Performance Test Protocol for Evaluating Inverters Used in Grid-Connected Photovoltaic Systems

Prepared by

Ward Bower

Sandia National Laboratories

Photovoltaic Systems Applications

Albuquerque, NM 87185-0753 USA

Chuck Whitaker

Endecon Engineering

San Ramon, CA

William Erdman

Lafayette, CA

Table of Contents

SectionPage

1Overview......

1.1Objectives:......

1.2Approach and Methodology......

1.3Scope and Purpose......

2Definitions......

3Safety Considerations......

4Background and Test Overview......

4.1Inverter Size......

4.2Testing Considerations......

5Test Procedures and Criteria......

5.1General Requirements......

5.2Test Equipment Requirements......

5.2.1Inverter DC Input Power Supply (PV Array Simulator) Requirements:......

5.2.2Inverter AC Output (Simulated Utility) Power Supply Requirements:......

5.3DC Input Characterization......

5.3.1Maximum Power Point Voltage Tracking Range......

5.3.2Maximum Power Point Current Tracking Range......

5.4Inverter Efficiency......

5.4.1Test Procedure......

5.4.2Reported Values......

5.5Maximum Power Point Tracking Accuracy......

5.5.1MPPT Steady State Response Test:......

5.5.2MPPT Dynamic Response Test:......

5.6Tare Losses......

5.6.1Test Procedure - Tare Level......

5.6.2Test Procedure - Input Power Level, Startup......

5.6.3Test Procedure - Input Power Level, Shutdown......

5.6.4Reported Values......

5.7Power Foldback......

5.7.1Power Foldback with Temperature......

5.7.2Power Foldback with High Array Output......

5.8Inverter Performance Factor/Inverter Yield......

5.8.1Test Procedure......

5.8.2Reported Values......

6Glossary of Acronyms......

7References......

Annexes......

A1Simplified Photovoltaic IV Curve Model......

A2IV Curve Translation......

A3PV Array Simulator Description......

A3.1PV Array Simulator Calibration......

A3.2PV Array Simulator Validation......

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Inverter Performance Test Protocol

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Sandia Inverter Performance Test Protocol

Performance Test Protocol for Evaluating Inverters Used in Grid-Connected Photovoltaic Systems

1Overview

One measure of the maturity of an industry is the extent to which it has adopted standardized test procedures to establish minimum levels of safety, reliability, quality and performance. The existence of PV product listing procedures (UL1703 for photovoltaic modules, UL1741 for inverters) has gone a long way to provide consumers and building and electrical inspectors with the necessary assurance regarding safety and installation requirements. Currently, there is no standardized methodology or testing body for inverter performance. With over 10,000 inverters installed in grid-tied PV systems worldwide by the end of 2002, there is clearly a market for these products. The development of standard test procedures and a corresponding certification program that delivers accurate, believable estimates of inverter performance and, ultimately, system performance, is needed to ensure that market claims and customer expectations are being met.

1.1Objectives:

The objective of this document is to provide a test protocol for evaluating and certifying the performance of inverters for grid-connected photovoltaic system applications[1]. Tests that are conducted for listing and interface compatibility, well documented, and performed in a consistent manner with published accuracy will not be repeated in this test protocol. Tests needed for “Certification” are either "Recommended" or "Required" to indicate the importance of the test results in predicting performance of the inverter or ultimately a photovoltaic system. Some tests, now performed only by the manufacturer and generally used to verify design or algorithms, may need more specific procedures and equipment call outs in order to satisfy certification-testing requirements.

Considerations taken into account for determining tests that are needed for certification include the following:

  1. The needs for certification (performance verification, industry-wide performance improvements, elimination of misleading claims, manufacturer-specific or model-specific ratings)
  2. The type of certification (hardware compatibility, safety, performance or operation of multiple units.
  3. The value of further testing for certification.
  4. The costs of certification.
  5. The effectiveness of the certification results.
  6. The required accuracies.
  7. The applicability of the certification results in all situations.

1.2Approach and Methodology

The following steps were used to determine the requirements for further certification testing.

  1. Survey and then list all possible (old and new) types of testing methods and requirements in existence.
  2. Tabulate tests in use and determine where to expand the tests.
  3. Formulate a draft protocol based on needs to certify inverter performance.
  4. Choose tests that are necessary, repeatable, possible under less than ideal conditions, and economical.
  5. Obtain industry/expert feedback.

1.3Scope and Purpose

This document provides guidelines for tests for the certification of grid-connected inverters with or without energy storage. The tests results will provide information not generally found on today's specification sheets, on listing labels or other labels. The guidelines will help to:

  1. Determine that the inverter functionally meets the design and interconnect requirements,
  2. Verify or establish inverter performance when used in conjunction with a photovoltaic system that is properly sized and rated.
  3. Verify or establish other relevant inverter performance characteristics.

The tests described in this document apply to grid-connected inverters as well as the stand-alone features of inverters that serve dual roles. They may also be adopted for other uses. Tests cover the inverter operation, performance, the photovoltaic array interface, and the ac grid interface. The tests for operation and performance are conducted over a range of temperatures and array characteristics. In addition to inverter performance certification, these tests may also be performed for troubleshooting or to evaluate performance and operation at any point in the life of the inverter.

Tests related to provisions and verification of controls, protection features, and alarms are included to verify operation and to allow expansion of those tests beyond what is required or recommended for certification. Performance tests including efficiency, MPPT accuracy, voltage and current operating windows, power quality, array utilization and features such as set points for out of tolerance ac and dc conditions will be performed as recommended or required for certification.

These tests are supplementary to UL1741 and are not intended to duplicate or conflict with the UL1741 power quality, utility interconnection requirements, or safety.

2Definitions

The following definitions are pertinent to performance certification of inverters.

2.1Data Acquisition System (DAS): A system that receives data from one or more locations. (from IEEE Std. 100-1996)

2.2Disconnect Switch: A switching device that breaks an electrical circuit. These devices may have ac or dc voltage and current ratings and may or may not be rated for breaking under load. Disconnect switches usually provide a visible break, and may have a locking feature to provide control over the status of the disconnect switch.

2.3Efficiency: The ratio of the output power to the input power.

2.4Interconnection: The equipment and procedures necessary to connect an inverter or power generator to the utility grid. IEEE Std. 100-1996 Def: The physical plant and equipment required to facilitate transfer of electric energy between two or more entities. It can consist of a substation and an associated transmission line and communications facilities or only a simple electric power feeder.

2.5Inverter: A machine, device, or system that changes direct-current power to alternating-current power. For the purposes of this test procedure, the inverter includes any input conversion (i.e., dc-dc chopper) that is included in the inverter package and any output device (i.e. transformer) that is required for normal operation.

2.6Islanding: Continued operation of a photovoltaic generation facility with local loads after the removal or disconnection of the utility service. This is an unwanted condition that may occur in the rare instance of matched aggregate load and generation within the island.

2.7I-V Curve: A plot of the photovoltaic array current versus voltage characteristic curve.

2.8Listed Equipment: Equipment, components or materials included in a list published by an organization acceptable to the authority having jurisdiction and concerned with product evaluation, that maintains periodic inspection of production of listed equipment or materials, and whose listing states either that the equipment or materials meets appropriate standards or has been tested and found suitable for use in a specified manner. (from the National Electrical Code; Article 100.)

2.9Maximum Power Point: The point on the array IV Curve that yields the greatest output power.

2.10Maximum Power Point Tracker (MPPT): A function included in an inverter or in a separate device, that attempts to operate and maintain a PV array at its Maximum Power Point

2.11Parallel / Paralleling: The act of synchronizing two independent power generators (i.e. the utility and a photovoltaic power plant) and connecting or “paralleling” them onto the same buss. In practice, it is used interchangeably with the term interconnection. IEEE 100 Def.: The process by which a generator is adjusted and connected to run in parallel with another generator or system.

2.12Power Conditioning Subsystem (PCS): The subsystem (Inverter) that converts the dc power from the array subsystem to ac power that is compatible with system requirements. (From 100-1996) See also Inverter.

2.13Power Conditioning Unit, PCU: A device that converts the dc output of a photovoltaic array into utility-compatible ac power. The PCU (Inverter) may include (if so equipped) the array maximum power tracker, protection equipment, transformer, and switchgear. See also Inverter, Power Conditioning Subsystem (PCS), and Static Power Converter (SPC).

2.14Power foldback: An operational function whereby the unit reduces its output power in response to high temperature, excessive input power, or other conditions.

2.15Supervisory Control and Data Acquisition (SCADA): Utility equipment used to monitor and control power generation, transmission, and distribution equipment. (IEEE Std 100 Def): A system operating with coded signals over communication channels so as to provide control of remote equipment (using typically one communication channel per remote station). The supervisory system may be combined with a data acquisition system, by adding the use of coded signals over communication channels to acquire information about the status of the remote equipment for display or for recording functions.

2.16Static Power Converter: Any static power converter with control, protection, and filtering functions used to interface an electric energy source with an electric utility system. Sometimes referred to as inverter, power conditioning subsystem, power conversion system, solid-state converter, or power conditioning unit. (Preceding is from 100-1996). The term solid-state inverter is intended to differentiate a solid-state device from a mechanical motor-generator type converter. See Inverter.

2.17Standard Reporting Conditions (SRC): For photovoltaic performance measurements, a fixed set of conditions that constitute the device temperature, the total irradiance, and the reference spectral irradiance distribution to which electrical performance data are translated. (See ASTM Std E 1328)

2.18Standard Test Conditions (STC): A particular set of SRC defined as 1000W/m2 irradiance, 25C cell temperature, and Air Mass 1.5 spectrum (See ASTM Std. E 1328).

2.19Utilization: (Array Utilization): The ratio of the maximum available energy (power) to the energy (power) that is extracted from the module or array.

2.20Utility: For this document, the organization having jurisdiction over the interconnection of the photovoltaic system and with whom the owner would enter into an interconnection agreement. This may be a traditional electric utility, a distribution company, or some other organization. IEEE 100 Def: An organization responsible for the installation, operation, or maintenance of electric supply or communications systems.

3Safety Considerations

Standard electrical system safety practices should be strictly adhered to during the evaluation of or testing of a grid-interactive inverter for a photovoltaic system.

4Background and Test Overview

This document is based on the results of surveys of industry participants, installers and manufacturers and a compilation of available standards for testing photovoltaic inverters. Test protocol and procedures were provided by scientists and engineers associated with Sandia National Laboratories, Endecon engineering, and the Southwest Technology Development Institute.

The tests and criteria described in Section 5 were chosen to test inverters from the photovoltaic array through the inverter in a utility-interactive photovoltaic system. Tests will be for compliance with specifications and to evaluate the photovoltaic array interface, the inverter operation, the ac interfaced and the inverter performance in the system. Suggested sequences for the tests are described below in Section 6.

4.1Inverter Size

Test procedures and criteria are sometimes a function of the size of the system or inverter being tested. For simplicity, three sizes are categorized within this document roughly defined as

Small:10-kW or less (may provide single- or three-phase output)

Medium:10-kW to 100-kW (usually three-phase output)

Large:100-kW and greater (usually three-phase output).

These size specifications are meant to provide general guidelines for testing and not to restrict testing to distinct categories. Unless otherwise stated, tests are not size-dependent.

4.2Testing Considerations

Determination of which of the tests described in this document should be performed for certification will depend on many factors. Some tests may be required by the utility. Other tests may be standard practice of the buyer or installation contractor. Still other tests may be administered to verify a new product or installation procedure. In some cases, certified factory test results may suffice in lieu of further testing for certification. Some tests like the array utilization due to MPPT abnormalities can be extremely difficult since the efficiency also changes with MPP operating points. These tests must be examined in great detail to make sure the tests are practical and economical.

This test protocol for performance certification provides the recommended procedure for each aspect of inspection, test, or calibration. Exact procedures and evaluation criteria may have to be modified based on system size and local requirements, and by referring to the manufacturer's instruction, data sheets, specification, drawings, and other applicable documentation.

Some of the performance certification tests may also be conducted periodically over the life of the photovoltaic system to ensure that reliable and expected operation is maintained and that maintenance may be needed.

Performance certification test reports and manuals should normally be retained by the system owner for all major equipment such as custom transformers, switch gear, inverters, drive motors, tracking controllers, instrument transformers, etc. The manufacturer's certified “Test and Calibration” reports for major equipment may eliminate the need for field-testing some of these components.

5Test Procedures and Criteria

5.1General Requirements

For convention, power from the inverter to the simulated utility is considered positive and power from the simulated utility to the inverter is considered negative.

5.2Test Equipment Requirements

Unless otherwise specified, the requirements in this section apply to all test procedures Basic measurement requirements are provided in Table 51.

Table 51 Basic Measurement Requirements

Parameter / Minimum Accuracy
DC Voltage / ± 1% of reading
AC Voltage / ± 1% of reading
DC Current / ± 1% of reading
AC Current / ± 1% of reading
AC Frequency / ± 0.05 Hz
Temperature / ±1°C

Ambient temperature shall be measured 6 to 12 inches horizontally away from the enclosure and at the mid point of the height of the enclosure,

Inverter temperature shall be measured at the switching device, or as close as practical.

5.2.1Inverter DC Input Power Supply (PV Array Simulator) Requirements:

For efficiency measurements the inverter dc input supply (or the PV array simulator) shall meet the following minimum specifications (for this test, the Input supply does not necessarily have to provide a PV-like IV curve, though such a power supply or an appropriately sized PV array may be used.):

  1. a maximum voltage ripple of 1.0% over the range of expected operation
  2. rated continuous output of at least 200% of the inverter rated input over the range of inverter input voltage
  3. Adjustable output voltage range of at least the inverter input voltage range

When the dc source has little or no surge limitations, an external series R/L impedance inserted between the power supply output and inverter input may be necessary to

  • limit surges to the inverter
  • isolate the power supply output from the inverter input and eliminate unwanted interactions (i.e. the dc supply regulator controlling the operating point of the inverter or visa-versa)

The PV array simulator described in Annex A.3 may be used in lieu of a real PV array to provide a current-voltage characteristic curve (IV curve) representative of a variety of PV technologies, when such characteristics affect the test results.

5.2.2Inverter AC Output (Simulated Utility) Power Supply Requirements:

For efficiency measurements the ac output power supply (simulated utility) shall meet the following minimum specifications:

  1. a maximum THD of 1.5%
  2. a maximum impedance less than 5 percent of the inverter output impedance where the inverter output impedance is equal to the inverter rated output voltage divided by the inverter rated output current at unity power factor. (Inverter Rated Output Power)/(Inverter Output Current at Rated Power) at fundamental frequency. (The impedance may be a series/parallel combination of resistance and inductance so as to present reasonable impedance at all frequencies while limiting losses)
  3. rated power input (sink) of at least 200% of the inverter rated output
  4. be able to sink full power over the entire operating voltage range of the inverter.
  5. adjustable voltage and frequency ranges at least equal to those of the inverter under test.
  6. Frequency stability – frequency shall not change by more than ±0.1 Hz during any single test.
  7. a response to sudden changes that does not create voltage sags or surges to the inverter and
  8. time-constants associated with the reference waveform that are consistent with changes expected in output power associated with these tests.
  9. A slew rate for voltage change of at least 10Volts per cycle
  10. A slew rate for frequency of at least 1 Hz/cycle.
  11. The ability to withstand instantaneous switching to open circuits at the output

5.3DC Input Characterization

5.3.1Maximum Power Point Voltage Tracking Range

This test will determine the voltage range over which the MPPT operates and if the voltage of the operating point affects the controls or accuracy. The test shall be conducted with the actual maximum power point near the center of the dc current operating range specified by the manufacturer.

5.3.1.1Test Procedure

<TBD>

5.3.1.2Reported Values

<TBD>

5.3.2Maximum Power Point Current Tracking Range

This test will determine the current range over which the MPPT operates and if the current of the operating point affects the controls or accuracy. The test shall be conducted with the actual maximum power point near the center of the dc voltage operating range specified by the manufacturer. It is anticipated lowering the operating dc current levels will eventually disable the MPPT circuitry and that level shall be recorded.