Attachment 04 PV BESS Technical Specifications PSL 05 22.docx

PHOTO VOLTAIC AND BATTERY ENERGY STORAGE SYSTEM

DESIGN SPECIFICATIONS

Prepared by Otto Van Geet National Renewable Energy Lab

Table of Contents

Abbreviations and Acronyms

1. Scope of Work

1. Design and Install Photovoltaic and Battery Energy Storage System

1. Design and build a minimum 26 kW roof mounted photovoltaic system and 24 kW, 100 kWh Lithium-ion Battery Energy Storage Systems (PV + BESS). The PV system shall be physically attached to the building concrete roof and tilted at 5 degrees to the south. The PV system shall be designed to withstand category 5 hurricane winds. Due to the critical life safety nature of this system and necessity of power delivery, this system should be considered risk category IV, exposure category B, and gust factor I when applying ASCE-7 2016 standards, or other agreed upon design requirements.

2. Integrate the PV + BESS with the existing 120/240 V building electrical distribution system.

3. The PV inverters, BESS and BESS inverters may be installed in room 201 (11’ x 9’-9”) or in an exterior container located near the building, or a combination of building and containers installation. The room and/or container shall be equipped with exterior grill and thermostatically controlled exhaust fan and/or air conditioning system. Battery energy storage systems, components, and associated ancillary equipment shall have required working space clearances, and electrical circuitry shall be within weatherproof enclosures marked with the environmental rating suitable for the type of exposure in compliance with NFPA 70. Spaces about the ESS shall comply with NEC 110.26. Working space shall be measured from the edge of the ESS modules, battery cabinets, racks, or trays, (NEC 706.10(C), NEC 480.9, 110.26)

4. Grid outage scenario: Integrate the PV + BESS with the existing 60 kW Generac emergency generator and automatic transfer switch (ATS). Install a microgrid control system and modify the existing ATS as necessary to provide electricity to the building upon grid failure as follows:

a. Provide electricity from the PV + BESS until the BESS is drained to 20% (20 kWh) remaining.

b. When the BESS is at 20% start the emergency generator to power the building and recharge the BESS. When the BESS is 80% charged turn off the emergency generator and power building with the PV + BESS until BESS is at 20%, then start the emergency generator again. Repeat this cycle until grid power is returned.

5. Demand control scenario: Integrate the PV + BESS to provide grid electricity demand control/ peak shaving to limit demand (kW) to programmed setting. Current Aviary monthly peak demand is 35 kW, and average load is 10.6 kW. Limit grid demand to 25 kW (adjustable).

6. Commission PV + BESS and provide commissioning report documenting PV + BESS performance during normal grid tied operations, during demand control and during grid failure.

7. Provide one year of turnkey PV + BESS operation, maintenance, warranty.

8. Contractor shall provide all labor, material, equipment, engineering, maintenance and capital to design, install, commission, and interconnect a PV + BESS as required herein.

9. Contractor is responsible for all permits, approvals, environmental compliance, freight, financing, procurement, monitoring, site inspection, billing, and incidentals as necessary to design, construct and interconnect all the complete PV + BESS systems, described hereinafter.

1. Existing Feasibility Studies and Engineering Studies Done by Others The Contractor is responsible for ascertaining relevant site conditions to determine project feasibility and final PV + BESS size according to the terms of this solicitation. If any existing engineering studies or facility conditions reports are provided through this solicitation from the site information package or agency representative, the bidder and Contractor shall independently verify all information provided.

1. Codes, Standards, and Regulations The Public Buildings Amendments of 1988, Public Law 100-678, Section 21 requires that for new construction and renovation projects, the government shall, to the maximum extent feasible, be in compliance with one of the nationally recognized model building codes and with other applicable nationally recognized codes. The latest edition of the local and nationally recognized codes and any updated supplements in effect at the time of contract award, shall be used throughout the project design and construction. Codes and standards applicable to the PV + BESS project can be found below.

Electric Power Requirements. Electricity from the PV + BESS system must be provided at 60 Hertz and at the appropriate voltage for electrical interconnection to the Site at the voltage service level, which will be specified by Trustees.

The PV + BESS components must comply with all codes and standards relevant to the operation and installation of PV and energy storage equipment by UL or other nationally recognized testing facility. PV, Batteries, enclosures, inverters and components must be certified to comply with the following requirements:

· UL Subject 1741, “Standard for Static Inverters and Charge, Converters, Controllers and Interconnection System Equipment for use with Distributed Energy Resources”

· UL Subject 1973 “Batteries for Use in Light Electric Rail Applications and Stationary Applications”

· UL Subject 1642 “Standard for Lithium Batteries”

· UL Subject 508 “Standard for Industrial Control Panels”

· UL 9540 Standard for Energy Storage Systems and Equipment

· UL 1703 Standard for Safety for Flat Plate Photovoltaic Modules and Panels

· Other codes and standards that will apply include but are not limited to:

· ANSI C12.1-2008; (electricity metering)

· National Electric Code 2017

· NFPA 70 (including NFPA 70E Arc flash)

· UL 1699 Arc-Fault Current Interrupters

· IEEE 1547

· NFPA 855, Standard for the Installation of Stationary Energy Storage Systems

· ASCE-7 Minimum Design Loads for Buildings and Other Structures

· IEC 61727 PV systems Characteristics of the utility interface

· IEC 62446 PV Commissioning, Documentation, Tests, and Inspection

· IEC 61215 Design qualification and type approval for crystalline silicon PV modules

· IEC 61730 Module safety qualification

· UL 467 Safety Standard for Grounding and Bonding Equipment

· SEAOC Report #PV2-2017 Wind Design for Solar Arrays” UL 270 Rack Mounting Systems and Clamping Devices for Flat Plate Photovoltaic Modules

1. Interconnection to Electrical Distribution Systems It is the sole responsibility of the Contractor to meet PREPA interconnection requirements.

Government owned electrical distribution system requirements Modifications or upgrades to the electrical system required to interconnect the PV + BESS systems are the responsibility of the Contractor (e.g. service panel, generator coordination). Any needed upgrades or modifications to existing agency electrical distribution systems must be included in the review and approval process outlined in the submittal section herein.

Franchise Utility Electrical Distribution Systems Interconnections The Contractor shall provide interconnection of the PV + BESS system with the electrical distribution system and take actions to ensure that the two components are compatible. Modifications or upgrades to the electrical system for interconnection are the responsibility of the Contractor. The Contractor is responsible for the proper circuit sizing, overcurrent protection, and coordination of the circuit(s) beyond the point of interconnection, including modifications to the site’s electrical equipment and circuits. The Contractor will assume the costs of these modifications. Any modifications to the approved PV + BESS system design that would affect the electrical distribution system shall require the written approval of the government.

The Contractor is responsible for complying with all electric utility interconnection requirements, including upgrades, providing all necessary PV + BESS system details for the interconnection applications, and funding any required interconnection studies to be performed by or on behalf of the electric utility. The Contractor is responsible for gaining approval from the electric utility for interconnection and any electric utility-required upgrades.

The Contractor shall provide supporting documentation or drawings required by PREPA.

Any local codes required by utility interconnection laws and regulations shall be followed by the Contractor.

1. Permits and Licensing The Contractor shall be responsible for:

· Preparing all permitting and licensing applications for the project

· Providing any supporting documentation, data, and information that may be required

· Coordinating and acting as the primary liaison with permitting and licensing agencies

· All permitting and licensing fees

· Complying with all requirements of permits and licenses for the project

1. Local Fire Marshall Involvement The Contractor shall involve the fire marshal or organization responsible for fire protection to provide design advice and design approval. The Contractor shall review the design of the system with the fire marshal and also observe design guidelines regarding firefighter access in the International Association of Fire Fighters and the NEC 2017.

These guidelines include requirements for pathways through the array, cutouts where firefighters can pass each other and lay down equipment, smoke ventilation, required markings and signage, and other important information. The Contractor shall invite local firefighters to a training where firefighters will be shown how the PV + BESS system works and how to shut it down, form a fire suppression plan, and shall work with the fire marshal to determine where to post the permanent instructions and required markings. The Contractor shall coordinate with local fire marshals on PV array and battery setback requirements, first responder training, and posted instructions for shutoffs.

2. Engineering and Construction by Array Type

2.1 All Array Types

2.1.1 Professional Engineer and Licensed Design Professionals All architectural and engineering (A-E) services shall be performed by design professionals licensed in Puerto Rico with responsible control for each respective design discipline. Preference will be given to bidders with experience designing structures, especially PV arrays, in high wind environments. Upon request by the government, all design and/or coordination meetings shall be attended by the A-E licensed design professionals, at no additional cost to the government.

2.1.2 Registration Seals

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

2.1.3 North American Board of Certified Energy Practitioners (NABCEP) The installation crew shall include at least one NABCEP “PV Installation Certified” installer. The goal of this is to ensure that the Contractor follows industry best practices in regard to the installation, operations, and health and safety of the PV system.

2.1.4 Coordination of Professional Services

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

2.1.5 Coordination of Subcontractor’s Credentials

The contractor shall ultimately be responsible for the completeness, accuracy, and coordination of all submittals but may delegate the preparation of submittals in whole or in part to subcontractors or suppliers.

2.1.6 Modifications and Alterations of Government Property

Modifications, alterations, and/or additions to existing facilities shall be designed and certified to satisfy applicable requirements of this Statement of Work (SOW) document and the governing codes and standards referenced in this SOW document.

2.1.7 Severe Weather

The PV + BESS system equipment shall be designed to withstand severe weather events, including sustained high winds, hurricanes, tornadoes, and thunderstorms including summer monsoons, and flooding.

Minimum Loading Strengths of Modules PV Modules shall be tested per ASTM E1830-15 prescribed test parameters for loading (snow and wind) of solar modules (front and back). The test also covers several other stress factors relevant to high winds such as the “twist test.” For best protection against physical damage, the Contractor shall consider modules that are rated for “Very Severe Hail” as per ANSI 4473. Table 3 below provides specific data on front and back load ratings. Modules shall be LG365Q1C-A5 or approved equal.

Minimum Loading Strength of Modules

Minimum Performance Requirements:

1. IEC 61215 – Silicon Crystal Modules

2. 25-Year Minimum Warranty – Linear

3. Minimum Safety Requirements:

a. UL 1703

b. IEC 61730 (Parts 1 and 2)

Mounting Solar Modules

· Specify PV panels and rail/rack systems that have UL 1703 and UL 2703 listing (as applicable), and an ICC AC 428 evaluation report.

· Fastener failures are a common primary point of failure for PV systems in severe weather, so this system requires robust design and quality installation of all bolted joints.

· Modules shall be through-bolted to the underlying racking only; top down clamps should not be used under any circumstances.

· Threaded fasteners should include locking mechanisms to address both preload relaxation and joint slip.

· Spring washers such as Belleville washers shall be used to compensate for preload relaxation, as specified by the structural engineer

· Wedge-lock washers and pre-applied thread lock can help mitigate slip in the bolted joint, fasteners should be designed and installed by the structural engineer in accordance with standard DIN 65151.

· Under no circumstances shall split washers, nylon-insert nuts, double-nutting, star washers, and/or serrated flange nuts be used to provide fastener locking capability.

Clamping Under no circumstances shall clamping systems be used to hold:

1. Underlying structural frame members together

2. Module frame to underlying structural frame member Tapping Sheet Metal Screws Under no circumstances shall self-tapping sheet metal screws of any grade be used to hold array structural elements together or to mount conduit, electrical enclosures, metering, and weather station components. Further, these screws shall not be used to field-assembled fencing, lighting, security camera systems, and communications equipment. Any proposed use of self-tapping screws must be pre-approved by agency CO or COTR having authority. Any such screws approved for use must be SAE 316-grade stainless suitable for marine applications.

Special Note on Use of Chemical Locking Compounds Chemical locking compounds can be used effectively to lock fasteners, however, there are three significant limitations to these products that contractors should be aware of. Thread locking compounds prevents re-tightening should a bolted joint loose pre-load on fastener. Additionally, chemical compounds prevent torque audits. It is unclear how durable locking compounds will be when exposed to heat, moisture, sunlight and corrosive dust and marine air.

Torque Rating of Fasteners Each sub-assembly shall be torqued to manufacturer’s specification using torque wrenches or drivers designed to provide calibrated and metered forces and be rated by ISO 6780-2. For field-assembled components of disparate manufacturers or from custom fabrications, a structural engineer shall specify torque ratings and field assembly procedures to be included in submittals and construction drawings. These torque ratings and procedures shall be included in operations and maintenance manuals for later use.

For fasteners holding friction or clamping forces, Section 3.3 of ICC AC 428, 2012 shall apply. For permanently locking fasteners such as lock bolts or those with pre-applied thread locking compounds, complete only steps 1-2.

At a minimum, field assembly and audit procedures shall include:

1. Threaded fasteners shall be pre or field treated with anti-galling compounds. The contractor shall consider a high strength removable thread locker compound.

2. Fastener to be torqued with a calibrated torque wrench to specification to achieve full loading.

3. Contractor will mark each fastener torqued with metal marker to indicate complete installation of the fasteners. Figure 2 shows a market nut, indicating torqueing has been performed.

4. Allow metal surfaces of bolted joint to mate after the initial torque rating is achieved.

5. Each fastener is to be torqued to spec a second time. Mark the bolts with a different color or marking. This marking can be referenced in the future to visually inspect whether a fastener has loosened (See figure below).

Soft Joint Bolting In instances where tubular materials are bolted together forming “soft joints”, the following bolting requirements apply:

· Project engineer to specify torque ratings to achieve proper pre-loading on bolt that provides needed clamping forces without collapsing joint.

· Use of locking fastener that can compensate for joint relaxation due to loss of bolt pre-load shall be used. Use of “Belleville” or spring/cupped washers to be specified by product or project engineer shall be used to maintain bolt preload with soft joints.

Framing considerations from observations of field failures Use of thin-walled cold rolled steel members Array’s built using light-gauge cold rolled steel members pose several challenges that must be considered during the design and engineering phases.

Thin-walled cold rolled channel members have larger profiles in order to reach strength ratings along certain axes, but they can be unstable along several other important dimensions and therefore must be braced and restrained in order to prevent deformation when exposed to high winds.

When designing structural members, ensure they are designed to resist loads from any direction.

2.1.8 Corrosion Resistance

All PV hardware and rack components shall be of corrosion-resistant material, such as stainless steel SAE grade 316. Aluminum and hot-dipped galvanized steel may be used for non-marine environments under ASTM F2329 specifications.

2.1.9 Array Grounding Systems

To prevent electric shock and fire, a protective ground must be done on the frames of solar modules and arrays. The grounding system shall be independent of the module mounting system. Components in the array grounding system shall comply with module manufacturer requirements and consist only of copper, brass, and stainless-steel componentry. Under no circumstances shall grounding lugs be mounted using standard carbon steel fasteners. Grounding lug set screws must be of the same metal as lug or stainless steel to prevent galvanic corrosion.

2.1.10 Wire Management

Under no circumstances shall plastic (non-metallic) cable-ties be used to secure and organize array wiring exterior to electrical enclosures. Exterior, long-life plastic ties shall not be used. Stainless steel ties or other stainless or galvanized hardware shall be used in wire management. Ties shall be UL-listed and have a minimum breaking strength of 40 lbs.

No mast heads entering the top or side of electrical enclosures shall be used to route string wiring into cabinets. String electrical conductors are to be routed through the bottom of the electrical enclosures to prevent wind-driven water infiltration.

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.

2.1.11 Conduit and Preventing Water Intrusion

Conduit routing and fittings must be selected to prevent water intrusion into inverter enclosures, combiner boxes, switchgear, and transformers. Conduit are to connect through the bottom of enclosures and provide fittings to allow water to drain prior to entering electrical enclosure.

Any exterior PVC conduit must be Schedule 80. All exterior wiring downstream of combiner boxes or string inverters must be in conduit.

2.1.12 NEMA Rated Enclosures

All exterior housings must be continuously welded, NEMA 4X (or better), fully gasketed, continuously hinged (piano hinge) with three-point door closure clamps, and designed to prevent water intrusion from hose-directed water, splashing water, and wind driven rain. Gaskets must be molded and of one continuous shape with no seams. All equipment mounted to the interior of the enclosure shall use back plates to minimize exterior cabinet penetrations. Conduit entry into electrical equipment shall be designed to prevent water intrusion. Minimum mounting height of enclosures shall be based on the 500-year flood plain and surge levels.

2.1.13 Locating Equipment and Appearance

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 (or 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. A simple open-sided shed roof structure is sufficient. Under no circumstances shall inverters be located on roofs in direct sun.

The Contractor shall coordinate with the Contracting Officer’s Technical Representative (COTR) and Electrical Engineer (EE) regarding locations and appearance of all equipment, including PV modules, conduit, inverters, disconnect switches, wireways, and control and monitoring equipment. The COTR and EE must approve all locations prior to installation.

2.1.14 Expected Service Life

Unless noted otherwise, all materials furnished for the project shall have an expected service life of thirty (30) years or more, given the unique service conditions of each array site. Equipment warranties (modules, inverters switchgear) are shorter than the expected service life. With a 30-year system life, it is common and well understood by industry that inverters and a small percentage of failed modules would need to be replaced, though the system as a whole would provide at least 30 years of service. Agencies should seek the type of equipment and workmanship that can result in a 30-year system.

2.1.15 Site Service Conditions

Materials shall be designed to withstand the year-round temperatures and conditions to which they are exposed (sunlight, heat, humidity, rain, , wind, seismic activity, salt air, fog, marine corrosiveness, etc.)

2.1.16 New Equipment

The Government shall not accept used, reconditioned, after-market, or grey-market products or equipment. Any offeror supplying used, reconditioned, after-market, or grey-market products may be held responsible for damages to the Government.

2.1.17 Markings (Labeling)

Strict conformance to system marking requirements of PV systems and their components are crucial for the safety of operators, service personnel, emergency responders, and others. General PV + BESS system labeling requirements, as per NEC 690 Ch. VI and specific requirements from Articles 690 and 705. Include all required and desired labeling language in the design drawings for agency review.

Electrical equipment and components used in PV systems shall have markings that identify the manufacturer, size, type, ratings, hazard warnings, and other specifications. Equipment markings should never be removed and should be able to withstand the environmental conditions in which the equipment is installed (e.g. “UV rated” for outdoor labels, or on an embossed steel placard, designed for outdoor use and fastened with adhesive and rivets). Markings must be visible or easily accessible during and after installation. The Contractor shall be responsible for all field-applied markings as required by local, state, and federal codes.

2.1.18 Lightning Protection

If a dedicated or separate grounding electrode is added for the lightning suppression, as is described in NEC 2017 Section 690.47(B), then the “Auxiliary Grounding Electrodes” must be bonded to the premises’ grounding-electrode system.

2.1.19 Contractor Provided Data Metering and Monitoring

Contractor to provide and host a secure online dashboard that provides, at a minimum the following features:

· On or off

· Communication status

· Reporting

· Not Reporting

· Kilowatt (kW) generation

· Kilowatt-hour (kWh) generation

· Subpages

· System Information

· System size (kW-DC)

· Date brought online

· Tilt

· Azimuth

· Module manufacturer and model

· Inverter manufacturer and model

· Installer contact info

· O&M Provider contact info

· Alarming Functionality

· Text or email

· Inverter(s) offline

· Inverter fault

2.1.20 Linear Module Warranty

Modules used shall have a minimum of a 25-year performance warranty as measured using the linear module warranty methodology.

No module will be warranted to or in actuality generate less than 97% of its STC rated output in year one. No module shall depreciate more than 0.9% for each year of the required minimum 25-year module warranty period.

2.2 Roof Arrays

2.2.1 Annual Roof Inspection and Repairs

All roof-mounted array systems shall allow normal routine annual roof inspections and maintenance to continue unimpeded and shall allow for visual inspections and physical access to the underlying roof system to perform needed roof inspections and repairs. Access to visually inspect and clean all roof drains shall be maintained.

Array shall not trap moisture, dirt and debris leading to algal and or weed growth.

All parts of the array must be assessable for service under reasonable worker reach without needing to stand, sit, or lean on module, racking, or other components.

2.2.2 Walkways and Access to Equipment for O&M

Where array conduit transects existing equipment access walkways, steps, ramps or a bridging assembly meeting ASCE 7-16 and OSHA requirements must be provided. Such systems shall protect conduit, pipe, and/or duct runs passing underfoot from damage and allow for movement of personnel, tools, and replacement parts.

2.2.3 Structural Engineering

2.2.3.1 Roof Structure

This system will be installed on the existing 10-in thick concrete roof slab with #6 rebar every 10 inches each way top and bottom.

The Contractor shall augment ASCE-7.16 with all relevant complimenting guidance in “Wind Design for Solar Arrays” published by Structural Engineering Society of California (SEAOC)- SEAOC Report #PV2-2017 July 2017.

The SEAOC guidance document PV2-2017 July 2017 is designed to work as a companion guidance document to ASCE-7.16. In the design phase, the contractor shall submit drawings and calculations that demonstrate adherence to both of these documents.

2.2.3.2 Fully Anchored

PV support racking shall be full anchored to the roof structure.

2.2.4 Weatherproofing Roof 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. 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 weatherproofing of penetrations shall be compatible with the roof warranty. Describe materials and methods to be undertaken to create watertight seals in the roofing systems for anchor points and conduit.

2.2.5 Inverters for Roof Arrays

Under no circumstances shall roof array inverters that are string or central type be mounted in locations exposed to direct sunlight and weather. Ideally, inverters are to be located in code-compliant ventilated machine rooms or penthouses, or at a minimum placed under open-sided shed roof structures designed to shield them from direct exposure. Module level power electronics (MLPE) mounted underneath solar modules shall be considered adequately protected from direct sun and weathering exposure.

2.3 Battery Energy Storage System Requirements

2.3.1 Project Description

Integrate the PV + BESS with the existing 120/240 V building electrical distribution system. Integrate the PV + BESS with the existing 60 kW Generac emergency generator and automatic transfer switch (ATS). Install a microgrid control system and modify the existing ATS as necessary to provide electricity to the building upon grid failure.

2.3.1.1 The minimum battery storage size acceptable is 24 kW, 100 kWh, or up to 20% larger size (kW and/or kWh).

2.3.1.2 The Contractor shall include BESS submittals in the proposal phase including: a site plan footprint, electrical schematic diagrams, energy storage capacity (kWh), rated power (kWAC), cycle life, annual degradation factor, fire protection/suppression system description as required by code/manufacturer, equipment manufacturer and product name, Battery Management System provider.

2.3.1.3 Power provided shall be compatible with the onsite distribution system

2.3.1.4 The Contractor shall identify an appropriate location for the balance of system (BOS) enclosure, and its related components and environmental control systems that will meet the following criteria:

· Ease of maintenance and monitoring

· Efficient operation

· Low operating losses

· Secured location and hardware

· Compatibility with existing facilities

· Minimum vegetative and landscape impact

2.3.1.5 The Contractor shall complete and submit in a timely manner all documentation required to qualify each system for available rebates and incentives.

2.3.1.6 All Balance of Systems (wiring, component, conduits, and connections) shall be suited for conditions for which they are to be installed.

2.3.2 Performance

2.3.2.1 Contractor shall integrate the BESS + PV to provide grid electricity demand control/ peak shaving to limit demand (kW) to programmed setting. Current Aviary monthly peak demand is 35 kW, and average load is 10.6 kW. Aviary intends to limit grid demand to 25 kW, while still retaining 50% of installed battery energy storage capacity, but other proposed reductions are acceptable.

2.3.2.2 A BMS (Battery Management System) shall be provided to control the charging and discharging of the equipment. The BMS shall include an HMI (Human Machine Interface) and be field programmable. Programming instructions and setpoints shall be shared with FWS staff.

2.3.2.3 Contractor shall provide a turnkey data acquisition and display system that allows the FWS to monitor, diagnose, and track the charging, discharging, and operating data of the BESS. Minimum requirement is the provision of a web-based monitoring and tracking system that includes a historical database and real time data on time of day use and peak loads in minimum 15- minute intervals. The system shall provide BESS hours of operation, air and cell temperature, state of charge and charge/discharge in hours.

2.3.2.4 The BESS inverters shall include 4 each SMA Sunny Island 6048 US and required controls to achieve performance or approved by COTR equivalent equipment.

2.3.2.5 The Contractor shall provide all components to operate the BESS at optimal operating temperatures. Provide any thermal management systems and operating strategies required to maintain the BESS and inverters per manufacturer’s recommendations.

2.3.2.6 Integrate the PV + BESS with the existing 60 kW Generac emergency generator and automatic transfer switch (ATS). The SMA (or other similar product) should be able to provide microgrid control; if not then install a microgrid control system and modify the existing ATS as necessary to provide electricity to the building upon grid failure as follows: Provide electricity from the PV + BESS until the BESS is drained to 20% (20 kWh) remaining.

2.3.2.7 When the BESS is at 20%, start the emergency generator to power the building and recharge the BESS. When the BESS is 80% charged turn off the emergency generator and power building with the PV + BESS until BESS is at 20% (or as recommended by the battery manufacturer), then start the emergency generator again. Repeat this cycle until grid power is returned.

2.3.2.8 Operations and Maintenance for the first year of operation:

· The Contractor shall conduct monthly O&M and monitoring to verify that the battery is performing as intended per the proposed battery storage strategy and manufacturer recommendations and submit an annual report to FWS. The report shall include:

· Monthly demand savings realized by the PV + BESS

· Summary of all outage events and accompanying description

· Contractor shall perform all required maintenance to the BESS and BMS to ensure that the monthly demand reduction is provided.

· Contractor will provide O&M training and supporting manuals to FWS personnel.

· Perform updates to the BMS dispatch strategy if required due to rate tariff or major site load profile changes.

· Ensure that all system firmware is up to date.

2.4 Battery Warranties

2.4.1 Contractor shall provide the following limited and performance warranties.

2.4.1.1 Battery pack performance warranty for 10 years after the date of successful completion of the commissioning. Battery pack shall retain at least 60% of nominal energy for the either 10 years after commissioning or for a minimum energy throughput of 2000 kWh/ kWh nominal energy (whichever comes first), or as specified by the battery manufacturer.

2.4.1.2 Power conversion system warranty of 5 years from successful completion of the commissioning.

2.4.1.3 Full turnkey system warranty for 1 year from successful completion of the commissioning. Contractor shall respond within 3 days if maintenance is required.

2.5 Battery Safety

2.5.1 The BESS shall have a Data Acquisition/monitoring/alarm system. System shall include:

· Visual and audible alarm if potential safety hazard exists.

· Trouble alarm if system can no longer perform within its intended criteria. System shall put the battery into safe operation in case of an anomaly.

· Notification when preventive maintenance is needed.

· Full monitoring of electrical voltage, current, power and system temperature.

2.5.2 The BESS system shall contain protective relays, circuit breakers, or fuses which self-protect the BESS in the case of internal electrical faults.

2.5.3 An outdoor rated disconnect device shall be installed in all systems at the interface between the BESS and the utility metering. This disconnect device shall be a visible break, Lock-Out Tag-Out device, and shall be installed at a convenient location near the service point/point of common coupling and accessible to utility personnel per utility requirements. Refer to applicable codes and PREPA requirements.

2.5.4 All electrical equipment, enclosures, disconnects, and overcurrent devices shall be clearly marked and identified. Markings shall reference the same designations called out in the one line.

2.5.5 Lock-out-Tag-out shall be enforced by the Contractor during construction.

2.5.6 Certifications shall be current for equipment operation on site (crane, forklift, man lift, etc.).

2.5.7 A fire detection/suppression system shall be provided, if required by code or by manufacturer.

3. Acceptance & Testing

3.1 E.3 Inspection

(a) The Contractor shall conform to the requirements of FAR Clause 52.212-4 paragraph (a), Inspection/Acceptance, included by reference in this solicitation and resulting Contract.

(b) The Contracting Officer or the delegated Contracting Officer’s Representative may inspect the Systems at any time during construction or after the Systems have been put in operation, with a minimum 48-hour notice. The Contractor may be ordered to stop work, or shut the systems down, if unsafe conditions or code violations are noted.

(c) A final inspection of all Systems shall be made only when all the materials have been furnished, all the work has been performed, and all the construction provided for by the contract in accordance with the terms has been completed. If, upon examination by the Contracting Officer and/or Government inspection personnel, the project is determined not sufficiently completed to have warranted a final inspection, the contractor may be charged with any additional cost of re-inspection.

(d) The contractor shall give the Contracting Officer ten (10) calendar days advance notice, in writing, of the date the work will be fully completed and ready for final inspection.

(e) The Contractor’s request for final inspection will not be approved unless documentation below, at a minimum, has been provided to the Contracting Officer, in addition to all other contract requirements:

· Final as‑built drawings (record drawings), meeting Section C as-built requirements

· Preventative maintenance work schedules and procedures

· Operation and maintenance manuals (electronic and hardcopy)

· Equipment documentation and spare parts lists

· Certificates of AHJ inspections

· As part of commissioning the contractor shall instruct and train FWS designated personnel on normal system operation and how to shut down the System in the event of an emergency. FWS may reasonably request additional training and contractor will conduct such training at contractor expense. The training session(s) may be recorded by FWS at FWS expense.

· Posted instructions for tasks that site staff may need to perform, such as system shutdown during an emergency

(f) As soon as practicable, following final inspection, the Contracting Officer will inform the contractor, in writing, of any discrepancies and/or omissions noted at the final inspection. The Contracting Officer shall also state the time allowable for replacement of material and performance or re-performance of any unsatisfactory work necessary before written notification of System Acceptance Testing.

(g) Upon written notification that all deficiencies identified during the final inspection have been corrected, the Contracting Officer will schedule a final inspection of the work. If all construction required by the contract is found completed and all contract requisites submitted, the Contracting Officer shall notify the Contractor in writing that the thirty (30) day performance period can begin. During this time period, the CO/COR can negotiate payment with the Contractor.

3.2 E.4 System Acceptance Testing

(a) After the franchise utility provides permission (interim for testing) to operate in parallel with the grid, the Contractor shall complete commissioning and acceptance testing, in accordance with agency safety plans, its own quality-control plan, manufacturer's recommendations, franchise utility interconnection requirements, IEC 62446 Grid Connected Photovoltaic Systems Minimum Requirements for System Documentation, Commissioning Tests and Inspection. The Contractor shall document all performance measurements.

(b) The Contractor shall provide all work required for testing, start-up, and commissioning as required by the following requirements:

1. Commissioning standard IEC 62446 shall be followed.

2. The Contractor shall provide the services of North American Board of Certified Energy Practitioners (NABCEP) or International Test Association (NETA) certified engineers and or technicians to perform start-up and acceptance testing of the specified PV system.

3. An agency manager or representative may request to be present during any or all phases of the start-up and testing activities.

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

5. Complete a system commissioning per this section and equipment manufacturer’s written instructions.

6. Request and coordinate with the Utility Company and Government for acceptance and certification of the PV system and permission to operate.

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

8. Commissioning shall include the Contractor’s Data Acquisition System (DAS)

9. Set and adjust circuit protection devices according to the Short Circuit and Coordination Study.

(c) The Contractor shall notify the Government not less than ten (10) Business Days prior to the anticipated date of System Acceptance Testing. The Government shall have the right, but not the obligation, to be present at and observe the System Acceptance Testing, at the Government’s sole cost. The System Acceptance Testing shall be witnessed by utility if required for interconnection approval and the Contractor shall meet the utility’s test notification requirements.

3.3 Battery System Acceptance Testing

(a) During the start-up and after utility approval, the FWS shall observe and verify the BESS’s performance. Required commissioning and acceptance test services will include:

(b) The BESS shall be commissioned per the EPRI “ESIC Energy Storage Commissioning Guide”. A commissioning report shall be provided to FWS.

(c) Demonstrate the operation of one full charge/discharge cycle of the PV + BESS and generator system as described in section 3.3.8 Performance, by turning off grid power. Report on system performance.

(d) While connected to grid power, start up the BESS until it achieves the minimum performance requirements, including demand savings.

(e) Conduct the performance testing for both on- and off-grid power scenarios over two discrete consecutive twenty-four (24) hour periods.

(f) The acceptable productive power output will be measured in kW (AC) at the building electrical interconnection point and must be consistent with the specifications for the system. Approvals as required by the State Fire Marshal and local electric utility will be a pre-requisite for acceptance and for authorization to energize the system(s). A Certification of Acceptance will be issued upon the approval of the Commissioning and Acceptance Test.

4. Final Acceptance The following requirements must be fulfilled before final acceptance:

1. The System equipment has been commissioned per IEC 62446, and other requirements as specified above.

2. System Acceptance Testing has been completed, with the System having generated electric energy for seven continuous days at energy and power production levels consistent with proposed System’s estimated production with 100% system availability, measured with applicable instruments and meters.

3. The System has been approved for interconnected operation by utility (with signed interconnection agreement).

4. Submission of as-built drawing

5. Training fulfillment documentation.

6. Provide one year of turnkey PV + BESS operation, maintenance, and warranty.

Then the Contractor shall send a Completion Notice and a copy of the System Acceptance Testing to the Contracting Officer so that the Government can complete their final acceptance. Government shall have ten (10) Business Days after receipt of the Completion Notice to review the System Acceptance Testing results and verify that the System installation is complete, safe, aesthetically acceptable, functional, constructed to all code requirements, does not interfere with Government or tenant operations, and otherwise meets all other requirements. The Contracting Officer will notify the Contractor in writing of System Acceptance.

If any of these requirements are not met, then the Government shall provide Contractor with a detailed notice of such failure (a "Rejection Notice") within the ten (10) Business Day period, with details regarding the required remedy (including repeat of either partial or full System Acceptance Testing, if appropriate, at the discretion of the CO or COR), and the time allowed to complete remedy. The Contractor shall promptly remedy at Contractor’s cost the items identified in the Rejection Notice and conduct the required System Acceptance Testing (if required by the Rejection Notice) until the System Acceptance Testing indicates that the System meets the contract requirements. In each such case, the Contractor shall send a new Completion Notice to the Government with a copy of the results of the new System Acceptance Testing as provided above and the foregoing procedures shall be repeated.

Written acceptance shall be final and conclusive except as regards latent defects, fraud, or such gross mistakes as may amount to fraud, or as regards the Government’s right under any warranty or guarantee, subject to the system performance warranty.

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