RFI-90 - SPEC 26 31 00.pdf

Power Generation with Microgrid 164947 Joint Base McGuire-Dix-Lakehurst, New Jersey

SECTION 26 31 00

FACILITY-SCALE SOLAR PHOTOVOLTAIC (PV) SYSTEMS

11/21

PART 1 GENERAL

1.1 REFERENCES

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 CONCRETE INSTITUTE (ACI)

ACI 318 (2019; R 2022) Building Code Requirements for Structural Concrete (ACI 318-19) and Commentary (ACI 318R-19)

AMERICAN NATIONAL STANDARDS INSTITUTE (ANSI)

ANSI C12.1 (2014; Errata 2016) Electric Meters - Code for Electricity Metering

AMERICAN SOCIETY OF CIVIL ENGINEERS (ASCE)

ASCE 7-16 (2017; Errata 2018; Supp 1 2018) Minimum Design Loads and Associated Criteria for Buildings and Other Structures

ASTM INTERNATIONAL (ASTM)

ASTM D149 (2025) Standard Test Method for Dielectric Breakdown Voltage and Dielectric Strength of Solid Electrical Insulating Materials at Commercial Power Frequencies

ASTM D257 (2014) Standard Test Methods for D-C Resistance or Conductance of Insulating Materials

ASTM D709 (2017) Standard Specification for Laminated Thermosetting Materials

ASTM D882 (2012) Tensile Properties of Thin Plastic Sheeting

ASTM D903 (1998; R 2017) Standard Test Method for Peel or Stripping Strength of Adhesive Bonds

ASTM D1876 (2008; R 2015; E 2015) Standard Test Method for Peel Resistance of Adhesives (T-Peel Test)

ASTM D2244 (2021) Standard Practice for Calculation of Color Tolerances and Color Differences from Instrumentally Measured Color

SECTION 26 31 00 Page 1

Coordinates

ASTM D2765 (2016) Standard Test Methods for Determination of Gel Content and Swell Ratio of Crosslinked Ethylene Plastics

ASTM D5870 (2016) Standard Practice for Calculating Property Retention Index of Plastics

ASTM D7567 (2009) Standard Test Method for Determining Gel Content in Crosslinked Ethylene Plastics Using Pressurized Liquid Extraction

ASTM E308 (2022) Standard Practice for Computing the Colors of Objects by Using the CIE System

ASTM E424 (1971; R 2023) Standard Test Methods for Solar Energy Transmittance and Reflectance (Terrestrial) of Sheet Materials

ASTM E772 (2015; R 2021) Standard Terminology of Solar Energy Conversion

ASTM E1171 (2015) Standard Test Methods for Photovoltaic Modules in Cyclic Temperature and Humidity Environments

ASTM F1249 (2020) Standard Test Method for Water Vapor Transmission Rate Through Plastic Film and Sheeting Using a Modulated Infrared Sensor

ASTM G155 (2021) Standard Practice for Operating Xenon Arc Lamp Apparatus for Exposure of Materials

INSTITUTE OF ELECTRICAL AND ELECTRONICS ENGINEERS (IEEE)

IEEE 1547 (2018) Interconnection and Interoperability of Distributed Energy Resources with Associated Electric Power Systems Interfaces

IEEE C2 (2023) National Electrical Safety Code

IEEE Stds Dictionary (2009) IEEE Standards Dictionary: Glossary of Terms & Definitions

INTERNATIONAL CODE COUNCIL (ICC)

ICC IBC (2024) International Building Code

INTERNATIONAL ELECTRICAL TESTING ASSOCIATION (NETA)

NETA ATS (2025) Standard for Acceptance Testing Specifications for Electrical Power Equipment and Systems

SECTION 26 31 00 Page 2

INTERNATIONAL ELECTROTECHNICAL COMMISSION (IEC)

ANSI IEC 60529 (2020) Degrees of Protection Provided by Enclosures

IEC 61215 (2005; ED 2.0) Crystalline Silicon Terrestrial Photovoltaic (PV) Modules - Design Qualification and Type Approval

IEC 61853-1 (2011; ED 1.0) Photovoltaic (Pv) Module Performance Testing and Energy Rating - Part 1: Irradiance and Temperature Performance Measurements and Power Rating

IEC 62446 (2018) Photovoltaic (PV) Systems - Requirements for Testing, Documentation, and Maintenance - Part 1: Grid Connected Systems - Documentation, Commissioning Tests and Inspection

INTERNATIONAL ORGANIZATION FOR STANDARDIZATION (ISO)

ISO 9001 (2015) Quality Management Systems- Requirements

NATIONAL ELECTRICAL MANUFACTURERS ASSOCIATION (NEMA)

NEMA 250 (2020) Enclosures for Electrical Equipment (1000 Volts Maximum)

NEMA IEC 60529 (2004) Degrees of Protection Provided by Enclosures (IP Code)

NATIONAL FIRE PROTECTION ASSOCIATION (NFPA)

NFPA 1 (2021) Fire Code

NFPA 70 (2026) National Electrical Code

NFPA 70E (2024) Standard for Electrical Safety in the Workplace

NFPA 780 (2023) Standard for the Installation of Lightning Protection Systems

U.S. NATIONAL ARCHIVES AND RECORDS ADMINISTRATION (NARA)

29 CFR 1910 Occupational Safety and Health Standards

UNDERWRITERS LABORATORIES (UL)

UL 969 (2017; Reprint May 2023) UL Standard for Safety Marking and Labeling Systems

UL 1703 (2002; Reprint Jun 2016) UL Standard for Safety Flat-Plate Photovoltaic Modules and Panels

UL 1741 (2021, Edition 3) UL Standard for

SECTION 26 31 00 Page 3

Inverters, Converters, Controllers and Interconnection System Equipment for Use With Distributed Energy Resources

UL 2703 (2015; Reprint Jul 2023) UL Standard for Safety Mounting Systems, Mounting Devices, Clamping/Retention Devices, And Ground Lugs For Use With Flat-Plate Photovoltaic Modules And Panels

UL 6703 (2014, Reprint Jun 2024) Standard for Connectors for Use in Photovoltaic Systems

UL Electrical Construction (2012) Electrical Construction Equipment Directory

1.2 RELATED REQUIREMENTS

Sections 26 20 00 INTERIOR DISTRIBUTION SYSTEM, 26 08 00 APPARATUS

INSPECTION AND TESTING, 25 05 11.05 CYBERSECURITY FOR FACILITY-RELATED

CONTROL SYSTEMS SMART METERS - LOW IMPACT, 25 05 11.06 CYBERSECURITY FOR

FACILITY-RELATED CONTROL SYSTEMS ELECTRICAL SCADA - LOW IMPACT, and 33 71 02 UNDERGROUND ELECTRICAL DISTRIBUTION apply to this section with additions and modifications specified herein.

1.3 DEFINITIONS

a. Unless otherwise specified or indicated, electrical and electronics terms used in these specifications, and on the drawings, are as defined in the IEEE Stds Dictionary .

b. Unless otherwise specified or indicated, solar energy conversion terms used in these specifications, and on the drawings, are as defined in

ASTM E772.

1.4 SUBMITTALS

Government approval is required for submittals with a "G" or "S" classification. Submittals not having a "G" or "S" classification are for Contractor Quality Control approval. Submittals not having a "G" or "S" classification are for information only. When used, a code following the "G" classification identifies the office that will review the submittal for the Government. Submit the following in accordance with Section

01 33 00 SUBMITTAL PROCEDURES:

SD-01 Preconstruction Submittals

Commissioning Plan ; G, RO

Commissioning Schedule ; G, RO

SD-02 Shop Drawings

Schematic Diagrams ; G, RO

Interconnection Diagrams ; G, RO

Installation Drawings ; G, RO

SECTION 26 31 00 Page 4

Site Plan Drawings ; G, RO

Riser Diagram and General Notes ; G, RO

Installation and Assembly Details ; G, RO

Shop Drawings ; G, RO

Complete Solar PV System Components and Interconnection Wiring Diagrams; G, RO

SD-03 Product Data

Combiner Boxes ; G, RO

Disconnects ; G, RO

Inverters ; G, RO ; S

String Inverter Efficiency ; G, RO ; S

Ground Mounting Structure for Modules ; G, RO

Photovoltaic Module Backsheet ; G, RO

Photovoltaic Module Encapsulant ; G, RO

Photovoltaic Modules ; G, RO ; S

Photovoltaic Wire ; G, RO

System Monitoring ; G, RO

System Wiring ; G, RO

SD-05 Design Data

System Operation ; G, RO

Calculations ; G, RO ; S

System Performance Calculations ; G, RO ; S

Structural Loading Calculations ; G, RO

Anticipated Annual Performance ; G, RO

FAA Glare Study ; G, RO

SD-06 Test Reports

NABCEP Acceptance Checks and Tests ; G, RO

NETA Acceptance Checks and Tests ; G, RO

Inverter Startup Tests ; G, RO

Functional Performance Testing ; G, RO

SECTION 26 31 00 Page 5

SD-07 Certificates

Installer ; G, RO

Materials ; G, RO

Warranty ; G, RO

Cybersecurity Equipment Certification ; G, RO

Commissioning Agent Qualification ; G, RO

Seismic Certification ; G, RO

Wind Certification ; G, RO

SD-08 Manufacturer's Instructions

Installation Instructions ; G, RO

Manufacturer's Installation Instructions ; G, RO

SD-10 Operation and Maintenance Data

Electrical Systems , Data Package 5; G, RO

Training Course ; G, RO

SD-11 Closeout Submittals

Solar Posted Operating Instructions ; G, RO

Solar Training Documentation ; G, RO

Final Commissioning Report ; G, RO

Warranty ; G, RO

As-Built Drawings ; G, RO

1.5 MAINTENANCE MATERIAL SUBMITTALS

Comply with requirements specified in Section 01 78 00 CLOSEOUT SUBMITTALS.

1.6 QUALITY ASSURANCE

1.6.1 Regulatory Requirements

Interpret references in these publications to the "authority having jurisdiction," or words of similar meaning, to mean the Contracting Officers. Provide equipment, materials, installation, and workmanship in accordance with the mandatory and advisory provisions of NFPA 70 unless more stringent requirements are specified or indicated.

1.6.2 Installation Drawings

Submit a minimum of three hard copies of drawings for government approval prior to manufacturing and equipment construction or integration. Submit site plan drawings and riser diagram and general notes at a minimum of 24

SECTION 26 31 00 Page 6 by 36 inches. Submit installation and assembly details at a minimum of 24 by 36 inches. Submit at minimum scale of 1/2 inch per foot for overview and 2 inches per foot for detail.

In addition to requirements in Section 01 33 00 SUBMITTAL PROCEDURES, include the following:

a. All details legible and all text no smaller than 0.1 inches in height on any drawing. As needed, provide enlargements to ensure clarity of intent.

b. Submit shop drawings at a minimum of 11 by 17 inches in size using a minimum scale of 1/4 inch per foot, for the exception of drawings not required scale. Shop drawings must include one-wire diagrams and installation details of photovoltaic (PV) system equipment indicating location as proposed in design drawings, layout and arrangement of PV modules, support and mounting mechanism, inverters, combiner boxes, AC and DC disconnects, equipment enclosures, switchboard drawings, conduits, monitors, meters, security systems, and all other accessories associated with the installation of the PV system. Wiring diagrams must identify circuit terminals and indicate the internal wiring for each item of equipment and the interconnection between each equipment item. Submit complete detailed product drawings for the solar PV system consisting of shop drawings and product data sheets.

Provide equipment dimensions, weights and structural mounting details.

c. Shop drawings must include legible copies of manufacturer's product literature, with selected items and specifications highlighted thereon.

d. Modifications to original drawings made during installation must be immediately recorded for inclusion into the as-built drawings. When items have changed relative to the approved design, the designer must provide certification indicating that the changes will not negatively affect the system's operation or the structure supporting the system.

1.6.2.1 Installation and Assembly Drawings and Details

Submit site plan drawings, components and interconnection wiring and general notes, and installation and assembly details drawings prior to start of construction. Drawings must include sufficient detail for all parts of the work to enable the Government to check conformity with the requirements of the contract documents. Include in the site plan drawings:

topographic and utility survey; bore logs; soils report and the Contractor-provided geotechnical report (if required for alternative foundation systems); site plan(s); site construction details; structural drawings; structural construction details; site electrical plan; and site electrical construction details. Include in the installation and assembly drawings and details: Parts lists; assembly drawings; interconnection wiring diagrams; wire and cable schedules; wire and cable termination schedules; instrument plan; instrument and control wire, conduit and cable schedules; instrument wire and cable termination schedule; control diagrams; control sequence of operation; seismic restraint details; and wind restraint details.

1.6.2.2 "As-Built" and Record Drawings

After completion of construction, submit As-built drawings prepared and certified by the construction contractor, showing in red ink, on-site changes to the original construction details and all underground utilities

SECTION 26 31 00 Page 7 measured from field benchmarks, accurate to within 1" of centerline of the utility. Immediately record for inclusion into the as-built drawings all modifications to original drawings made during installation. Indicate adequate clearance for operation, maintenance, and replacement of operating equipment devices.

After submittal and approval of "As-built" drawings, submit Record Drawings, prepared and by the project engineer(s) and architect(s), of the original design drawings reflecting all design changes and contractor noted changes in the "As-built" drawings.

1.6.2.3 Structural Loading Calculations

Provide design Calculations, including, but not limited to, structural loading. Include nameplate data, size, and capacity of each PV module.

Include all assumptions such as applicable wind speed, snow and seismic loads. Include applicable federal, military, industry, and technical society publication references.

1.6.2.4 Anticipated Annual Performance

Provide design Calculations, including, but not limited to, anticipated performance of solar PV array. Include nameplate data, size, and capacity of each PV module. Include all assumptions such as applicable wind speed, snow and seismic loads. Include applicable federal, military, industry, and technical society publication references.

1.6.2.5 FAA Glare Study

Provide analyses, including, but not limited to, FAA glare study. Include nameplate data, size, and capacity of each PV module. Include applicable federal, military, industry, and technical society publication references.

1.6.3 System Operation

Provide a complete description of the function of each component including PV modules, DC wiring, combiner boxes, inverters, AC wiring, AC and DC disconnect switches, and monitoring system. Provide a discussion of the overall system operation.

1.6.4 Installer

Submit NABCEP (North American Board of Certified Energy Practitioners) PV Installation Professional certification, and a resume with references that details least four successful projects that, in aggregate, equal or exceed the size of the proposed project. Provide references for each of these referenced projects.

1.6.5 Standard Materials and Products

Provide materials and equipment that are products of manufacturers regularly engaged in the production of such products which are of equal material, design and workmanship. Provide products with satisfactory commercial or industrial use for 2 years prior to bid opening, and past performance documentation with consistent design and bill of materials.

Include applications of equipment and materials under similar circumstances and of similar size. Where two or more items of the same class of equipment are required, products will be from a single manufacturer; however, the component parts of the item need not be the

SECTION 26 31 00 Page 8 products of the same manufacturer unless stated in the technical section.

Submit proof of compliance with requirements of UL, where material or equipment is specified to comply. The label of or listing in UL Electrical Construction Directory will be acceptable evidence. In lieu of the label or listing, a written certificate from an approved nationally recognized testing laboratory (NRTL) equipped to perform such services, stating that the items have been tested and conform to the requirements and testing methods of Underwriters Laboratories may be submitted.

1.6.5.1 Alternative Qualifications

Products having less than a 2-year field service record will be acceptable if the manufacturer has been regularly engaged in the design and production of solar photovoltaic products for a minimum of 5-years.

Similar photovoltaic products must have been in satisfactory commercial or industrial use for 5-years prior to bid opening and must have been on sale on the commercial market through advertisements, manufacturers' catalogs, or brochures during the 5-year period.

1.6.5.2 Material and Equipment Manufacturing Date

Products manufactured more than 3 years prior to date of delivery to site must not be used, unless specified otherwise.

1.6.6 Cybersecurity Equipment Certification

Furnish a certification that control systems are designed and tested in accordance with DoD Instruction 8500.01, DoD Instruction 8510.01, and as required by individual Service Implementation Policy.

1.6.7 Operation and Maintenance Data

Submit Solar Photovoltaic Systems data package for the following items in accordance with Section 01 78 23 OPERATION AND MAINTENANCE DATA.

a. Troubleshooting guide with as-built plans displaying modules identified according groups or zones, coordinated with activity to organize as required.

b. Warranty.

c. Operation instructions.

d. Preventive maintenance and inspection data, including a schedule for system operators.

1.6.7.1 Electrical Systems

Submit operation and maintenance data in accordance with Section 01 78 23 OPERATION AND MAINTENANCE DATA. In addition to requirements of Data Package 5, include the following for the actual solar photovoltaic (PV) system provided:

a. Service and maintenance information including preventive maintenance, assembly, and disassembly procedures.

b. Complete operation, repair, and maintenance information, detailed to the smallest replaceable unit.

SECTION 26 31 00 Page 9

c. Adjustment, trouble-shooting, configuration, tuning, and system calibration instructions.

d. Programming information for the communications and monitoring interface.

e. An instruction manual with pertinent items and information highlighted.

f. A layout drawing showing locations as well as views of equipment;

front, top, and side views.

g. A one-line drawing showing all components and interfaces to the electrical system.

h. Prices for spare parts and supply list including spare modules and inverters.

i. Inverter efficiency report and field acceptance test reports.

j. Actual nameplate diagram.

k. Date of purchase.

1.6.7.2 Training Course

Provide training by a factory trained instructor to provide full instructions to designated Government personnel in the operation, maintenance and programming of the specified systems and equipment.

Include safety training for first responders including fire department representatives. The proposed Training Course Curriculum (including topics and dates of discussion) indicating that all of the items contained in the operating and maintenance instructions, as well as demonstrations of safety and routine maintenance operations, including testing procedures included in the maintenance instructions, are to be covered. The proposed Training Course must be video-recorded and provided with any PowerPoint slides as part of the final documentation for those that cannot attend.

Submit training documentation along with the proposed training date(s), at least 14 days prior to date(s) of proposed training course. Provide training session for six personnel specifically oriented to installed equipment, system layout, and user operations.

1.6.8 Bill of Materials

Submit a Bill of Materials listing each product being incorporated into the system. Bill of Materials includes a general description of the product, quantity, and exact manufacturer's model number. Where the manufacturer's model number does not fully identify the product, list options, accessories, or custom features by additional descriptions.

1.6.9 Qualified Testing Organization

Comply with requirements specified in Section 26 08 00 APPARATUS INSPECTION AND TESTING. Engage the services of a qualified testing organization, NABCEP-certified professional, or licensed electrician to provide inspection, testing, calibration, and adjustment of the solar photovoltaic electrical distribution system and equipment listed herein.

Organization must be independent of the supplier, manufacturer, and installer of the equipment. The organization must be a first tier contractor.

SECTION 26 31 00 Page 10

Submit name and qualifications of organization. Organization must have been regularly engaged in the testing of electrical materials, devices, installations, and regularly engaged in solar PV systems for a minimum of five years.

Organization calibration program requirements:

a. Provide a calibration program which assures that all applicable test instruments are maintained within rated accuracy.

b. Accuracy: Traceable to the National Institute of Standards and Technology.

c. Instrument calibration frequency schedule: Less than or equal to 12 months for both test floor instruments and leased specialty equipment.

d. Dated calibration tables: Visible on all test equipment.

e. Calibrating standard: Higher accuracy than that of the instrument tested.

f. Keep up-to-date records that indicate dates and test results of instruments calibrated or tested. For instruments calibrated by the manufacturer on a routine basis, in lieu of third party calibration, include the following:

(1) Maintain up-to-date instrument calibration instructions and procedures for each test instrument.

(2) Identify the third party laboratory calibrated instrument to verify that calibrating standard is met.

1.6.10 Commissioning Agents

Commissioning Agents Qualifications: Engage commissioning service personnel, that specialize in the types of inspections and tests to be performed.

1.6.11 System Performance Calculations

Submit system performance calculations to show that the components provided will produce the minimum required production of power in accordance with PERFORMANCE REQUIREMENTS paragraph.

1.7 DELIVERY, STORAGE, AND HANDLING

a. Store solar PV modules in their original packaging according to the manufacturer's guidance, and do not remove from packaging until day of installation.

b. If a solar PV module is removed from its packaging, store it according to the manufacturer's guidance.

c. Do not store solar PV modules on-site for more than 12 months.

1.8 WARRANTY

Provide a list of all applicable warranties for all equipment and

SECTION 26 31 00 Page 11 components. Include warranty information, names, addresses, telephone numbers, and procedures for filing a claim and obtaining warranty services. The equipment items must be supported by service organizations which are reasonably convenient to the equipment installation in order to render satisfactory service to the equipment on a regular and emergency basis during the warranty period of the contract.

Warrant the overall system for both parts and labor for a minimum period of 5 years. Provide specific warranties for solar photovoltaic modules, inverters, combiner boxes, mounting system, and cybersecurity.

1.8.1 Solar Photovoltaic Modules

Furnish the solar photovoltaic module manufacturer's written warranty.

The warranty must be a 25-year linear 80 percent (minimum) power warranty (at the end of the 25th year after purchase an actual minimum power output of 80 percent based on the nameplate rating must be achieved) and not less than 10-years for workmanship material and manufacturing defects from the date of manufacture.

The warranty must state that the malfunctioning solar photovoltaic module must be exchanged by the manufacturer and promptly shipped to the using Government facility. The replacement solar module must be identical to, or an improvement upon, the original design of the malfunctioning solar module.

1.8.2 Inverters

Furnish the inverter manufacturer's warranty. Inverter to be free from defects in material and workmanship for a minimum of 20 years from the date of manufacture. Inverter device installation, transportation, and on-site storage must not exceed 12 months, thereby permitting 19 years of the 20 year warranty to be in service and energized.

The warranty must state that the malfunctioning inverter must be exchanged by the manufacturer and promptly shipped to the using Government facility, and arrive in no more than ten days. The replacement inverter must be identical to, or an improvement upon, the original design of the malfunctioning inverter.

1.8.2.1 Inverter Software Updates Title

Provide, at no cost or charge, any inverter software upgrades that become available during the warranty period .

1.8.3 Combiner Boxes

Combiner boxes to be free from defects in material and workmanship for a period of 5 years.

1.8.4 Mounting System

Provide PV mounting system warranty of minimum 15 years.

1.8.5 Warranty Exclusion

The warranty must cover all system malfunctions and failures except those resulting from misuse, abuse, neglect, fire, vandalism, acts of nature, or other causes beyond the control of the Contractor or manufacturer.

SECTION 26 31 00 Page 12

1.8.6 Cybersecurity During Warranty Period

All work performed on the control system after acceptance must be performed using Government Furnished Equipment or equipment specifically and individually approved by the Government.

1.9 CALCULATIONS

If construction deviates from design, provide relevant calculations to demonstrate that new design is satisfactory and approved by a licensed professional engineer.

1.10 CERTIFICATIONS

Provide seismic certification and wind certification , prepared by a licensed professional engineer or National Recognized Testing Laboratory, (NRTL) for all components and assembled systems in accordance with ICC IBC , ASCE 7-16 state and local building codes. Seismic and wind certifications must demonstrate system must withstand wind and seismic requirements as installed and remain online and functional after a seismic or wind event.

1.11 HEALTH AND SAFETY RECOMMENDATIONS

Section 01 35 26 GOVERNMENTAL SAFETY REQUIREMENTS, applies to this section with additions and modifications specified herein.

PART 2 PRODUCTS

2.1 SYSTEM DESCRIPTION

a. The PV system described in this document is a facility-scale less than 1 megawatt with system voltage not exceeding 1,000 VDC, single PV systems with a single service, and is of the grid-connected type which provides a direct interconnection of PV system and grid power service supplying building. The PV system does not include battery/backup storage or secondary electrical generation devices. PV system feeds AC power into the local services when solar energy is available and immediately disconnects from the grid upon loss of grid power to the service in accordance with IEEE 1547 and local utility regulations.

b. PV system must comply with these specifications, all applicable construction document drawings, all applicable codes, and all local authorities having jurisdiction. System must comply with all policies and standards required by the electrical utility having jurisdiction and all applicable incentive program guidelines. PV system equipment includes, but is not limited to, PV modules and electrical insulating components such as encapsulants and backsheets, raceways, inverters, combiner boxes, disconnect switches, wire, conduit, junction boxes, mounting hardware, mounting structure for modules (racking), monitoring and communication equipment.

2.1.1 System Requirements

Conform electrical installations to IEEE C2 , NFPA 70 , and requirements specified herein.

a. Base Bid: Provide 300 kW AC photovoltaic system. Bid Option:

Provide remaining 100 kW AC system.

SECTION 26 31 00 Page 13

b. Solar photovoltaic system characteristics provided includes:

(1) 414 minimum rated kW DC output.

(2) 400 minimum rated kW AC output.

(3) 635 minimum kWh AC per year for year one.

(4) 480V AC, 1000V DC system voltage.

(5) Ground mounted.

c. All equipment must be listed and labeled in accordance with NFPA 70 and OSHA-listed nationally recognized testing laboratories (NRTL) and installed in accordance with the listing requirements and the manufacturer's instructions.

d. Provide all accessories needed for a complete, secure, operational grid-tied PV system.

e. Wiring and connections of inverters, PV source circuits, AC branch circuits, and all interconnections must be rated at a minimum for IP65 in accordance with NEMA IEC 60529 .

2.1.1.1 System Wiring

System wiring must conform to Section 26 20 00 INTERIOR DISTRIBUTION SYSTEM and must be in accordance with Section 690 of NFPA 70 . Cabling exposed to sunlight must be UV resistant.

Provide conduits in accordance with Section 26 20 00 INTERIOR DISTRIBUTION SYSTEM. Use galvanized rigid steel conduit above grade and mount on UV resistant high-density polyethylene (HDPE) supports. Conduit below grade must be Schedule 40 PVC, 1-inches minimum.

2.1.1.2 Site Design

Provide adequate space for personnel, vehicles and equipment throughout the PV array to facilitate installation, inspection and maintenance access to all modules.

2.2 PHOTOVOLTAIC MODULES

a. PV modules must be IEC 61215 compliant and listed to UL 1703 , and manufactured in an ISO 9001 certified facility.

b. PV modules must be of monocrystalline technology and

(1) for rack-mounting.

c. PV modules must be of thin-film technology and

(1) for rack-mounting.

d. PV module efficiency must be greater than 15 percent for crystalline technology.

e. PV modules must be of the same manufacturer and model number and

SECTION 26 31 00 Page 14 consistent sub-components.

f. Submit on cutsheets PV module performance data from the manufacturer that must include a flash test data in accordance with IEC 61853-1 , and temperature coefficients at: STC, nominal operating cell temperature (NOCT), low irradiance conditions (LIC), high temperature conditions (HTC), and low temperature conditions (LTC).

g. PV module bypass diodes must be inside the solar PV module's single conductor cable junction box.

h. Photovoltaic wire , wiring methods, and utilization of locking-type connectors must comply with the requirements of NFPA 70 and UL 6703 .

Provide USE-2 or RHH or RHW-2 wire, and sunlight-resistant wire when exposed to sunlight.

2.2.1 Crystalline Photovoltaic Module Backsheet

a. Backsheet component must consist of a tri-layer construction (minimum thickness of 9.8 mils) with outer layers of polyvinyl fluoride (PVF) and an inner layer of polyester for crystalline-silicon modules.

b. Alternate polymeric backsheets consisting of different chemical composition, thickness, or construction must fulfill the safety and performance specifications and acceptance criteria in Table 1. The required component properties in Table 1 must be verified by a test report provided by an OSHA-listed nationally recognized testing laboratory (NRTL) and a cutsheet submitted.

TABLE 1 - PV MODULE BACKSHEET COMPONENT SAFETY AND PERFORMANCE

Items Test Methods Specification

Tensile Strength (MPa) ASTM D882 >=100 (TD)

>=100 (MD)

Elongation at Break (percent) ASTM D882 >=80 (TD)

>=100 (MD)

Dimensional Stability (percent, 150 degrees C, 0.5 h)

ASTM D882 <=1.0 (TD)

<=1.0 (MD)

Breakdown Voltage (kV) ASTM D149 >=18

WVTR (g/m^2 day, 37.8 degrees C, 100 percent RH)

ASTM F1249 <=2.5

Interlayer Peeling Strength (N/cm) ASTM D1876 >=4

Peeling Strength with EVA (N/cm) ASTM D903 >=40

Damp Heat (85 degrees C, 85 percent RH, 1000 hrs) -Color Change delta b -Elongation Retention (percent) -Appearance

ASTM E1171

ASTM E308/ ASTM D2244

ASTM D882/ ASTM D5870

<=2.5 >=70

No cracking or delamination.

SECTION 26 31 00 Page 15

TABLE 1 - PV MODULE BACKSHEET COMPONENT SAFETY AND PERFORMANCE

UV Exposure Irradiance of 0.55 W/m^2 at 340 nm (61 W/m^2) using a xenon lamp with a daylight filter (outer layer).

Exposure is 4200 hours (260 kWh/m^2 total UV (300-400 nm)) -Color Change delta b -Elongation Retention (percent) -Tensile Retention (percent) -Appearance

ASTM G155

ASTM E308/ ASTM D2244

ASTM D882/ ASTM D5870

ASTM D882/ ASTM D5870

<=2.0 >=70 >=70

No cracking or delamination.

2.2.2 Crystalline Photovoltaic Module Encapsulant

a. Encapsulant component must consist of ethyl vinyl acetate (EVA) with a total nominal (prelamination) thickness of 35 mils or greater in the completed module. The EVA must have a minimum of 28 percent VA content. Through statistical process control, the module manufacturer must ensure that the cured EVA has a minimum of 70 percent gel content per ASTM D7567 or ASTM D2765. The EVA must have a UV cutoff wavelength of 360 nm as measured according to ASTM E424. The EVA must have a minimum volume resistivity of 1X10^15 ohm-cm per ASTM D257.

b. Thermoplastic encapsulants consisting of different chemical composition, thickness, or construction must fulfill the safety and performance specifications and acceptance criteria described in Table

2. The required component properties described in Table 2 must be verified by a test report provided by an OSHA-listed nationally recognized testing laboratory (NRTL) and a cutsheet submitted.

TABLE 2 - PV MODULE ENCAPSULANT COMPONENT PROPERTIES

Items Test Methods Specification

Appearance Visual Examination No bubble, crack, or delamination.

Gel Content (percent) ASTM D7567/ ASTM D2765 >=70

UV Cutoff Wavelength (nm) ASTM E424 >=360

Volume Resistivity (ohm-cm) ASTM D257 >=1X10^15

2.2.3 Electrical Characteristics

Provide high-power type PV module(s), with typical peak power of not less than 480 watts, plus or minus 3 percent power tolerance, under Standard Test Conditions (STC). The AC output must not be less than 80 percent of the DC kWp rating. The individual current harmonics and TRD shall not exceed the limits specified in IEEE 1547 .

SECTION 26 31 00 Page 16

The operating voltage corresponding to the power output mentioned above must be at least 54 volts. The open circuit voltage of the PV modules under STC should be at least 64 volts. Operate PV module at an ambient temperature range of minus 40 degrees F to plus 185 degrees F with 100 percent relative humidity.

2.2.4 Terminal Box

Include a terminal box on the module having a provision for opening for replacing the cable, if required.

2.2.5 Nameplate

Include the following on the module nameplate so as to be clearly visible:

a. Name of the Manufacturer or distinctive logo;

b. Model or Type Number;

c. Serial Number;

d. Year of make;

e. Peak wattage rating;

f. Peak voltage; and

g. Peak current.

2.3 INVERTERS

a. Array-to-inverter kW ratio must not exceed manufacturer recommendations. Inverter must be IEEE 1547 compliant, listed to UL 1741 , comply with the latest applicable ANSI and FCC standards and addenda, and inspected before commissioning, testing, and operation of the system. Submit documentation validating system performance requirements.

b. Inverter must be approved by FCC Part 15, Class A as an unintentional radiator.

c. All same-sized inverters supplied must be of the same manufacturer and model number.

d. Provide inverter utilizing a support structure mount system.

e. Provide inverter utilizing a NEMA 3R outdoor enclosure in accordance with NEMA 250. Provide enclosure made of steel.

f. Provide inverter with anti-islanding protection to prevent back-feeding inverter generated power to the grid in the event of a utility outage. Anti-islanding protection must be listed to UL 1741 and IEEE 1547 .

g. Overcurrent protection, ground fault protection, arc fault circuit interrupter (AFCI), and rapid shutdown must comply with the requirements of NFPA 70 .

h. Provide inverter with self-diagnostics routines, and remote and local

SECTION 26 31 00 Page 17 display of operating status and remote monitoring capabilities.

Provide inverter compatible with monitoring system and metering system. If capability for remote monitoring and control does not exist, then it must be added.

i. Provide inverter with integrated monitoring system. Data monitoring equipment must be able to sustain an overload across its output terminals up the 150 percent load, while supplying any load within its rating and without reducing its output voltage. Fuse power semiconductors in the inverter with fast acting fuses to prevent cascading failures. Provide each fuse with a blown fuse excluding String inverters and alarm indicating diodes on the control panel.

j. Rate each inverter output as 100 AC kW at unity (1), 3 phase, 480 volts, 600 maximum power point tracking (MPPT) voltage range. The peak inverter power conversion efficiency must be 96 percent or greater.

k. Match inverter DC input to the design of the PV module array outputs and account for the following:

(1) The inverter low voltage is 50 percent of the maximum system voltage, to account for 25 year degradation.

(2) Voltage decrease due to high temperatures at project site.

Operate inverter at an ambient temperature range of minus 4 degrees F to plus 122 degrees F with 95 percent humidity (non-condensing).

l. Provide isolation transformer via built into each inverter to provide safe galvanic separation between the AC side of the inverter and the grid.

m. Inverter must include AC and DC disconnecting means. DC and AC disconnecting means must be listed with ratings suitable for the intended use and purpose. System disconnecting means must meet the requirements of NFPA 70 .

2.3.1 String Inverters

a. Submit String Inverter Efficiency of having a weighted average inverter power conversion efficiency of 98 percent or greater.

b. Allow the use of DC optimizers provided that a design which coordinates the DC optimizers and the inverter(s) is approved by the Contracting Officer.

c. Inverter must feature maximum power point tracking (MPPT).

2.4 COMBINER BOXES

a. All combiner boxes must be listed to UL 1741 , and inspected before commissioning, testing, and operation of the system.

b. Provide combiner boxes support structure mount, NEMA 3R outdoor aluminum enclosures in accordance with NEMA 250.

c. Supply combiner boxes designed for use with the inverter provided, and coordinated to the specific PV source circuit design.

SECTION 26 31 00 Page 18

d. Include in the combiner boxes fuses and a bus to combine the outputs of the strings. Each combiner box must be UL 1741 listed and operate at an ambient temperature range ofminus 13 degrees F to plus 135 degrees F. Provide combiner box capable of at least 12 inputs and an input fuse rating of 15 amps.

e. Provide combiner box output terminals for paralleling two conductors for the PV positive and negative, as well as the equipment ground conductors. Run set of wires from the combiner box to the inverter.

Provide overcurrent protection and output disconnecting means listed for intended use and purpose that comply with the requirements of

NFPA 70 .

2.5 GROUND MOUNTING STRUCTURE FOR MODULES

a. Provide racking for array as indicated on the drawings, including the module azimuth and tilt. Design all structural components in a manner commensurate with attaining a minimum 50 year design life. Provide racking compliant with UL 2703 .

b. Racking and PV array, including modules, hardware, and attachments, must withstand snow loads, seismic, and wind loads as required by ASCE 7-16 and ICC IBC .

c. Racking must be suitable for Seismic Design Category B as defined by ASCE 7-16 and ICC IBC .

d. Submit seismic, wind, and snow load design calculations for the array mounting system, mounting system foundation, and PV modules attachment to the structure showing compliance with seismic, wind and snow requirements while supporting the PV modules.

e. Provide the mechanical hardware for mounting the PV arrays and all other hardware required for assembling the PV modules, and the attachments to the mounting structure.

f. Use array mounting hardware compatible with the site considerations and environment. Use a galvanized steel support structure. Do not use wood or plastic components for support.

g. Use cathodic protection compatible with the site considerations and environment. Utilize galvanized anchor driven into ground.

2.5.1 Foundation Design

The primary foundation system for the array mounting system is to be a ballasted foundation. If site conditions require the use of a pile foundation or other alternative foundation systems, the design must be based on geotechnical information obtained from a site-specific geotechnical report. The Contractor is responsible for making and obtaining this geotechnical report, including performing all necessary field investigations and testing. Design the foundations for the array mounting system that complies with one of the following foundation systems. Coordinate locations of the foundations to avoid any utility or obstruction that was identified in contract drawings and by field survey of the existing conditions. Provide calculations and drawings of the foundation design that are signed and sealed by a professional engineer.

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a. Ballasted Foundation (Primary Foundation): Provide a shallow concrete ballasted foundation in accordance with ICC IBC , and Section 03 30 00

CAST-IN-PLACE CONCRETE.

b. Driven Pile: If utilized, provide driven piles in accordance with PDCA Specification 103.

c. Shallow Foundation: Provide shallow concrete foundation in accordance with ICC IBC , and Section 03 30 00 CAST-IN-PLACE CONCRETE.

d. Helical Piles: If utilized, provide helical or screw piles in accordance with ICC IBC .

2.5.2 Wind and Seismic Ratings

The mounting system and overall installation must be capable to withstand winds of Category 3 as defined by the Saffir-Simpson Hurricane Wind Scale for all attachment points and consistent with the manufacturer's installation instructions . Provide wind certifications for all components and assemblies.

All structures and structural elements must be suitable for Seismic Design Category B in accordance with ICC IBC , ASCE 7-16 , and all other applicable building codes and standards pertaining to the erection of such structures. Submit seismic, wind and snow load design calculations for the array mounting system and its attachment to the structure showing compliance with seismic, and wind and snow requirements while supporting the PV modules.

2.6 CAST-IN-PLACE CONCRETE

Provide concrete associated with electrical work for other than encasement of underground ducts rated for 4500 psi minimum 28-day compressive strength unless specified otherwise. Conform to the requirements of Section 03 30 00 CAST-IN-PLACE CONCRETE.

2.6.1 Foundation Anchorage

Anchor mounting structure to concrete pad in accordance with Sections 03 30 00 CAST-IN-PLACE CONCRETE, 05 40 00 COLD-FORMED METAL FRAMING and 05 05 20 POST-INSTALLED CONCRETE AND MASONRY ANCHORS, as required.

2.7 PV SYSTEM MONITORING

a. Provide a PV system monitoring panel mounted as indicated.

b. The following quantities must be viewable local touch screen display mounted at location as indicated:

(1) DC Input Voltage from PV array

(2) DC Input Power from PV system

(3) DC Input Current from PV system

(4) AC Phase Current from PV system (average)

(5) AC Voltage from PV system (average)

SECTION 26 31 00 Page 20

(6) AC Real Power from PV system

(7) Daily, Weekly, Monthly, Yearly, and Cumulative Energy Production

(8) Fault Status Report

(9) DC Ground Current Report

(10) AC Neutral Current from PV system

(11) AC Power Factor

(12) AC Phase Current from inverter (A, B, C)

(13) AC Voltage from inverter (A, B, C)

c. Provide additional data acquisition sensors to measure irradiance, wind speed, and ambient temperature, and PV module temperature. Any additional data acquisition sensors require a conduit separate from the current conductor conduit.

2.8 PV SYSTEM METERING

a. Provide a non-revenue-grade Interval Data Recording (IDR) meter complete with industry standard telemetry for communications with Ethernet, or other common output capabilities. Conform to CSI requirements and electrical utility requirements.

b. Connect to a monitoring/data collection recording solar production through time increments applicable to installation standards, with a minimum of 15-minute intervals and 30-day memory.

c. UL listed and conform to ANSI C12.1 .

d. Measure kWh, demand, instantaneous power, volts, amps, and watts.

e. Provide UL listed communication and annunciator panel.

2.9 POSTED OPERATING INSTRUCTIONS

Provide for each system and principal item of equipment as specified in the technical sections for use by the operation and maintenance personnel. The operating instructions include the following:

a. Wiring diagrams, schematic diagrams , interconnection diagrams , control diagrams, and control sequence for each principal system and item of equipment.

b. Array layout showing the locations of all DC and AC disconnects.

c. Start up, proper adjustment, operating, and shutdown procedures.

d. Safety precautions.

e. The procedure in the event of equipment failure.

f. Other items of instruction as recommended by the manufacturer of each system or item of equipment.

SECTION 26 31 00 Page 21

Print operating instructions and frame under glass or in approved laminated plastic. Post instructions where directed. For operating instructions exposed to the weather, provide weather-resistant materials or weatherproof enclosures. Operating instructions do not fade when exposed to sunlight and secure to prevent easy removal or peeling.

2.10 MANUFACTURER'S NAMEPLATE

Each item of equipment must 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 will not be acceptable. For PV modules, a label on the back of the module is acceptable.

2.11 FIELD FABRICATED NAMEPLATES

ASTM D709. Provide laminated plastic nameplates for each equipment enclosure, relay, switch, and device; as specified. Each nameplate inscription identifies the function and, when applicable, the position.

Nameplates are of melamine plastic, 0.125 inch thick, white with black center core. Surface is of matte finish. Square corners. Accurately align lettering and engrave into the core. Minimum size of nameplates is 1 inch by 2.5 inches. Lettering is a minimum of 0.25 inch high normal block style.

2.12 PV EQUIPMENT MARKING AND WARNING LABELS

Provide PV equipment listed or be evaluated for the application and have a field label applied in compliance with NFPA 70 .

Provide warning signs for the enclosures of electrical equipment having a nominal rating exceeding 600 volts.

a. Provide PV equipment with UL 969 weather-resistant marking and warning labels in compliance with NFPA 1 and NFPA 70 .

b. When such equipment is guarded by a fence, mount signs on the fence.

Provide metal signs having nominal dimensions of 14 inches by 10 inches with the legend "DANGER HIGH VOLTAGE KEEP OUT" printed in three lines of nominal 3 inches high white letters on a red and black field.

c. Provide warning signs for arc flash protection in accordance with NFPA 70E for all electrical equipment and components that are requiring examination, adjustment, servicing, or maintenance while energized. Provide field installed signs to warn qualified persons of potential electrical arc flash hazards when warning signs are not provided by the manufacturer. Provide marking that is clearly visible and readable from each accessible side to qualified persons before examination, adjustment, servicing, or maintenance of the equipment.

2.13 CABLE TAGS IN MANHOLES AND HANDHOLES

Provide tags for each power cable or wire located in manholes and handholes.

The tags must be polyethylene. Do not provide handwritten letters. The first position on the power cable tag denotes the voltage. The second through sixth positions on the tag identify the circuit. The next to last position denotes the phase of the circuit and must include the Greek "phi" symbol. The last position denotes the cable size.

SECTION 26 31 00 Page 22

2.14 GROUNDING AND BONDING

a. Provide properly sized equipment grounding conductors. Equipment grounding conductors must be insulated stranded copper, except that sizes 10 AWG and smaller must be solid copper. Insulation color must be continuous green for all equipment grounding conductors, except that wire sizes 4 AWG and larger shall be identified per NFPA 70 .

b. Provide grounding lugs for aluminum PV solar module frames of either stainless steel or tin-coated copper.

c. Bonding conductors must be bare stranded copper, except that sizes 10 AWG and smaller must be bare solid copper. Bonding conductors must be stranded for final connection to motors, transformers, and vibrating equipment.

d. Provide bonding fittings on concentric/eccentric knockouts with metal conduits for circuits over 250 volts in accordance with NFPA 70 .

e. Provide bonding fittings for ferrous metal conduits enclosing grounding electrode conductors in accordance with NFPA 70 .

PART 3 EXECUTION

3.1 MANUFACTURER'S INSTALLATION INSTRUCTIONS AND INSTALLATION DRAWINGS

a. Complete all electrical work in accordance with NFPA 70 .

b. Provide all permanent and temporary shoring, anchoring, and bracing required by the nature of this work in order to make all parts absolutely stable and rigid, even when such shoring, anchoring, and bracing are not explicitly called for.

c. Install the solar PV system in accordance with this section, installation drawings, and the printed installation instructions of the manufacturer.

d. Follow the manufacturer's installation recommendations to ensure no electricity is being fed to the grid and that all available disconnects are in the open position and fuses are not installed during wiring operations. Utilize on-site measurements in conjunction with engineering designs to accurately cut wires and layout before making permanent connections. Locate wires out of the way of openings and other hazards. Ensure wires are free of snags and sharp edges that have the potential to compromise the wire insulation. Ensure breakers in combiner box are in the off position (or fuses removed) during combiner box wiring. Ensure wires and conduit are not installed as a trip hazard.

e. Attach solar PV modules to the mounting structure according to the manufacturer's instructions and approved plans.

f. Install instrumentation according to the manufacturer's instructions, with control panels located as indicated.

3.1.1 Wiring Methods

Furnish and install conductors required to connect incoming and outgoing circuits. Install conductors with conduits, boxes, and terminal cabinets

SECTION 26 31 00 Page 23 in a totally enclosed installation. Install wiring in accordance with NFPA 70 and Section 26 20 00 INTERIOR DISTRIBUTION SYSTEM.

3.1.2 Electrical Connections

a. Use twist on wire connectors listed for the environment (i.e., wet, damp,…