GSA_FASPP_SOL_PART_1_SECTION_C__AMENDMENT_6.pdf

FASPP

Part I, Section C

SECTION C — STATEMENT OF WORK

C.1 Table of Contents

C.1 Table of Contents

C.2 General

C.3 Definitions and Glossary

C.4 Order of Precedence

C.5 Places of Performance

C.6 UDC Interconnection Requirements

C.7 Site Conditions

C.8 Warranties

C.9 Personnel Qualifications

C.10 PV System Monitoring

C.11 System Startup and Commissioning

C.12 Project Management Requirements

C.13 Operational Requirements

C.14 Design and Construction Standards

C.2 General

Contractor shall provide all labor, material, equipment, engineering, maintenance and capital to design, install, commission, maintain and operate solar photovoltaic systems as required herein. The contract will be a power purchase agreement. The Government will pay the Contractor solely on the basis of a price per kilowatt hour of energy produced by each system and delivered to the facility, aside from possible payments for temporary system removal and restoration, and payment of unamortized costs in the event the option period is not exercised, as described herein. The Contractor, or any special purpose entity designated by the Contractor, shall maintain title to the systems. The Government will grant licenses or temporary easements to the Contractor for nonexclusive use of rooftop, ground, or parking lot space for the Contractor to keep and maintain the systems. The solicitation is structured with the intent for the Contractor to be able to take advantage of the solar investment tax credit and accelerated depreciation; the Contractor is responsible for taking any necessary steps to take advantage of these.

The Contractor shall confine systems to the footprint defined in the site-specific specifications, unless the Contracting Officer gives written permission to exceed such footprints.

The contractor is responsible for ascertaining relevant site conditions in order to verify project feasibility and for determining appropriate system size, subject to the minimum and maximum system size required.

Solar arrays must be engineered and constructed with high quality components (modules, inverters, transformers, circuit protection, and conductors) and methods in order to maximize kWh production and dollar savings. For sites with time of use (TOU) and/or demand rates, solar PV systems are to be designed to maximize dollar savings in order to offset greatest amount of electricity in higher cost rate periods and achieve greatest annual dollar savings.

The systems shall convert solar radiation into AC electric power, within power quality specifications, and at a voltage and configuration of phases compatible with the local utility grid power distribution system, and acceptable to the local utility distribution company. At a minimum, each system shall consist of a solar photovoltaic generation system, all necessary support structure and mounting provisions, all necessary reinforcement of existing support structure, terminal and combiner box(es), quick connect solar panel electrical connectors, cable and wiring, conduits, DC disconnect, grid-connected inverter, transformers, AC disconnect, all metering and control equipment, a system monitoring and data retrieval sub system, ground and arc fault protection and alarming and an electrical grounding sub system, surge protection from the existing electric distribution systems, and any other equipment necessary to produce a fully operational system and to interconnect with site electrical distribution systems and as required by each UDC’s interconnection standards.

In addition to the above, the contractor shall provide all incidentals required, such as impact studies and modifications required by the UDC, permits, approvals, environmental compliance, taxes, freight, financing, procurement, monitoring, inspection, billing, and incidentals as necessary to design, construct, operate, and maintain all the complete solar photovoltaic generation systems, generally described hereinafter.

This Section C states requirements applicable to all sites. Site-specific specifications found in the Site Statements of Work describe additional requirements applicable to each specific site.

This contract is a joint effort of the General Services Administration (GSA) and the U.S. Forest Service (USFS). GSA is executing and administering the contract for its own and USFS’s behalf. Eight (8) sites belong to GSA, and one (1) to USFS. Each agency will pay the invoices for production for its respective sites.

This subsection constitutes a general overview only; details are found elsewhere herein.

C.3 Definitions and Glossary

“AC” means Alternating Current — http://en.wikipedia.org/wiki/Alternating_current.

“Array” means any number of photovoltaic modules connected together to provide a single electrical output.

“Blind Spot Ground Fault Protection” means protection from ground faults that occur within array wiring that go undetected by inverter ground fault protection hardware.

“BOS” means balance of system components — all needed systems other than modules; such as inverters, wiring devices, metering and mounting hardware.

“Contractor” means a selected offeror chosen through a formal bidding process to perform a scope of work.

“COR” means Contracting Officer’s Representative.

“DC” means Direct Current.

“DOE/FEMP” means Department of Energy – Federal Energy Management Program.

“Existing Roof Equipment” means equipment which shall include but not be limited to HVAC, window washing rigging, electrical, lighting arrestors, communications equipment, skylights and roof drains.

“Fair Market Value (FMV)” means The amount for which real property or Personal Property would be sold in a voluntary transaction between a buyer and seller, neither of whom is under any obligation to buy or sell.

“FASPP” means Federal Aggregation Solar Pilot Program – Project name for the requirements covered by this solicitation.

“GSA” means General Services Administration.

“GFP” means ground fault protection.

“Inverter” means a device that converts solar DC electric power into AC (single or multiphase) power for use in the building’s electrical system or the grid, or both.

“LBNL” means Lawrence Berkeley National Laboratory.

“NABCEP” means North American Board of Certified Energy Practitioners.

“NEC” means National Electric Code.

“NEM” means net metering — a special set of interconnection laws in a state which permit end use customer to operate a renewable energy system in parallel to the utility grid. The act of net metering usually refers to kWh generated minus kWh consumed – the “net” of production and consumption.

“NREL” means National Renewable Energy Laboratory.

“NETA” means International Electrical Testing Association.

“PTC/CEC” means performance test conditions used to qualify modules by California Energy Commission.

“PCS” means power conditioning system.

“PV” means photovoltaic system — the total components and subsystems that, in combination, convert solar energy into electric energy suitable for connection to utilization load.

“PVWatts” means a performance calculator for grid-connected PV systems developed by the National Renewable Energy Laboratory. See http://pvwatts.nrel.gov/.

“Shop Drawings” means drawings used to convey changes to 100% plan check that contractor proposes during construction phases.

“STC” means standard test conditions.

“UDC” means electric utility distribution company — the servicing electric utility with which the Contractor must interconnect.

“USFS” means United States Forest Service.

“Utility Provider” mean existing electricity utility.

C.4 Order of Precedence

See Section A.

C.5 Places of Performance

C.5.1 Facilities

US Forest Service – Pacific Southwest Region - Mare Island Address: 1323 Club Drive, Vallejo CA 94592

GSA - Robert F. Peckham Federal Building Address: 280 South 1st Street, San Jose CA 95113

GSA - John F. Shea Federal Building Address: 777 Sonoma Avenue Santa Rosa, CA 95404

GSA - Sacramento Federal Building Address: 2800 Cottage Way, Sacramento CA 95825

GSA - USGS Campus in Menlo Park Address: 345 Middlefield Road, Menlo Park CA 94025

GSA - C. Clifton Young Federal Building Address: 300 Booth Street Reno, NV 89509

GSA – Leo J. Ryan Federal Records Center Address: 1000 Commodore Drive, San Bruno CA 94066

GSA – Browning U.S. Courthouse Address: 95 7th Street, San Francisco, CA 94103

GSA Carson City Federal Building Address: 705 North Plaza, Carson City NV 89701

C.5.2 Minimum System Size Requirements and Maximum Annual Production

The table “System Minimum and Maximum Capacity Requirements” establishes:

1. The minimum aggregate first year production for each site in kWh per year. This will be verified at time of award using the PVWatts model. Systems submitted by Offerors must equal or exceed this minimum.

2. The maximum aggregate first year production for each site in kWh per year. The Government will not be required to purchase kWh over the maximum stated, although if there is excess production and the Government uses such production the Government will pay the price established by the contract.

The table is provided as a separate document.

C.5.3 Staging Areas

Contractor shall limit staging of equipment, laydown areas, storage of tools, and delivery of materials, to the areas indicated by the site management. Contractor can utilize areas for staging and laydown only with permission from the site and only for the indicated period of time.

C.6 UDC Interconnection Requirements

The contractor shall be subject to and shall satisfy the interconnection requirements of the electric utility serving each project site. The contractor shall provide any needed repair and upgrade to site electrical distribution equipment to meet interconnection requirements. The contractor shall provide the local utility companies with required drawings or diagrams, required product information, estimated energy production data estimates, and other specifications and data with respect to the proposed new generating systems as may be required by each UDC.

The Contractor shall be responsible for system impact studies when required by the serving utility or when warranted to produce a safe, functional and grid- compatible system.

C.7 Site Conditions

The Contractor shall provide all work necessary to explore, inventory, and evaluate existing facilities (including, but not limited to: mechanical, electrical, utility, structural, and architectural facilities) in order to complete the project. Where this exploratory and inventory work requires opening of finish surfaces, uncovering, demolition, and/or excavation, the contractor shall promptly return all such areas to preconstruction condition or better upon completion of investigations.

In the event that unforeseen site conditions are discovered which result in a negative feasibility determination for a given site the Government will permit a no-cost partial termination for the convenience of the Government to eliminate such site, subject to review and determination that the project is not feasible due to conditions that were not reasonably foreseeable. The Contractor must submit such a negative feasibility determination for the Government’s consideration not later than 60 calendar days after contract award.

C.8 Warranties

C.8.1 Total Array Output Warranty

Contractor shall maintain the system to achieve a performance ratio of at least 0.9 over any monitoring period. Calculation of the performance ratio shall take into account snow cover or other conditions beyond the Contractor’s control in estimation of how much energy the system should have produced over the monitoring period.

The ratio of actual to predicted performance is the “Performance ratio” as described in IEC 61724 or ASTM E2848 – 13 Standard Test Method for Reporting Photovoltaic Non-

Concentrator System Performance. Recommendations are provided in the NREL report Weather- Corrected Performance Ratio.1

This extended warranty shall apply for 25 years, to include if the Government negotiates a purchase of the system(s) from the Contractor. If the Government purchases the system(s) the warranty may be contingent on the Government performing reasonable recommended maintenance. The negotiated purchase may bilaterally modify the terms of this warranty.

C.8.2 System Degradation

The total array output shall not depreciate more than the percentage indicated by the Annual Degradation Factor offered in the Price Schedule. In no event shall the system depreciate more than 0.7% for each year of the 25-year warranty.

C.9 Personnel Qualifications

C.9.1 National Association Of Board Certified Contractors (NABCEP) Certified Installers With the exception of support laborers, electricians and tradesman shall be NABCEB certified.

C.9.2 Professional Engineer and Licensed Design Professionals

All architectural and engineering services shall be performed by California licensed design professionals (or Nevada licensed design professionals for those sites located in Nevada) with responsible charge (as defined in California Professional Engineers Acts, Section 6703) or responsible control (as defined in California Architects Practice Act 5535.1) for each respective design discipline.

Each submitted final Design drawing, calculation document, and specification manual shall be signed and dated by, bear the seal of, and show the State Certificate Number of the Architect or Engineer who prepared the document and is responsible for its preparation.

C.9.3 Project Manager

The Contractor shall assign a project manager with authority to represent the Contractor. The project manager must have at least five years’ experience with project management of photovoltaic installations of similar scale and complexity.

C.10 PV System Monitoring

C.10.1 An agency meter, Schneider ION 7550 or functional equivalent, shall be installed for agency use at each site. All agency specified meters to be completely independent of contractor billing meters and shall include separate current transducers, voltage sensing and communications cabling. The Contractor is not responsible for software integration of the meter into the agencies SCADA system, but the Contractor shall coordinate with the agency and agency’s systems integrator to provide field assistance with this function.

1 International Electrotechnical Commission (IEC). (1998). “IEC 61724 ed1.0.” Geneva, Switzerland: IEC. Accessed November 2014: http://webstore.iec.ch/webstore/webstore.nsf/standards/IEC%2061724!opendocument.

Alternatively, the Contractor’s revenue meter can be used as the second meter IF it has an available RS- 485 port and can communicate by Modbus. IP communication to the Government network will not be permitted since the Contractor and the Government will both be communicating to a common meter.

The Contractor must calibrate both the Contractor’s revenue meter and the additional meter if used, and provide certificate of calibration.

C.10.2 The Government may test the accuracy of the meter at any time at Government expense, and if not within specification it is to be immediately replaced or repaired by the Contractor.

C.10.3 Energy and site weather data (if weather stations are used) collected by contractor shall be made available to agencies through a web portal. A minimum of 25 months of data shall be stored by contractor’s web portal and be made available for agency download. The data shall at a minimum comprise the following information:

• Center of array irradiance either through onsite pyrometer or through satellite information, hourly historic data.

• Center of array temperature, hourly average historic data.

• Center of array wind speed, hourly average historic data.

• AC power.

If there is more than one PV system in the same vicinity they may share data regarding environmental conditions from a single monitoring station, and data from other nearby (2 miles) weather stations may be used, as well as purchasing satellite data from vendors, but it is the Contractor’s responsibility to secure and present data that is truly representative of conditions at the site to the government on an ongoing basis.

C.10.4 If incentive programs require use of a performance monitoring and reporting service, the Contractor is responsible for meeting such requirements in addition to other metering requirements herein.

C.10.5. For GSA sites, the Contractor must install Ethernet cable (cat 5e or cat 6) from the weather station and electric meter to the nearest GSA switch location. Alternatively wireless can be used if it meets NIST encryption standards. If wireless is used the Contractor must provide transmitter and receiver equipment and assure functionality of the wireless network. GSA is separately integrating the devices onto the GSA network and into the metering SCADA system.

C.10.6. Meters at GSA sites are subject to GSA device security requirements. The ION 7550 has been scanned and has a remediation plan from Schneider. If another meter is proposed as an alternative then the Contractor must submit an RFI for GSA to determine if that meter has been scanned and has an acceptable remediation plan with the manufacturer. If not the Contractor must:

(a) provide a meter temporarily for GSA to scan, with complete configuration information;

(b) obtain written assurance from the manufacturer that the manufacturer will make reasonable efforts to remediate any high risk or critical vulnerabilities detected.

C.11 System Startup and Commissioning

The contractor shall provide all work required for testing, start-up, and commissioning as required by the following requirements.

C.11.1 Commissioning standard IEC 62446 shall be followed.

C.11.2 Contractor shall provide services of third party Testing Agency that employs NABCEP or NETA certified engineers or technicians to perform start-up and acceptance testing of the specified PV system.

C.11.3 All start-up and testing activities may be witnessed by the FASPP’s Project Manager, Agency Site Project Coordinator and DOE/FEMP Inspector.

C.11.4 The system shall be started-up and tested in accordance with the regulations of the applicable interconnection standards.

C.11.5 Complete a system commissioning per the Specification and equipment manufacturer’s written instructions.

C.11.6 Request and coordinate the Utility Company and GSA for acceptance and certification of the PV system and permission to operate.

C.11.7 Set and adjust circuit protection devices according to Short Circuit and Coordination Study.

C.11.8 Commissioning shall include contractor’s Data Acquisition System (DAS)

C.12 Project Management Requirements

C.12.1 Meetings

Meet with the Government on site or telephonically as necessary to complete the work of this project.

Meetings are anticipated to include, but are not limited to, an in-person overall kickoff meeting in San Francisco, 50% and 90% on-site design review meetings, a pre-construction meeting at each site, and weekly telephonic progress meetings during design and construction. Additional meetings will likely be required in response to particular problems or issues that arise.

Where the Contractor reasonably synchronizes the schedules for multiple sites the Government will make reasonable efforts to schedule meetings efficiently so that Contractor and Government personnel traveling to meetings may attend multiple meetings on one trip.

The Contractor will create minutes for each meeting, circulate for comments within two working days of the meeting, and finalize within two working days of receipt of comments.

C.12.2 Permits and Licensing

The Government is exempt from local planning reviews and permitting. The Government is subject to NEPA, Clean Water Act and Clean Air Act to include most local agency enforcement of such statutes.

The Government is subject to the requirements of the National Historic Preservation Act; the Browning USCH is an historic building. For the Browning USCH the Contractor shall provide all information including design documents and renderings that may be required by the process described in Section 106 of the Act.

The Contractor is subject to all permits and licensing requirements governing the operation of the Contractor’s business outside of the Government sites. The Contractor is responsible for compliance with all such permitting and licensing requirements, to include project permitting and licensing where the Government is not immune from such requirements, and for compliance with any other federal regulations that apply to the work to be performed.

C.12.3 Schedule Management

In addition to the overall project schedule which must be approved before notice to proceed is granted, the Contractor must submit for approval:

1. Any revisions to the overall schedule for each site

2. A week-ahead schedule must be submitted by Thursday of each week for the next week, when construction activity is anticipated for the next week.

3. A request must be submitted two weeks in advance for any activity which requires an electrical or other service outage. Such outages must be scheduled for Saturdays, and must not disrupt agency activities.

4. Two weeks notice shall be given if the contractor’s activity is to interfere with access on or near the site, such as crane blocking a lane of traffic, staging areas blocking parking access, elevator use affecting ordinary use, or any other interference that affects operations in the building

C.13 Operational Requirements

C.13.1 Permits and Licenses

During the term of the contract the Contractor or assignee of the Contractor shall be the legal owner and operator of the systems. The Contractor shall operate the new electric generating systems in accordance with their permits, licenses, and in accordance with all local, state, and federal laws and regulations.

C.13.2 Maintenance of System

The Contractor shall be responsible for all aspects of maintaining and operating the PV array, including but not limited to: cleaning the arrays, replacing broken or worn out system components, performing maintenance in accordance with equipment manufacturer recommendations, the minimum performance standards established through this procurement. Contractor shall maintain solar PV array area to include mowing, raking, sweeping, mopping, dusting, snow removal, disposal of accumulated waste materials and rubbish and other operations necessary to present a neat appearance. The Contractor shall store all maintenance supplies and equipment only at approved storage area so as to preclude theft or damage and maintain the site in a neat and orderly manner. The system shall be maintained so as to comply with the version of the National Electrical Code (NFPA 70) in effect at time of contract award.

The Contractor shall maintain all records related to maintenance, and shall make all records available for the Government to review or copy on request with reasonable notice.

C.13.3 Emergencies and Unsafe Conditions

The Contractor shall promptly notify the Government if it becomes aware of any damage to or loss of the use of the solar PV systems or of circumstances that could reasonably be expected to adversely affect the arrays. The Contractor shall promptly notify the Government if it becomes aware of any event or circumstance that poses an imminent risk to human health, the environment, the solar array or the Premises. The Contractor shall immediately dispatch the appropriate personnel to perform the necessary repairs or corrective action in an expeditious and safe manner and notify site personnel.

In the event the Contractor fails to respond as required in the contract and in the event of emergencies, the Government may incur expenses to perform emergency repairs to Contractor installed equipment as well as Government equipment for which the Contractor assumed maintenance and repair responsibilities. The Contractor shall hold the agency harmless in such cases where the Contractor fails to respond appropriately in emergencies. The Contractor shall promptly reimburse the Government for any and all costs incurred in responding to such emergencies. Such reimbursement may include the Government adjusting the payment schedule, as necessary, to recover such costs.

C.13.4 Normal Building Electrical System Shutdowns

The Government may shut down building electrical systems up to three times per year, for a maximum of 72 hours in the aggregate, for electrical maintenance. If the government requires shut-down of the PV system exceeding 72 aggregate hours in any one year the contractor shall be paid for lost energy production as per the Price Schedule.

C.13.5 Roof Replacements and Major Repairs During Life of Contract

Each roof may undergo a replacement or major repairs requiring temporary dismantling and restoration of the system once during the period of performance. In such an event the Government will reimburse the Contractor as described in the Price Schedule.

The Government cannot guarantee on-site storage facilities for materials removed.

Contractor to assume one roof replacement or major repair to occur during life of contract. Government to pay costs to temporarily remove arrays and balance of system components that interfere with roof replacement. Once roof replacement work is completed, contractor to restore system to normal operation for the given year of the contract.

As part of bid response, contractor to provide the total cost of temporarily removing and restoring solar PV systems – see pricing schedule. Price provided by contractor in bid response shall be for year one (1).

For the year in which the roof replacement occurs, year one (1) bid price shall be inflated (compounded) using CPI numbers to determine the current cost of the temporary remove and then restore.

Determination of the amount of energy that would have been produced during the relocation shall be based on the NREL Performance Ratio methodology2

2 Walker, Ardani, Keating 2014

Contractor will have thirty days (30 days) from the written or verbal notice to restore system back to normal operation. If contractor fails to restore system within the thirty-day (30) period, contractor shall not receive payment for lost electricity sales past this period. If system is not restored within one (1) month of roof replacement completion, government shall retain the services of a qualified solar PV firm, at contractor expense.

On a space available basis, agency will provide staging area to store components onsite.

C.14 Design and Construction Standards

C.14.1 General

The contractor shall be responsible for the professional quality, technical accuracy, and the coordination of all investigations, evaluations, drawings, testing, cost estimating, submittals, written reports, construction, operations, and all deliverables as required by this Scope of Services document or as required to complete the work of this contract.

Prevention of harm to person or property from fire, electrical hazards or structural deficiencies shall be a priority consideration in design, construction, and system operation.

C.14.2 Specifications

The Contractor shall use ARCOM Masterspec to create specifications for design of each system, and submit such specifications with drawings as part of the 50%, 90%, draft 100% and final construction documents submittal packages.

The Contracting Officer may approve an alternative specification standard, where the Contracting Officer finds the alternative comparable in scope and rigor.

C.14.3 Codes and Standards

Design and construction must conform to the following standards (version current at time of proposal submission):

(a) International Code Council (ICC).

International Mechanical Code (IMC).

International Plumbing Code (IPC).

International Building Code (IBC) International Fire Code (IFC) (note: requires access and clearance around roof areas and other requirements related to fire protection).

(b) GSA 2014 P-100 Facilities Standards for the Public Building Service Chapter 6 shall take precedence over other electrical codes listed in this RFP to the extent there are contradictions.

(c) Occupational Safety and Health Administration Regulations for Construction; all regulations apply to all aspects of the project, with special attention to requirements for electrical safety and fall protection:

Title 29 Code of Federal Regulations 1910 Occupational Safety and Health Standards Title 29 Code of Federal Regulations 1926 Safety and Health Regulations for Construction.

(d) Environmental Protection Agency Regulations.

(e) AISC (American Institute of Steel Construction) Manual of Steel Construction, latest edition.

(f) ACI (American Concrete Institute) Building Code requirements for Structural Concrete (ACI-318, latest edition).

Manual of Concrete Practices

(g) ASCE (American Society of Civil Engineers) Minimum Design Loads for Buildings and Other Structures (ASCE-7, latest edition).

(h) National Roof Contractors Association (NRCA), The NRCA “Roofing and Waterproofing Manual.”

NRCA “Guidelines for Roof-mounted Photovoltaic Systems"

(i) Institute of Electrical and Electronic Engineers, Inc. (IEEE) IEEE C2 National Electric Safety Code (NESC) as applicable to modifications to the utility system not covered by National Electric Code (NEC).

IEEE 928 Recommended Criteria for Terrestrial PV Power Systems P929 Recommended Practice for Utility Interface of Photovoltaic (PV) Systems IEEE standard 1547 "Standard for Interconnecting Distributed Resources with Electric Power Systems".

Upon mutual agreement of the Contractor, Government and Utility, the low voltage ride through, low frequency ride through, and power factor adjustments afforded by the emerging 1547a standard may be considered.

IEEE 519 Recommended Practices and Requirements for Harmonic Control in Electric Power Systems IEEE 1262 Recommended Practice for PV Module Qualification PV Module Performance and Reliability IEEE P1373 Recommended Practice for Field Test Methods IEEE 1374 Guide for Terrestrial PV Power System Safety IEEE 2030 Guide for Smart Grid Interoperability of Energy Technology and Information Technology operation with Electric Power Systems and End-use Applications and Loads

(j) International Electrotechnical Commission (IEC);

1. IEC 60904 Photovoltaic devices –Measurement of photovoltaic current-voltage characteristics

2. IEC 61215 and IEC 61646 Design Qualification and Type Approval for crystalline silicon and thin film PV modules.

3. IEC 61646 - Thin film Thin Films & Amorphous Module Quality & Reliability

4. IEC 61724 Photovoltaic systems performance monitoring – guidelines for measurement, data exchange and analysis

5. IEC 61730 “Photovoltaic (PV) module safety qualification”

6. IEC 61727 Photovoltaic (PV) systems – Characteristics of the utility interface

7. IEC 62093 “Balance-of-system components for photovoltaic systems - Design qualification natural environments”

8. IEC 62108 Concentrator photovoltaic (CPV) modules and assemblies - Design qualification and type approval

9. IEC 62109 “Safety of power converters for use in photovoltaic power systems” both Parts 1 and 2.

10. IEC 62446 Grid connected photovoltaic systems – Minimum requirements for systems documentation, commissioning tests and inspection

11. IEC 62548 Installation and Safety Requirements for Photovoltaic (PV) Generators

(k) Underwriters Laboratory (http://www.ul.com). Only products that are listed, tested, identified, or labeled by UL, FM, ETL, or other nationally recognized testing laboratory shall be used when available.

Non-listed products are permitted only when listed products do not exist. Non-listed products must be identified as such in all submittals and must be approved by the Government prior to use in construction of the systems. Underwriters Laboratory standards referenced include:

1. UL 467 Safety Standard for Grounding and Bonding Equipment

2. UL 969 Recognized Materials Marking and Labeling Systems

3. UL 1699 Arc-Fault Current Interrupters

4. UL1703 Standard for Safety for Flat Plate Photovoltaic Modules and Panels

5. UL1741 Inverters, Converters, Controllers and Interconnect System Equipment for Use with Distributed Energy Resources

6. UL2703 Rack Mounting Systems and Clamping Devices for Flat Plate Photovoltaic Modules

(l) Factory Mutual; for components where approval is available specify FM Approved,

1. FM Approved, Fire Protection tests for Solar Components

(m) National Fire Protection Association (NFPA)

1. NFPA 1 Fire Code

2. NFPA 70, National Electrical Code (NEC) - Refer to the version of the NEC which is adopted by the Washington D.C. jurisdiction having authority. The electrical requirements of the National Electric Code, have been adopted by GSA in lieu to the technical electrical requirements of the ICC Electrical Code. All sections are referenced, with particular emphasis on articles:

i. NEC Article 300: Wiring Methods and Materials

ii. NEC Article 690: Solar Photovoltaic Systems

iii. NEC Article 705: Interconnected Electrical Power Production Sources

3. NFPA 70E Standards for Electrical Safety in the Workplace

4. NFPA 101 Life Safety Code. Egress requirements of the National Fire Protection Association (NFPA 101), Life Safety Code shall apply in lieu of other code references

5. NFPA 780 Standard for the Installation of Lightning Protection Systems

(n) International Association of Plumbing and Mechanical Officials (IAPMO), Uniform Solar Energy Code Safe Solar System Requirements (2006).

(o) American Society of Civil Engineers,

1) ASCE 7 (most recent) Minimum Design Loads for Buildings and Other Structures.

(p) Structural Engineers Association of California (SEAOC) PV 1-2012 (or most recent) “Structural Seismic Requirements for Rooftop Solar Photovoltaic Systems” PV 2-2012 (or most recent) “Wind Design for Low Profile Solar PV Arrays on Flat Roofs”.

(q) Steel work shall comply with AISC Manual of Steel Construction, latest edition.

(r) National Roofing Contractors Association (NRCA).

1. NRCA “Roofing Manual.”

2. NRCA “Waterproofing Manual”

3. NRCA “Guidelines for Roof Systems With Rooftop Photovoltaic Components”

(s) ASTM International (formerly American Society for Testing and Materials (ASTM)

1. E1026-08 Standard Test Methods for Electrical Performance of Non-concentrator Terrestrial Photovoltaic Modules and Arrays

2. E1038-10 Standard Test Methods for Determining Resistance of Photovoltaic Modules to Hail

3. E1171-09 Standard Methods for Photovoltaic Modules in Cyclic Temperature and Humidity Environments

4. E1462-00(2006) Standard Test Methods for Insulation Integrity and Ground Path Continuity of Photovoltaic Modules

5. E1799-08 Standard Practice for Visual Inspection of PV Modules

6. E1830-09 Standard Test Methods for Mechanical Integrity PV Modules

7. E2848 - 13 Standard Test Method for Reporting Photovoltaic Non-Concentrator System Performance

8. E2939-13 Standard Practice for Determining Reporting Conditions and Expected Capacity for Photovoltaic Non-Concentrator Systems

(t) California Energy Commission Listing

(u) IESNA Dark Sky Standards

(v) GSA purchases for products and services must meet sustainable product requirements of the PBS Sustainable Products Requirements List. The Contractor shall comply with these sustainable product requirements by using products that meet the criteria and standards listed. The contractor is responsible for providing sufficient documentation to confirm that the products provided have the required sustainable criteria, upon the Government's request.

C.14.4 Structural Engineering

For arrays on flat or slow slope roofs (<=7 degrees), current ACE 7.05 or ACE 7.10 must be augmented by the use of “Wind Design For Low-Profile Solar Photovoltaic Arrays on Flat Roofs” Structural Engineers Association of California – SEAC Report #PV2-2012, August 2012.

Page 6 of SEAC report lists the following changes/additions to ACE 7-10 with flat roof systems:

1. Adding Section 29.9 to address solar arrays on flat roofs

2. Modifying Table 29.1-1 to include solar arrays

3. Adding Figure 29.9.1 to determine pressure coefficients for solar arrays

4. Adding a definition of Effective Wind Area for solar arrays

5. Adding Section 31.6 to address wind tunnel testing of solar

6. Submit structural engineering calculations showing use of SEAC Report #PV2-2012.

C.14.5 Service Conditions

Materials shall be designed to withstand the year-round temperatures and conditions to which they are exposed (sunlight, heat, rain, cold, wind, seismic, salt air, fog, marine corrosiveness, etc.). Site-specific service conditions are presented in the “Site Specific Specifications” for each Site. Refer to the appendices to this Scope of Services document.

C.14.6 Same Manufacturer & Product Line

All modules, inverters and electrical switchgear to be of same manufacturer and product line for each array.

C.14.7 Locating Equipment

Major electrical components, including the inverter, isolation transformer, and metering shall be installed in code compliant enclosures. Components shall be located indoors whenever feasible, in ventilated (non-air conditioned) utility rooms and where space and codes allow. When inverters and major electrical components are located outdoors they shall be protected from direct exposure to weather (sun, rain, snow and sleet) and leafy debris. Simple open-sided shed roof structure is sufficient or under shaded carport arrays. Inverters shall not be located on roofs exposed to weather and leafy debris.

C.14.8 Expected Service Life

Unless noted otherwise, all materials furnished for the project shall have an expected service life of thirty-years (30) or more.

C.14.9 Minimum Transformer Efficiency Rating

If new transformers are installed, then high efficiency transformers shall be furnished. All transformers shall comply with “NEMA Premium” and be of amorphous steel core with bio-based oil.

C.14.10 Array Ground & Arc Fault Detection and Remediation

Hardware shall be included to detect DC ground and arc faults. Once faults are detected, automatic system shutdown must occur and contractor shall dispatch qualified electrical technicians to site within 24-hour notice in order to locate fault and make necessary repairs.

C.14.11 Acceptable Array Ground And Arc Fault Hardware Detection Schemes:

C.14.11.1 For Grounded Systems

a. An arc-fault detection system which is NRTL-listed and compliant to the 2014 National Electrical Code must be installed. If fault occurs, system must shutdown and automated alarm be sent to contractor.

b. The PV system must include DC residual current detector(s) (RCDs) that disconnect faulted circuit(s) and transmits an alarm alert to contractor.

C.14.11.2 For Ungrounded Systems

a. An arc-fault detection system, which is NRTL-listed and compliant to the 2014 National Electrical Code, must be installed. If fault occurs, system must shutdown and automated alarm be sent to contractor.

b. The PV system must include DC residual current detector(s) (RCDs) that disconnect faulted circuit(s) and transmits an alarm alert to contractor.

c. Inverter includes a morning wakeup isolation resistance (Riso) check through built-in hardware. If test fails, the system must be shut down and automated alarm be sent to contractor.

C.14.12 Lightning Arrestor

If a dedicated or separate grounding electrode is added for the lightning suppression as is described in 2014 Section 690.47(D) then the “Auxiliary Grounding Electrodes,” must be bonded to the premises’ grounding-electrode system.

If solar array lighting protection is required by code, contractor may couple to existing lighting system only if codes requirements can be maintained.

C.14.13 Module Safety, Quality, and Long-Term Performance

C.14.13.1 Part One ─ Specifications Section

Minimum Performance Requirements:

IEC 61215 – Silcon Cyrstal Modules IEC 61646 – Thin Film Modules IEC 62108 – Concentrated Solar PV Modules 25-Year Minimum Warranty – Linear

Minimum Safety Requirements:

UL 1703

IEC 61730 (Parts 1 and 2) Class C Fire Rating when used on or near buildings

C.14.13.2 Part Two ─ Selection Criteria

1. Contractor track record of low failure rates with operating and maintaining systems of similar design to that proposed.

2. ISO 17025 or Equivalent Quality Program in Manufacturing of Proposed Module & Inverter

3. Warranty Return Rates with Module Proposed

4. Adherence to some or all of the extended module quality and safety tests as detailed in Appendix A of the NREL Photovoltaic Module Qualification Plus Testing program3 http://www.nrel.gov/docs/fy14osti/60950.pdf

C.14.14 Solar Photovoltaic Array Glare Hazard Prevention

For any array which will be located in the view shed of a neighboring building, aircraft control tower, or runway approaches, contractor is to perform a formal “Glare Hazard Analysis” using the “Sandia Glare Hazard Analysis Tool (SGHAT) - https://share.sandia.gov/phlux .

Contractor is to include the SGHAT results as part of the 50% submittal package.

C.14.15 Wire, Cable and Conduit Management

3 Photovoltaic Module Qualification Plus Testing, Sarah Kurtz, John Wohlgemuth, Michael Kempe, Nick Bosco, Peter Hacke, Dirk Jordan, David C. Miller, and Timothy J. Silverman National Renewable Energy Laboratory http://www.nrel.gov/docs/fy14osti/60950.pdf https://share.sandia.gov/phlux

Direct Current (DC) Circuits: All interior and exterior DC conduits, raceways, enclosures, cable assemblies, and junction boxes associated with the PV system shall be marked to alert individuals that DC power is present. The marking shall be placed every ten (10) feet or fraction thereof, at turns and above and below penetrations, and on all DC combiner and junction boxes.

Wire Management: Wire cannot lie exposed directly on roof surface or ground. Long horizontal conduit runs shall have expansion unions every 30’ in order to reduce wire abrasion caused by fixed couplings.

Couplings and expansion unions to use anti-abrasion bushings. All power wiring shall be attached to the system components by the use of strain reliefs or cable clamps, unless enclosed in conduit.

Location of DC Conductors: To limit the hazard of cutting live conduit in fire department venting operations, DC wiring shall be run in metallic conduit or raceways when located within enclosed spaces in a building and shall be run, to the maximum extent possible, along the bottom of load-bearing members. Exposed conduit, wiring systems and raceways for PV circuits shall be located as close as possible to the ridge or hip or valley on the roof to reduce trip hazards and maximize ventilation opportunities.

Ground Mounted PV Arrays: Ground mounted PV arrays shall, have a minimum clear brush area of ten (10) feet on all sides.

C.14.16 Minimum Permanent Signage and Labeling

1. For rooftop systems, the signage shall contain the text “CAUTION PHOTOVOLTAIC SYSTEM

INSTALLED ON ROOF.”

2. For parking lot and ground mounted systems, signage shall contain the text “CAUTION

PHOTOVOLTAIC SYSTEM”

3. Warning letters shall consist of letters having a principal stroke of not less than ¾ inch wide and be at least six (6) inches high on a contrasting background.

4. When serving utility, applicable codes and authorities having jurisdiction require additional or different signage – these requirements supersede above.

5. Signage is required on all stairway doors providing access to the roof where PV systems are installed. Each stairway door providing access to the roof shall have a sign affixed to the interior side of the stairway door.

6. Print or engrave 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 shall not fade when exposed to sunlight and shall be secured to prevent easy removal or peeling.

C.14.17 Minimum System Energy Performance

1. Offeror to state minimum warranted system output along with annual module and system total annual degradation.

2. The methodology to determine if system is performing to the warranted minimum shall be the NREL Performance Ratio methodology cited above. Linear module warranties shall be used to determine module degradation factors for any given year of the contract period.

3. If system performance falls below minimum production levels as required herein, the Contractor is required to perform retro-commissioning of system to identify all substantive issues affecting performance and safety of system within 60 calendar days of the end of the performance year in which performance was substandard (each performance year beginning at the anniversary date of system startup). Submit a retro-commissioning report indicating remedial action taken within 90 calendar days of the end of the performance year.

C.14.18 Arrays On Flat Roofs

1. Self-Ballasted Where Possible. Solar PV arrays on flat roofs shall be self-ballasted style designed to minimize penetrations through roofing system. If building structure cannot support array ballast, contractor shall propose partially ballasted system that uses minimum roof penetrations. If building structure cannot support any array ballast, fully anchored systems will be allowed as a last choice.

2. Structural Limitations. For facilities where ballast weight cannot be supported by building structure and or where high wind speeds warrant, proposed roof array systems may in these cases incorporate a tie-down system that penetrates roofing in order to attach to underlying roof frame members. Extra system tie-down will be allowed only where ballast weight needs to be reduced and or wind speeds are high. A tie-down system that incorporates a minimum number of roof penetrations is preferred.

3. Annual Roof Inspections And Repairs. All roof-mounted array systems shall allow normal routine roof inspections and maintenance to continue unimpeded; shall allow for visual inspections and physical access needed to perform roof repairs.

4. Weather Proofing Penetrations. All roof penetrations shall be designed and constructed in collaboration with the roofing professional or manufacturer responsible for the roof and roofing material warranty for the specific site. The number and size of the penetrations necessary to extend the power and control cable into the building must be kept to a minimum and grouped in a single location when practicable. All weather proofing of penetrations shall be compatible with the roof warranty.

5. Existing Rigging. Rooftop installation shall coordinate with the building-rigging plan associated with powered platform, etc. and address the relocation or incorporation of the davits.

6. Describe materials and methods to be undertaken to create watertight seals in roofing systems for anchor points and conduit.

7. Steps or ramps shall be provided where defined walkways created for maintenance personal to navigate in and around arrays for equipment access intersect with conduit, pipe or duct runs.

8. Contractor shall contract roofing contractor holding the warranty for the roof or if none a roofing company certified by the roof manufacturer, ascertain their required process of design approval, product certification, and inspection and fulfill the requirements such that the integrity of the roof is preserved and the warranties remain valid.

C.14.19 Shaded Carport Arrays

1. General Design Guidelines: Carports shall be designed to be supported by central support posts and cantilever over parking spaces on both sides, like a ‘T’. All carports are intended to be of similar design at approximate width to cover two cars parked end to end and of varying lengths.

The width may range between 36’ and 40’ and lengths may be adjusted by plus or minus four feet to match and optimize various panel layouts. Federal agencies seek a balance between aesthetics and maximizing electrical production.

2. The PV panels on the carport shall be sloped to balance aesthetics and power production. The carport PV shall be at least 9 feet clear in all locations.

3. Purlin Deflection. Purlin deflection shall be limited to L/180 or less.

4. Parking Lot Lighting. Existing parking lot lighting poles and fixtures illuminating proposed solar PV carport areas shall be removed and lighting restored by new LED fixtures mounted to carport structure. The LED fixtures shall be FEMP Designated or Energy Star and allow for control through photocell. Lighting layout to achieve IES recommended foot-candle levels and uniformity for parking lots - ANSI/ASHRAE/IESNA Standard 90.1-2007 and also comply with the International Dark Sky (IDA)/IESNA Lighting Ordinance – Model Lighting Ordinance - Latest Version.

5. Lighting for Security Cameras: New, array mounted light fixtures shall also provide illumination levels and distribution needed to support existing security camera systems and comply with the Proposed lighting layout and specification to be part of submittal package.

6. Fire Lanes. Fire lanes established to access any adjacent facility by local fire department shall be maintained and comply with California or Nevada state Fire guidance. Changes to fire lanes are allowed but only under approval by Fire authorities having jurisdiction over site and under coordination and approval by agency project manager. Fire lanes are to be shown on submittal drawings.

7. American Disabilities Act (ADA) COMPLIANCE. All changes to parking lot shall comply with ADA requirements.

C.14.20 Ground Mounted Systems

1. All ground-mounted electrical supporting equipment (inverters, transformers and switchgear) shall be installed on concrete slab(s) with appropriately sized and spaced rebar. The sizes and strength of the pad and rebar shall be adequately calculated and designed by the contractor.

2. Contractor shall provide and maintain site protection to keep deer, children, vandals, wildlife and unauthorized personnel out of ground sites. At a minimum provide chain link fence minimum six feet high with a lockable gate. Key is to be provided to Government. Contractor shall provide for vegetation growth control in the PV parcel and shall be responsible for a fire control and weed control program.