power ratings and efficiency results are presented.

15. SUBJECT TERMS

PV; Outdoor Testing Facility; testbed; module; concentrating photovoltaics; two-axis tracking; testing and evaluation; 

tracking error; procedures; power rating; efficiency;

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