APPENDIX_O.pdf

APPENDIX O

SMALL COMMERCIAL SOLAR ELECTRIC SYSTEM

(PHOTOVOLTAIC)

SECTION 48 14 00 - SMALL COMMERCIAL SOLAR ELECTRIC SYSTEM (PHOTOVOLTAIC )

PART 1 - GENERAL

1.1 RELATED DOCUMENTS

A. Drawings and general provisions of the Contract, including General and Supplementary Conditions and Division 01 Specification Sections, apply to this Section.

1.2 REFERENCES

A. The publications listed below form a part of this specification to the extent referenced. The publications are referred to within the text by the basic designation only.

AMERICAN SOCIETY OF CIVIL ENGINEERS

ASCE -7 (2006) Minimum Design Loads for Buildings and Other Structures

ASTM INTERNATIONAL

ASTM D 709 (2001; Rev 2007) Laminated Thermosetting Materials

INSTITUTE OF ELECTRICAL AND ELECTRONICS ENGINEERS (IEEE)

IEEE 519 (2004) Recommended Practices and Requirements for Harmonic Control in Electrical Power Systems

IEEE 1374 (1998) Guide for Terrestrial Photovoltaic Power System Safety

IEEE 1547 (2003; Rev thru Sep 2008) Interconnecting Distributed Resources with Elec-tric Power Systems

NATIONAL FIRE PROTECTION ASSOCIATION (NFPA)

NFPA 70 (2007; AMD 1 2008) National Electrical Code - 2008 Edition

UNDERWRITERS LABORATORIES (UL)

UL 1703 (2002; Rev thru Apr 2008) Flat-Plate Photovoltaic Modules And Panels

UL 1741 (1999; Rev thru Nov 2005) Standard for Static Inverters and Charge Control-lers for Use in Photovoltaic Systems

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1.3 SUMMARY

A. These specifications cover the procurement of equipment, hardware, documentation, labor and supervision required for the design and installation of one (1) nominal 19.9 kW grid-connected PV system. There shall be no energy storage devices (e.g. batteries) used in this system.

B. The PV system shall be designed for outdoor installation at Davis Monthan AFB, AZ. The region is semi-arid and subject to long-term high temperature conditions. The elevation is 2700 feet above sea level. Annual ambient temperatures can range from 30° F to 100° F. The nominal 3-second gust design wind speed is 90 mph. Supplied equipment must be rated and warranted to withstand and operate under these conditions.

C. The PV system shall be installed at site. The array shall be roof-mounted with non-penetrating clips attached to the standing seam portion of the roof in a manner that is in accordance with the manufacturer’s recommendations and acceptable to the Contracting Officer. This structure shall be installed with a horizontal tilt angle between 10 degrees and 60 degrees, and an azimuth angle of +/- 100 degrees of due south. (The specific horizontal tilt angle and azimuth angle will affect the Up-Front Incentive rebate payment. Coordinate installation angles with Tucson Electric Power Company.) The system shall be attached to the roof either parallel or perpendicular to the direction of the roof slope (not skewed).

D. The PV system shall be connected to the Tucson Electric Power Company electric grid through a grid-interactive power conditioner (inverter). The design and specification of the PV modules, power conditioners, utility interconnections, PV system electrical design, and PV array mechanical design shall comply with the requirements of Tucson Electric Power Company, the Arizona Corporation Commission and the requirements contain herein.

E. The PV system shall fully comply with all requirements of Tucson Electric Power Company to qualify for the Up-Front Incentive rebate payment through the Grid-Tied Non-Residential 20 kW or Less Solar Program administered by Tucson Electric Power Company.

F. The Contractor shall complete and process all documentation required to receive the Up-Front Incentive rebate payment from Tucson Electric Power Company. The Contractor shall coordinate the documentation and processing with the Davis Monthan AFB Energy Efficiency Manager, Mr. Greg Nobel (520-228-6026). Coordination shall be through the Contracting Office.

G. The Up-Front Incentive rebate payment shall be assigned to the Contractor and shall be reflected in the Contractor’s bid.

1.4 PERFORMANCE REQUIREMENTS

A. Delegated Design: Design, supervise, test, and inspect the installation of a photovoltaic system, including comprehensive engineering analysis by a qualified professional engineer, using performance requirements and design criteria indicated.

B. Select components and accessories for performance, durability, and ease of maintenance.

Design system for an estimated life of 25 years before replacement.

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C. Coordinate the design, installation and testing with Tucson Electric Power as necessary to qualify for the Up Front Incentive.

D. Prepare and organize all documentation required by Tucson Electric Power for approving the installation for the Up Front Incentive.

E. Locations of photovoltaic modules, inverters, meters and other materials shall be coordinated with and approved by the Contracting Officer.

1.5 DEFINITIONS

A. PV: Photovoltaic.

B. NABCEP: North American Board of Certified Energy Practioners.

C. STC: Standard Test Conditions.

D. TEP: Tucson Electric Power Company.

E. UFI: Up-Front Incentive.

1.6 SUBMITTALS

Government approval is required for submittals with a "G" designation; submittals not having a "G" designation are for information only. When used, a designation following the "G" designa-tion identifies the office that will review the submittal for the Government. The following shall be submitted in accordance with Section 01 33 00 SUBMITTAL PROCEDURES:

A. SD-02 Shop Drawings; G, DO

Include wiring diagrams and installation details of equipment indicating proposed location, layout and arrangement, panels, accessories, conduit, wiring and other items that must be shown to ensure a coordinated installation. Wiring diagrams shall identify circuit terminals and indicate the internal wiring for each item of equipment and the interconnection between each item of equipment. Drawings shall indicate adequate clearance for operation, maintenance, and replacement of operating equipment devices. Roof plan shall show scaled location of photovoltaic array.

B. SD-03 Product Data

Photovoltaic Modules; G, DO Photovoltaic Inverters; G, DO Check Meters; G, DO Spare Parts Spare parts data for each different item of material and equipment specified.

C. SD-05 Design Data; G, DO

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Calculations to determine the quantity of photovoltaic modules required. Factors relating to building orientation, array tilt and angle, and shading shall be included.

D. SD-06 Test Reports

Approved Test Procedures; G

Test plan and test procedures for the acceptance tests. The test plan and test procedures shall explain in detail, step-by-step actions and expected results to demonstrate compliance with the requirements specified. The procedure shall also explain methods for simulating the necessary conditions of operation to demonstrate system performance.

Acceptance Tests; G

Test reports in booklet form showing all field tests performed to adjust each component and to prove compliance with the specified performance criteria, upon completion and testing of the installed system. The reports shall include the manufacturer, model number, and serial number of test equipment used in each test. Each report shall indicate the final position of controls and operating mode of the system.

E. SD-07 Certificates

Components; G

Copies of current approvals or listings issued by UL, or other nationally recognized testing laboratory for all components.

F. SD-10 Operation and Maintenance Data

Electrical Systems, Data Package 5; G

Submit operation and maintenance data in accordance with Section 01 78 23 OPERATION AND

MAINTENANCE DATA.

1.7 QUALITY ASSURANCE

A. Qualifications, Design Engineer: Registered Professional Engineer with verification of experience and at least five (5) years of current experience in the design of the commercial solar photovoltaic systems.

B. Qualifications, Installer: The installing Contractor shall provide the following: NABCEP certified PV Installer to perform the installation of the system, or an installer listed on the Tucson Electric Power Company 2009 PV INSTALLER’S LIST. The installer shall have a minimum of 4 years of experience and shall be factory trained in the installation, adjustment, testing, and operation of the equipment specified herein.

C. Electrical Components, Devices, and Accessories: Listed and labeled as defined in NFPA 70, Article 100, by a testing agency acceptable to authorities having jurisdiction, and marked for intended use.

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1.8 WARRANTY

A. Photovoltaic System Warranty

1. Full Warranty: Furnish a full warranty on all parts and labor for a period of not less than twenty-four (24) months from the date of beneficial occupancy. The warranty shall include all parts and labor, including the cost of removing any defective component, shipping it to the manufacturer, and reinstalling the component after it is repaired or replaced.

B. Photovoltaic Module Warranty

1. Product Warranty: Furnish the photovoltaic module manufacturer's product warranty.

The warranty period shall not be less than ten (10) years from the date of delivery. The photovoltaic module shall be warranted to be free from defects in materials and workmanship under normal application, installation, use and service conditions. If the photovoltaic modules fail to conform to this warranty, then for a period ending not less than ten (10) years from date of manufacture, the manufacturer shall, at its option, either repair or replace the product. The replacement module shall be identical to, or an improvement upon, the original design of the malfunctioning photovoltaic module. The warranty shall state that the replacement module shall be promptly shipped to the using Government facility.

2. Power Warranty: Furnish the photovoltaic module manufacturer's power warranty. The warranty period shall not be less than twenty (20) years from the date of delivery. For not less than the first ten (10) years of the warranty period, the photovoltaic module power output shall be warranted to not drop below 90% of the Minimum Peak Power as specified at the date of delivery in the Product datasheet. For not less than the second ten

(10) years of the warranty period, the photovoltaic module power output shall be warranted to not drop below 80% of the Minimum Peak Power as specified at the date of delivery in the Product datasheet. If the photovoltaic modules fail to conform to this warranty, then for a period ending not less than twenty (20) years from date of manufacture, the manufacturer shall, at its option, replace such loss in power either by providing additional PV modules to make up such loss in power, or by providing monetary compensation equivalent to the cost of additional PV modules required to make up such loss in power, or by repairing or replacing the defective PV modules. The replacement module shall be identical to, or an improvement upon, the original design of the malfunctioning photovoltaic module. The warranty shall state that the replacement module shall be promptly shipped to the using Government facility.

C. Inverter Warranty

1. Product Warranty: Furnish the inverter manufacturer's product warranty. The warranty period shall not be less than ten (10) years from the date of delivery. The inverter shall be warranted to be free from defects in materials and workmanship under normal application, installation, use and service conditions. If the inverter fails to conform to this warranty, then for a period ending not less than ten (10) years from date of manufacture, the manufacturer shall, at its option, either repair or replace the product. The replacement inverter shall be identical to, or an improvement upon, the original design of the inverter.

The warranty shall state that the replacement inverter shall be promptly shipped to the using Government facility.

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1.9 COORDINATION

A. Coordinate layout and installation of PV modules with other construction that penetrates roof or is supported by roof, including lightning protection equipment, vents and other equipment.

PART 2 - PRODUCTS

2.1 PHOTOVOLTAIC MODULE AND ARRAY

A. Description: The photovoltaic module shall be a framed flat-plate crystalline/amorphous silicon module; complying with UL 1703.

1. The PV array shall be sized to achieve a nominal 19.9 kW DC STC output for the entire system under peak sun conditions (1000 W/m2). In general, AC output should be approximately 70% of the DC kW rating.

2. Each PV module shall include bypass diodes for protection against overheating.

3. Each PV module shall have an anodized aluminum frame and tempered glass front.

4. PV array mounting hardware shall be compatible with the site considerations and environment. Special attention should be paid to minimizing the risk from exposed fasteners, sharp edges, and potential damage to the modules or support structure.

Corrosion resistance and durability of the mechanical hardware should be emphasized – the use of stainless steel fasteners and an aluminum support structure is preferred. The use of ferrous metals, wood or plastic components is prohibited. Galvanic corrosion should be avoided.

5. To prevent excessive temperatures that decrease output and increase module degradation, PV array modules shall be installed with sufficient clearance to allow for proper ventilation and cooling. In no case shall PV modules be mounted less than 4 inches above any surface and an additional inch of clearance for each foot of continuous array surface beyond four feet in the direction parallel to the mounting support surface. Where manufacturer clearance recommendations exceed the aforementioned clearance, the installation shall comply with the manufacturer clearance recommendations.

2.2 INVERTER

A. Description: The inverter shall be designed specifically for utility grid interconnection of photovoltaic arrays and shall be capable of automatic, continuous, and stable operation over the range of voltages, currents, and power levels for the size and type of array used. The inverter shall comply with IEEE 519, IEEE 1547 and UL 1741.

1. The inverter shall have an automatic visual indicator showing whether the system is on-line or not.

2. The inverter shall not operate without the line voltage present. The inverter shall sense a

"loss of line" (utility) condition and shall automatically disconnect from the line. In the event of multiple inverters and/or balanced load on a common line, the inverter shall contain circuits (such as Sandia Voltage Shift and Sandia Frequency Shift) that will cause the inverter voltage or frequency to drift downwards under loss of line conditions and cause it to cease energizing the grid within two seconds after loss of line. The inverter restart shall occur automatically after restoration of line voltage and frequency for at least five minutes.

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3. The inverter shall provide maximum power point tracking for the full voltage and current range expected from the photovoltaic panels used and the temperature and solar insolation conditions expected at Davis Monthan AFB, Arizona.

4. The inverter shall be capable of adjusting to “sun splash” from all possible combinations of cloud fringe effects without interruption of electric production.

5. The inverter shall be installed with sufficient clearance to allow for proper ventilation and cooling. The installation shall comply with or exceed the manufacturer clearance recommendations.

6. The inverter shall include a by-pass switch allowing the inverter to be by-passed for maintenance or repair while the building loads remain connected to the utility grid or emergency generator.

7. The inverter, generator and utility power shall be interfaced such that the inverter output does not interfere with the specified and code mandated operation of the emergency generator.

2.3 NET (BI-DIRECTIONAL) UTILITY METER

A. The Net Meter shall measure the difference between the power delivered by TEP and the power received from the photovoltaic system.

B. The Net Meter shall be provided by TEP and installed by the Contractor in a meter socket installed in a readily accessible outdoor location ahead of the building service entrance disconnect. The meter location shall be unobtrusive and shall be coordinated with TEP and approved by the Contracting Officer.

2.4 CHECK METER

A. The Check Meter shall measure the energy generated by the photovoltaic system.

B. The Check Meter shall be provided and installed by the Contractor. The meter shall be digital and shall be designed for recess mounting in finished spaces. The meter shall be installed in the building lobby in a location coordinated with and approved by the Contracting Officer.

C. The Check meter shall display the current power output, the daily total power output, and the cumulative power output since installation.

2.5 MISCELLANEOUS COMPONENTS

A. All components required to make the system fully operational and in conformance with these specifications shall be provided. All electrical components shall be UL listed.

2.6 FIELD FABRICATED NAMEPLATES

A. Provide laminated plastic nameplates for each equipment enclosure, relay, switch, and device.

Each nameplate inscription shall identify the function and, when applicable, the position.

Nameplates shall be melamine plastic, 0.125 inch thick, white with black center core. Surface shall be matte finish. Corners shall be square. Accurately align lettering and engrave into the

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2.7 MANUFACTURER’S NAMEPLATES

A. Each item of equipment shall have a nameplate bearing the manufacturer's name, address, model number, and serial number securely affixed in a conspicuous place; the nameplate of the distributing agent shall not be acceptable.

PART 3 - EXECUTION

3.1 INSTALLATION

A. Install photovoltaic components and systems according to NFPA 70 and IEEE 1374.

B. Photovoltaic modules and their attachments shall be capable of withstanding the applicable seismic forces defined in ASCE-7 based on the seismic information provided on sheet S-001 of the plans.

C. No more than one roof penetration shall be allowed. The single penetration shall be for the power connection and shall comply with the roof manufacturer’s recommendations for penetrations.

D. Enclosures for disconnect switches and required electronics shall be pad-lockable. Enclosures shall be NEMA 3R and shall provide any venting and weather sealing required for temperature stability of the electronics enclosed.

E. An ac disconnect means shall be provided on all ungrounded AC conductors and shall consist of a lockable gang operated disconnect clearly indicating open or closed. The switch shall be capable of being visually inspected to determine if the switch is open. The switch shall be clearly labeled stating “PV SYSTEM SERVICE DISCONNECT.”

F. Series connected strings of photovoltaic modules shall include a series fuse and a blocking diode (to prevent reverse currents). These diodes shall have low voltage drop to meet the maximum voltage drop requirements, and shall have voltage and current ratings (at temperature) of no less than twice the open-circuit voltage and short-circuit ratings of the source circuits.

G. Parallel connections of photovoltaic modules in individual source circuits shall not be permitted. Parallel-connected cells within individual modules are allowable as long as the module listing allows for the series fuse required for this configuration.

H. To create a uniform appearance of the array, spacing between individual photovoltaic modules shall be kept to a minimum. All mechanical hardware, conduit, junction boxes and other equipment should be concealed beneath and/or behind the array. The Contracting Officer shall be notified prior to installation in cases where concealment is not possible.

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I. The array location on the roof shall be selected to maximize efficiency and minimize compromising the building aesthetics. The location shall be coordinated with and approved by the Contracting Officer.

3.2 WIRING INSTALLATION

A. All wiring shall be listed for a minimum operation of 600 volts and temperature rating of 90° C in wet locations. All current carrying conductors shall be enclosed in conduit, including module interconnections.

B. Ampacity calculations must take into account appropriate de-ratings as required. All conductors in the system are subject to a 125% NEC de-rate, and all DC source circuit conductors and overcurrent devices must include an additional 125% de-rate for solar radiation enhancement.

Appropriate temperature de-ratings for conductors used in module junction boxes must be considered for peak module operating temperatures, as well as de-ratings for instances where more than three current-carrying conductors are enclosed in a conduit.

C. Size conductors according to manufacturer's written instructions, unless otherwise indicated.

D. Voltage drop in array DC source circuits shall be limited to manufacturer recommendations and TEP requirements, but in no case shall voltage drop exceed five percent (5%), including losses in conductors and through all fuses, blocking diodes and termination points.

E. Overcurrent devices shall have trip ratings no greater than the de-rated ampacity of the protected conductors.

F. Connections shall only be made on numbered terminal strips in junction, pull, and outlet boxes;

terminal cabinets; and equipment enclosures. Twist on wire splices, crimped, soldered or taped connections shall not be allowed for the required field installed wiring.

3.3 GROUNDING

A. All module frames, panel/array support structures, metal enclosures, panel boards and cabinets shall be provided with connections for bonding to a common grounding conductor and terminating at the facility ground connection point.

3.4 FIELD QUALITY CONTROL

A. The Contractor shall notify the Contracting Officer in writing at least 45 calendar days prior to completion of the complete solar electrical (photovoltaic) system installation. At this time the Contractor shall schedule the photovoltaic module manufacturer's technical representative to inspect the completed installation. The technical representative shall provide instruction for activity personnel as specified in paragraph titled "DEMONSTRATION”.

B. Initial Inspection and Tests: The photovoltaic module technical representative, the Contracting Officer, and the Contractor’s Solar System Design Engineer, shall inspect the completed installation in the presence of the Contractor. The Contractor shall correct construction or

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1. Compare equipment nameplate data with drawings, specifications and approved shop drawings.

2. Inspect physical and mechanical condition. Inspect doors, panels, and sections for paint, dents, scratches, fit, and missing hardware. Inspect the displays for scratches, dark pixels or uneven brightness.

3. Inspect anchorage, alignment, grounding, and required clearances.

4. Verify that fuse sizes and types correspond to drawings.

5. Verify the units are clean.

6. Test all electrical and mechanical interlock systems for correct operation and sequencing.

7. Inspect bolted electrical connections for high resistance using one of the following methods:

a. Use a low-resistance ohmmeter.

b. Verify tightness of accessible bolted electrical connections by calibrated torque-wrench method.

c. Perform thermographic survey.

8. Verify operation of forced ventilation where applicable.

9. Verify that vents are clear and new clean filters are installed where applicable.

10. Measure the array azimuth orientation and tilt angle using compass and inclinometer.

C. Acceptance Tests: The Contracting Officer and the Contractor’s Solar System Design Engineer, shall perform acceptance tests of the completed installation in the presence of the Contractor. Test shall be conducted on a clear day with the plane of array irradiance at 800 watts per square meter or greater. The Contractor shall correct construction or installation deficiencies as directed. Perform acceptance checks in accordance with the manufacturer's recommendations and include the following tests:

1. Measure the PV Array Open Circuit Voltage (Voc).

2. Measure the PV Array Short Circuit Current (Isc).

3. Measure the inverter DC Input voltage and current.

4. Measure the inverter AC Output voltage, current, and power factor.

5. Measure the irradiance and module temperature, and calculate the efficiency

3.5 ADJUSTING

A. Make necessary adjustments and jumper settings for proper operation of grid tied inverter system.

3.6 DEMONSTRATION

A. Engage a factory-authorized service representative to train Government maintenance personnel to adjust, operate, and maintain the solar electric (photovoltaic) system. The Contractor’s Solar System Design Engineer shall participate in the training for no less than two (2) hours. Training shall be a minimum of eight hours and shall be recorded.