APPENDIX A – PROJE T SOPE Contents

RFP-2021-18 Solar+Storage Engineering, Procurement and Construction (EPC) – Appendix A – Project Scope 1 of 42

APPENDIX A – PROJECT SCOPE

Contents

A. SCOPE OF WORK ....................................................................................................... 4 1. MEDIUM-VOLTAGE AC ...................................................................................................... 4 2. LOW-VOLTAGE AC.............................................................................................................. 5 3. SOLAR PV SYSTEM ............................................................................................................ 5 3.1 Solar PV Array .............................................................................................................. 5 3.2 Inverters ....................................................................................................................... 6 3.3 Solar PV AC Combiner .................................................................................................. 6 3.4 Solar PV Wiring System & PV Connectors ................................................................... 6 4. E-HOUSE: SITE BUILDING .................................................................................................. 7 5. SCADA & COMMUNICATIONS .......................................................................................... 7 5.1. Telecommunication Scope ........................................................................................... 8 6. BATTERY ENERGY STORAGE SYSTEM (“BESS”) ................................................................. 8 7. SITE SECURITY ................................................................................................................... 9 8. BONDING AND GROUNDING ............................................................................................ 9 9. CIVIL SCOPE ....................................................................................................................... 9 9.1. Brushing and Preliminary Site Preparation ................................................................. 9 9.2. Site Levelling and Grading ......................................................................................... 10 9.3. Drive Paths ................................................................................................................. 10 9.4. Lower Primary Access Road ....................................................................................... 10 9.5. Upper Primary Access Road ...................................................................................... 10 9.6. Secondary Access Road ............................................................................................. 10 9.7. Equipment Yard .......................................................................................................... 10 9.8. Fencing ....................................................................................................................... 10 9.9. Foundation for Ground-Mount Racking System ....................................................... 11 9.10. Earthworks Plans ....................................................................................................... 11 9.11. Fire Hydrants .............................................................................................................. 11 9.12. Additional Design Considerations ............................................................................. 12 10. REQUIRED ENGINEERING STUDIES ............................................................................ 12 10.1. Short-Circuit Study ..................................................................................................... 12 10.2. Load-Flow Study ........................................................................................................ 12 10.3. Grounding Study ........................................................................................................ 13 10.4. Protection Philosophy ............................................................................................... 13 10.5. Ampacity Study .......................................................................................................... 13 10.6. Voltage Drop and Losses Study ................................................................................. 13 11. WORK TO BE SUBMITTED FOR DISTRICT REVIEW ..................................................... 13

B. EQUIPMENT SPECIFICATIONS .................................................................................. 14 1. SECURITY SYSTEM ........................................................................................................... 14 2. NEW 480 VAC SERVICE FOR SOLAR INVERTERS ............................................................. 14 2.1. 480 VAC Solar AC Combiner Panel............................................................................. 14 3. SOLAR PV SYSTEM .......................................................................................................... 15 3.1. Solar PV Modules ....................................................................................................... 15


3.2. Solar PV Connectors ................................................................................................... 15 3.3. String Inverters ........................................................................................................... 16 3.4. Solar Transformer ...................................................................................................... 16 3.5. Ground-Mount Racking System................................................................................. 16 3.6. Solar PV Wiring System ............................................................................................. 17 3.7. Solar PV Dispatch Strategy ........................................................................................ 17 4. BATTERY ENERGY STORAGE SYSTEM SPECIFICATIONS .................................................. 17 4.1. BESS Structure ............................................................................................................ 17 4.2. Heating & Cooling System ......................................................................................... 18 4.3. Battery System ........................................................................................................... 18 4.4. BESS Inverter System ................................................................................................. 19 4.5. BESS Transformer ....................................................................................................... 19 4.6. Station Service Transformer ...................................................................................... 20 4.7. Master Onsite SCADA Equipment Requirements ..................................................... 20 4.8. HMI Specification ....................................................................................................... 21 4.9. Security....................................................................................................................... 22 4.10. Battery Logic Integration ........................................................................................... 22 4.11. Site Control System .................................................................................................... 22 4.12. Monitoring ................................................................................................................. 23 5. E-HOUSE BUILDING SPECIFICATIONS ............................................................................. 24 6. BALANCE OF SOLAR FACILITY ......................................................................................... 24 7. NOISE LEVELS .................................................................................................................. 24 8. AVAILABILITY AND RELIABILITY ...................................................................................... 25 9. DOCUMENTATION ........................................................................................................... 25

C. CONSTRUCTION, INSTALLATION & TESTING REQUIREMENTS ................................. 26 1. PERMITTING .................................................................................................................... 26 2. GENERAL CONSTRUCTION NOTES .................................................................................. 26 3. ADDITIONAL REQUIREMENTS ........................................................................................ 27

D. SYSTEM TESTING REQUIREMENTS .......................................................................... 28 1. TRANSFORMERS ............................................................................................................. 28 2. GROUNDING ................................................................................................................... 28 3. SWITCHGEAR AND MEDIUM-VOLTAGE DISCONNECT .................................................... 28 4. PRIMARY METER ............................................................................................................. 28 5. AC CABLES (>1000 V) ...................................................................................................... 29 6. SCADA & HMI .................................................................................................................. 29 7. BESS: FACTORY TESTING ................................................................................................. 29 8. BESS: FACTORY TESTING OF BATTERY CELLS AND MODULES ........................................ 29 9. BESS: SITE ACCEPTANCE TESTING ................................................................................... 30 9.1. Test-Area Safety Checks ............................................................................................. 30 9.2. Initial Inspection ........................................................................................................ 30 9.3. Test Procedure: System Functionality ....................................................................... 31 9.4. BESS: SAFETY .............................................................................................................. 32 10. SOLAR PV: SITE PERFORMANCE ACCEPTANCE TEST ................................................. 32

E. SPARE PARTS ............................................................................................................ 33

F. PREVENTATIVE MAINTENANCE ............................................................................... 33


G. SYSTEM ORIENTATION & TRAINING ........................................................................ 34 1. SYSTEM ORIENTATION .................................................................................................... 34 2. SCADA OPERATION TRAINING ........................................................................................ 34 3. MEDIUM-VOLTAGE EQUIPMENT OPERATION TRAINING .............................................. 34 4. BESS SYSTEM OPERATOR TRAINING ............................................................................... 34 5. SITE TRAINING AND PROJECT HANDOVER MATERIALS ................................................. 35

H. WARRANTY .............................................................................................................. 35

ANNEX A - EXAMPLE LAYOUT, SINGLE LINE DIAGRAM & SCADA NETWORK DIAGRAM ...... 37

ANNEX B – GEOTECHNICAL ENGINEERING ASSESSMENT REPORT ...................................... 38

ANNEX C – METEOROLOGICAL STATION INFORMATION ...................................................... 39

ANNEX D – SUMMERLAND SITE LAYOUT KMZ FILE .............................................................. 40

ANNEX E – SUMMERLAND SOLAR ARRAY STAGE 2 ENVIRONMENTAL PRELIMINARY SITE INVESTIGATION REPORT ....................................................................................................... 41

ANNEX F – CODES AND STANDARDS .................................................................................... 42


A. SCOPE OF WORK

The Project scope includes the design, procurement, supply, installation, and commissioning of a new solar photovoltaic (“PV”) system and battery energy storage system (“BESS”) for the District at 13500 Prairie Valley Road/12591 Morrow Avenue/Denike Street (the “Project Site”). Annex A to this Appendix provides a geographical layout of the Project Site, with a typical layout and single line diagram (“SLD”) of the electrical system. This design configuration will allow for independent operation of the BESS and solar PV systems.

The PV and BESS system will interconnect to the Summerland 8 kV distribution facility, with the SCADA, telecommunication, and protection scope described below.

1. MEDIUM-VOLTAGE AC

In the future, the District plans to upgrade the existing 8.32/4.8 kV distribution network to 24.9/14.4 kV (herein referred to as 8kV and 25kV respectively). All equipment should be sized to 25 kV to handle the future increase in voltage. The transformers shall be specified as dual-voltage 8/25 kV. See the SLD in Annex A to this Appendix.

The scope of work for the design, supply, and installation of the new 8 kV service — sized and rated to 25 kV, beginning at the southwest distribution interconnection point — shall include the following:

• One 25 kV interconnection dead-end pole for the District’s 8 kV feeder interconnection. The pole will require guy-wire reinforcement. The Contractor shall collaborate with the District to determine the best pole design and routing.

• One 25 kV-rated protection recloser with SCADA controllable relay for overall solar system protection for interconnection to Summerland Feeder 449.

• One 25 kV-rated primary meter for high-accuracy bi-directional power metering using 8 kV potential transformers (“PT”) for accurate measurement. PTs will be swapped out for 25 kV rating during a future voltage conversion project.

• One overhead-to-underground fused riser pole for connection. The Contractor shall size fuses to coordinate with in-line breakers and reclosers to ensure adequate protection.

• Underground installation of 25 kV-rated cable in PVC conduit to the pad-mounted switch cubicle. Routing of cable must avoid solar panel racking foundations.

• Installation and termination of a station service transformer, solar transformer and BESS transformer. The transformers shall be sized appropriately for the preliminary design (refer to RFP Appendix C, Section 1).

• One 25 kV-rated SCADA-enabled protective device such as four-way pad-mounted switch cubicle with vacuum fault interrupters (VFI) for protection. Protective devices must bi-directionally protect faults from both battery and solar systems as well as protect from distribution facility faults. o Protection switch cubicle will need to be installed and commissioned using compatible settings

by coordinating to the District’s existing in-line protective devices and substation breaker. The Contractor shall submit settings for review by the District for appropriate coordination.

• Termination of 25 kV-rated cable to the high-voltage connection of the BESS transformer, solar transformer and station service transformer.

• An isolation or grounding transformer as deemed necessary in the preliminary design (refer to RFP Appendix C, Section 1).


• Refer to Section B of this Appendix for a complete list of equipment specifications.

• High voltage distribution design and materials to meet Summerland Electric Utility Distribution standards which will be made available at design phase.

2. LOW-VOLTAGE AC

The scope of work for low-voltage AC (LVAC) includes design, supply, and installation of the following

components:

• A 480Vac service between the solar transformer and solar AC combiner panel.

• A LVAC connection between the BESS inverter system and BESS transformer. o The service voltage shall be compatible with inverter’s AC voltage and the LVAC connection shall

be suitable for BESS-rated power flow at an ambient temperature of 50°C. o If a prefabricated throat connection is proposed, it shall have a CSA or cUL safety certificate or be

an original part of an overall system that has one of these safety certificates.

• A LVAC connection from the station service transformer to the BESS and the SCADA building. o The service voltage shall be compatible with BESS and SCADA building station load voltages and

suitable for supplying full station service calculated by the Contractor at an ambient temperature of 50°C.

• Refer to Section B for a complete list of equipment specifications.

3. SOLAR PV SYSTEM

The scope of work for the ground-mounted solar PV system comprises design, procurement, supply, and

installation for a system with a minimum 1 MWDC nameplate; a sample layout and SLD of the system are

available in Annex A to this Appendix.

The Contractor shall provide a solar PV system equivalent to the example design provided in Annex A to

this Appendix or a system with higher energy yield according to the PVsyst simulation Proponents are to

submit as a part of their Proposals. Refer to RFP Appendix C Section 6 for modelling assumptions.

3.1 Solar PV Array

• The solar PV system shall have minimum 12-foot clearance from the fence from all locations of the array.

• The solar array and Project fence shall stay within “Maximum Available Land” area shown on the typical layout in Annex A to this Appendix. The boundaries presented for the layout are based on the known environmental constraints of the Project Site and cannot be changed without an update to the Environmentally Sensitive Development Permit.

• The Project layout shall consider environmental and wildlife restrictions such as wetlands, salamander and snake habitats and trees used by wildlife. These wildlife boundaries have been preliminarily demarcated in the Summerland Site Layout kmz file included in Annex D to this Appendix; the District’s QEP will oversee the finalization of the layout as part of the Environmentally Sensitive Development Permit process. The Contractor is expected to work closely with the District and the QEP through the detailed site design process.

• The Contractor shall install gates at the Project location per the layout drawing. The locations of the secondary egress gates on the perimeter fencing are approximate and should be finalized during detailed site design in consultation with the District.


• The Contractor shall provide final site surveyed boundaries of the layout to the District prior to construction; these boundaries are subject to approval of the District and the District’s QEP.

• Foundation and mounting structure for the District’s meteorological station.

• Refer to Section B Solar PV System for specifications.

3.2 Inverters

• The Contractor shall procure, supply, and install PV string inverters with a minimum total nameplate that results in an inverter clipping loss of less than 1% according to the loss diagram in the PVsyst simulation report submitted during the detail design phase.

• The Contractor may install inverters outdoors. In this case, an awning cover constructed of non-flammable materials shall be installed above inverters to protect them from vandalism (e.g., objects thrown at them from outside the fence).

• Inverters shall be installed in accordance with the manufacturer’s installation and operation manual.

• The Contractor shall design, supply, and install a structure to support the inverters. The design shall be submitted for review by the District prior to construction.

Refer to Section B, String Inverters for the specifications.

3.3 Solar PV AC Combiner

The Contractor shall procure, supply, and install the following components:

• One (1) solar PV AC combiner;

• One (1) AC main breaker;

• One (1) AC breaker per inverter; and

• One (1) complete foundation system for the combiner.

This equipment will be located outdoors. See the layout in Annex A to this Appendix for the approximate location.

Refer to Section B, 480 VAC Solar AC Combiner Panel for the specifications.

3.4 Solar PV Wiring System & PV Connectors

The Contractor shall design, procure, supply, and install the following components:

• DC wiring and solar PV connectors from solar PV modules to inverters.

• AC wiring from inverters to the solar PV AC combiner panel.

• Bonding conductors to bond the grounding conductor and exposed conductive surfaces of the array and supply-circuit equipment per CEC 24th edition requirements.

• Any underground cable shall be installed in a conduit. All underground installations shall follow CEC Part 1, Section 12, or CSA C22.3-No.7.

• The Contractor shall provide voltage drop and ohmic loss calculations for the solar farm in the design package for the District to review.

Refer to Section B, Solar PV Connectors, and Section B.4.6, Solar PV Wiring System, for the specifications.


4. E-HOUSE: SITE BUILDING

The Contractor shall procure, fabricate, install, and commission a SCADA control building for SCADA control panel and telecommunications equipment.

• The Contractor shall design, procure, and install a reliable and cost-effective foundation for the pre-fabricated building. All foundations must adhere to all local British Columbia (BC) Building Codes.

• This prefabricated building must have: o Building HVAC rated for ambient temperatures from -25°C to +50°C; o Metering and protection instrumentation; o Communication devices, including fibre-optic patch panels; o Cellular device for back-up communication; o SCADA equipment including human operator interface (“HMI”) for control of plant (refer to

Sections B.4.7 and B.4.8); o Circuit breakers; o Switches; o External Emergency generator connection point; o AC distribution breaker panels for communications equipment and indoor AC receptacles; and o Lights and receptacles.

Refer to Section B.5 E-House building specifications.

5. SCADA & COMMUNICATIONS

During the design and implementation of the Project, the Contractor will work closely with the District’s contractor responsible for the District SCADA and telecommunications upgrade project. The scope of this separate project is to develop a new, robust SCADA and telecommunication system spanning the entire municipality. The upgrades include the following:

• New fibre-optic network connecting several key infrastructure services including but not limited to:

o Prairie Valley Substation; o Trout Creek Substation; o Water Treatment Plant; o Landfill Administration building; o Pole yard; o Works & Infrastructure building; and o Municipal Hall.

• Implementing a central control centre terminal located at the Works & Infrastructure Building;

• SCADA main server and network head-end design for primary SCADA system at Works and Infrastructure building and a secondary backup system at the Solar and Battery site to be completed by the District’s contractor; and

• SCADA equipment deployment for control and monitoring of key loads and operations in the District.


The Contractor shall design a local SCADA system for control and real-time monitoring of all on-site devices; refer to the network diagram in Annex A to this Appendix for the devices that will be included in the local SCADA system. The SCADA system shall have the following functions:

• Real-time acquisition and display of data, status, alarms and trends;

• Display of the solar facility system data suitable for operation and fault finding, including diagnostics and self-reporting functions;

• Operation of the solar facility and BESS equipment;

• Logic functions for control, protection and annunciation of the equipment and systems;

• Display and historical storage of measured values and events; and

• Remote login functionality for remote measurement and control.

The local SCADA system shall be built into the pre-fabricated E-House. It shall integrate with the master SCADA and telecom system being developed by the District’s contractor, which will require transparency and sharing of information from all parties during all design phases.

5.1. Telecommunication Scope

The Contractor shall procure, supply, and install the following necessary telecommunications equipment:

• Fibre-optic patch panels as required for integration into the District’s SCADA and telecom system with a minimum of 8 spare connections in patch panel for future telecom upgrades; and

• Fibre-optic interconnection through underground trenches and overhead under-strung cabling.

SCADA equipment must be connected to all required onsite devices for communication and control. Onsite network equipment will be specified by the District’s contractor(s).

6. BATTERY ENERGY STORAGE SYSTEM (“BESS”)

For this District initiative, the battery will ultimately be used for peak shaving to reduce the District substation demand from the transmission wholesaler and, consequently, reduce the electricity bill by discharging during peak and charging during off-peak hours.

The scope of work for the BESS includes designing, procuring, shipping, supplying, installing, and testing the BESS and its associated inverter system, foundations, electrical connection(s) of the BESS to the inverter system, inverter system to BESS transformer and station service. The BESS shall comply with specifications listed in Section B, Battery Energy Storage System Specifications.

The Contractor shall provide factory acceptance testing (“FAT”) for the BESS inverter(s) as well as BESS modules (if applicable). The Contractor shall provide an ‘On-site Testing and Commissioning Plan’ for the District to review and approve, and a final ‘Site Acceptance Test’ (“SAT”) report for the overall system as well as individual components including but not limited to the PV modules, PV strings, PV inverters, PV AC combiner panel, transformers, site control system, battery management system (BMS), fire suppression, heating and cooling, etc.

The Contractor shall ensure the District has access to the commissioning team and Project Site during commissioning to observe. The Contractor shall not limit the District’s involvement during this time.


The BESS shall also include a site controller system that performs the charging and discharging algorithms for the BESS. This site control system will be integrated with the District’s SCADA system and interface with the onsite SCADA system built into the E-House. The 8 kV feeder information for the BESS control system will be provided through a fibre interconnection to the District’s Prairie Valley Substation provided by the District’s contractor. The Contractor will work closely with the District’s contractor to tie the fibre into the E-House and battery system.

7. SITE SECURITY

In addition to site security for construction (refer to RFP Appendix C, Section 10.4), the Contractor shall work with the District throughout the design phase to develop post-energization security camera requirements, including placement of conduit, wiring, etc. The cameras will be purchased and installed by the District. The design and configuration of the infrastructure for these cameras must be able to monitor the BESS and inverter site area as well as the main gates into the Project Site. A ‘Handover Plan’ detailing site security measures shall be developed during Project execution and delivered to the District.

Yard lighting is to be included, at a minimum, around the Equipment Yard and main vehicle entrance. District of Summerland standard davit streetlights to be used. Specifications will be provided during the design phase.

8. BONDING AND GROUNDING

The Contractor shall undertake a complete grounding study of the Project Site. The 25 kV-rated ground grid must be designed to limit the touch-and-step potential of on-site personnel and meet the safety criteria of IEEE 80 and CSA C22.1. The low-voltage grounding and bonding must adhere to the CEC Part 1 Section 10 Code. All metallic equipment must be grounded safely and effectively. While a site-wide bare-copper grounding network may not be required, individual equipment grounding must be sufficient. The equipment to be grounded includes but is not limited to:

• Overhead 8 kV power poles including the riser and primary meter poles;

• Switch cubicle ground loop with ground rods;

• E-House ground loop and battery container ground loop with ground rods;

• BESS transformer, solar transformer, and station service transformer ground loops;

• Racking shall be grounded and solar modules bonded through effective racking; and

• Fencing where applicable (e.g., overhead fence crossing at interconnection point).

Soil resistivity tests have been completed in the Geotechnical Engineering Assessment Report (refer to Appendix A, Annex B).

9. CIVIL SCOPE

9.1. Brushing and Preliminary Site Preparation

The Contractor shall complete brushing and site clearing, including snow and the preliminary site preparation, prior to site levelling and grading. These activities must be completed in consultation with the District and the District’s QEP. Where possible, and in consultation with the District, felled trees should be utilized for ecological purposes.


9.2. Site Levelling and Grading

The Contractor shall complete the detailed topographical survey prior to grading design. The final Project Site levelling, grading design, and construction shall be as per the final layout plan and include PV array areas, battery energy storage area, drive paths, and the drainage system. The site grading design and construction shall adhere to the recommendations in the Geotechnical Engineering Assessment Report provided in Annex B to this Appendix.

9.3. Drive Paths

The Contractor shall design and construct drive paths, which will typically be a 3.5 m wide gravel road. The gravel road shall meet the District and BC requirements for light to medium-weight vehicles.

9.4. Lower Primary Access Road

The Contractor shall upgrade the existing lower primary access road to meet the District’s local road standard (50mm asphalt, 75mm crush base, 300mm subbase; if the subbase is suitable, this could be modified based on the Contractor’s recommendation in consultation with the District). The existing access road may need to be widened and the parking area with turn-around constructed approximately as shown on the layout provided in Annex A to this Appendix. Refer also to Annex D to this Appendix. One gate as shown on the layout shall be designed and installed.

9.5. Upper Primary Access Road

The Contractor shall design the upper main access road to the District’s gravel road standard. The alignment will match the existing road with some minor modification. The existing asphalt along this road shall be removed prior to construction of gravel road.

9.6. Secondary Access Road

The Contractor shall design and construct the secondary access road as shown on the layout plan. The proposed road alignment shall be confirmed by the Contractor based on the site condition. This road is intended for use as an access for maintenance and emergency vehicles. The road will typically be 4.5m-wide gravel road, designed and constructed to meet District standards and specifications applicable to the type of road.

9.7. Equipment Yard

The Contractor shall design and complete site grading in and around the equipment yard and provide the gravel surface. The Contractor shall design and construct a direct and easy access route (gravel) to the equipment yard from the main site gate. Due to the steep slope, significant cut may be expected at this location.

9.8. Fencing

The Contractor shall design and install perimeter fence with three (3) sliding vehicle gates (20 ft. wide each) and two (2) personnel gates (4 ft. wide each). The approximate locations of the gates are shown on the layout included in Annex A to this Appendix. Refer also to Annex D to this Appendix. The fence


shall be galvanized chain-link and mounted on galvanized steel posts. All post foundations shall be designed and installed per the geotechnical reports (see Annex B to this Appendix). Fence height may be seven (7) feet plus one (1) foot barbed wire on top. The fence must have at least twelve (12) feet of clearance from the PV system.

9.9. Foundation for Ground-Mount Racking System

The Contractor shall design, procure, and install a reliable and cost-effective foundation system compatible with the solar PV modules to be installed. All foundations shall be designed in accordance with the Geotechnical Engineering Assessment Report as provided in Annex B to this Appendix.

The rack structure and foundation system shall be designed in compliance with the latest applicable National Building Code of Canada and BC Building Code; using site-specific climatic data (1/50 years hourly wind pressure and snow load) and seismic data; and in compliance with ASTM steel qualities and shall be galvanized to ASTM A123/A123M-02. Other racking and foundation system requirements are as follows:

• All welding shall be in accordance with CSA Standard W59-03;

• The Contractor shall provide the District with drawings for rack structures and foundations, which must be authenticated by a Professional Engineer registered in BC; and

• The racking shall include integrated bonding through module clamps per UL 2703.

9.10. Earthworks Plans

• The Contractor shall submit to the District the ‘Erosion and Sediment Control Plan’, ‘Vegetation Management Plan’, and ’Invasive Species Management Plan” at both pre- construction and post-construction phases.

• The Contractor shall explore and comply with District requirements for a ‘Stormwater Management and Drainage Plan’, and design and construct as required.

• Erosion and sediment control work shall be completed in accordance with BC’s Erosion and Sediment Control Best Management Practice and District guidelines.

• Any larger-scale erosion and sediment control work shall be pre-approved by the District.

9.11. Fire Hydrants

To provide some fire suppression capacity to the solar site area, the Contractor shall design and construct a fire hydrant and water main to the location as shown in Annex A to this Appendix. It is anticipated that the connection to the municipal water system will come from the area of Denike Street and Morrow Avenue approximately two hundred and sixty (260) metres through Ottley Avenue (unconstructed road right of way).

Water modelling has been completed to determine the tie in location and main sizing. The modelling report will be provided to the Contractor and suggests installing a 200mm main to the 150mm main at the intersection of Denike Street and Morrow Avenue through Ottley Avenue (unconstructed road right of way). The water main and hydrant design must be completed by a qualified professional and approved by the District to produce issued for construction drawings.

The Contractor is responsible for completing all required permitting, such as Interior Heath permitting and District permitting for work in the right of way. Construction inspection, testing, and


completion of record drawings will also be the responsibility of the Contractor. All water main design must follow District of Summerland Subdivision and Development Servicing bylaw standards for design and construction of water systems, MMCD, and AWWA for testing procedures.

9.12. Additional Design Considerations

The District is interested in exploring the possibilities of the Contractor creating a pollinator habitat understory, re-naturalizing the area, creating educational/interpretive areas, and/or enhancing recreational access surrounding the site. The Contract may be requested to incorporate these or other similar concepts during detailed design.

The Project end of life should be considered during planning and material selection. Concepts such as deconstruction, recyclability, and future land uses should be taken into account during detailed design.

10. REQUIRED ENGINEERING STUDIES

The Contractor shall complete the following engineering studies, which the District will review and approve.

10.1. Short-Circuit Study

The short-circuit study is performed to validate the sizing of the equipment on the system. The maximum short-circuit current is determined at each location on the system from the sum of each source’s contribution. The maximum current calculated is then compared to the equipment short-circuit withstand capacity for conformance. The short-circuit levels will also be used to appropriately program the protective devices on site.

10.2. Load-Flow Study

The load-flow study is conducted to ensure that the Project meets CSA C235-83 voltage regulation and power factor requirements at the point of common coupling (PCC).

Table 1: Summerland Electric Utility Required Voltage and Power Factor Levels at PCC

Maximum 8 kV Bus Voltage at PCC 1.04 p.u.

Minimum 8 kV Bus Voltage at PCC 1.00 p.u.

Maximum Power Factor at PCC 1.05 PF

Minimum Power Factor at PCC 0.95 PF

The load-flow study will demonstrate that the Project can meet the specific interconnection requirements from the District. The load flow study is to be completed using CYMDist, with the software files provided to the District for further use.


10.3. Grounding Study

A grounding grid shall be designed for the site. All metallic structures and other non-energized metallic equipment shall be bonded to either one complete ground grid or adequately grounded individually as per the grounding study. Grounding study software files are to be provided to the District for further use.

10.4. Protection Philosophy

The protection system for the Project shall be designed to prevent personnel injury, minimize damage to system components and limit the extent and duration of service interruption whenever there is equipment failure, human error or adverse natural events affecting any portion of the system. The study shall be reviewed and approved by Summerland Electric Utility for implementation. The protection philosophy describes the system features, as well as those of its major components (e.g., fuses, circuit breakers, protection relays and implemented protection functions etc.).

The District will require all settings files in an editable format from the Contractor for use in the 25 kV upgrade project. Note: as this upgrade will be completed in the future, the settings change project is excluded from this Project scope and will be the subject of a separate procurement.

10.5. Ampacity Study

An ampacity study is performed to determine the power cable sizes that will be able to carry the expected maximum steady-state currents. The DC string and low- and medium-voltage AC cables shall be studied.

10.6. Voltage Drop and Losses Study

The voltage-drop and losses analysis is used to determine the expected electrical losses (AC and DC) of the system at full active power and ensure that the system complies with the electrical code for the maximum allowable voltage drop on each of the cable runs.

11. WORK TO BE SUBMITTED FOR DISTRICT REVIEW

The Contractor shall submit the following to the District for review during the engineering and design process and seek District approval prior to construction:

• Datasheets, installation manuals and shop drawings, as applicable for the following equipment: o Solar racking system; o Solar PV panels; o Solar PV inverters; o Solar AC combiner panel and its components; o BESS and its components; o BESS inverters; o All foundation systems; o Transformers; o Site controller; o Distribution switch cubicle; o Primary meter;


o SCADA and telecommunications equipment; o E-House building; o Fence and gates; o Security system components and location recommendations; and o DC, AC and communication cables.

• All layout and engineering drawings, including but not limited to: o Site layout; o Electrical SLDs; o Telecom and SCADA drawings; o Trench details; o Solar racking and foundation design drawings; o Foundation layout with coordinates of foundation locations; o Foundation design drawings for buildings and any self-standing equipment; o Drainage system; o Access roads, parking areas, turn arounds, and drive paths within PV array areas; o Perimeter fence and gates; o Protection relay settings; o SCADA equipment configuration files; and o BESS controller configuration files.

B. EQUIPMENT SPECIFICATIONS

The following Sections provide the equipment specifications for the new 480 VAC service, main distribution panel and associated concrete base, solar PV system, and battery energy storage system. It also includes specifications for the control building, high-voltage equipment, and associated SCADA equipment. All equipment shall be new and CSA certified as applicable. For greater certainty refurbished equipment will not be accepted.

1. SECURITY SYSTEM

Permanent site security cameras are to be installed by a District contractor; however, the Contractor is expected to consult with District throughout the design phase to ensure the site, solar PV system, and battery storage system are designed and constructed to allow for a future security system (e.g., conduit placement, appropriately-sited mounting poles, consideration of sightlines, etc.).

2. NEW 480 VAC SERVICE FOR SOLAR INVERTERS

A minimum 1,200 Amp service shall be designed, based on diagram D11 and Table D11A of CEC 2018, between the solar PV transformer and the main break of the solar AC combiner.

2.1. 480 VAC Solar AC Combiner Panel

• The main distribution panel’s bus shall be rated at minimum 1,200 Amp. The Contractor shall select the bus rating based on the maximum inverter AC output currents as continuous current rating and any other design considerations such as ambient temperature of -25 to +50°C;


• All breakers shall be a minimum of 480 VAC rated. The Contractor shall calculate the fault currents and select breakers with breaking capacities exceeding the maximum possible fault current at the 480 VAC system;

• The main breaker shall be 3P back-feed capable and sized appropriately to protect the system and must not cause any nuisance tripping under normal operating condition, including continuous operation of inverters at maximum AC output current;

• Breakers feeding inverters shall be 3P back-feed capable and sized appropriately to protect the inverter circuit and must not cause any nuisance tripping under normal operating condition, including continuous operation of the inverter at maximum AC output current;

• The AC combiner panel shall include a minimum of one (1) spare inverter breaker;

• Circuits connecting the inverters to breakers shall be designed to exceed the branch breaker’s rated current assuming 75°C lug temperature rating;

• All equipment shall be a minimum of NEMA 3 if applicable; and

• The solar AC combiner panel and its components shall be CSA certified.

3. SOLAR PV SYSTEM

3.1. Solar PV Modules

• Photovoltaic modules shall be factory assembled, consisting of 144 photovoltaic half-cut cells, frame, junction box, cables for series connection and bypass diodes for shade tolerance; they shall be rated for a minimum of 1500 VDC and listed as complying with UL 61730;

• Monocrystalline or polycrystalline silicon bifacial photovoltaic modules shall comply with IEC 61215;

• Modules’ power at the maximum power point (MPP) shall be equal to or greater than 445 WDC at standard test condition (STC: irradiance 1000 W/m2, module temperature 25°C);

• Module efficiency shall be equal to or greater than 20.5% at STC;

• The modules can be taken from a maximum pf two power class bins with 5W difference. All modules connecting to the same inverter MPPT shall come from the same power bin;

• Module weight shall be equal to or less than 27.5 kg (61 lbs.);

• Refer to Section H of this Appendix for warranty and linear performance guarantee requirements for the modules;

• Module degradation shall not be more than 2% in the first year. Thereafter, power output decrease shall not exceed 0.45% per year. Minimal nominal rated power after 30 years must be at least 84.95%;

• Modules must have a weatherproof factory-installed junction box with factory-installed terminals and bypass diodes, and a protection class ≥ IP68;

• Modules shall have IEC 61215, IEC 61730 and UL 61730 certifications;

• Modules shall be dual-glass with operational temperature of -40 to +85°C;

• Modules must have factory-installed cables;

• The module manufacturer shall be ranked “A” or higher in PV ModuleTech Bankability Ratings for Q4 2020; and

• The module manufacturer shall have the history of selling a minimum of 50 MW, in Canada, of modules from the same module class proposed by the Contractor.

3.2. Solar PV Connectors

• Solar PV connectors shall be rated for ambient temperature of -40 to +85°C;


• Minimum protection class ≥ IP68; and

• Minimum 1500 V 30A rated.

3.3. String Inverters

• String inverters shall have a DC input voltage operating range of 200 to 1000 VDC;

• String inverters shall have a rated output AC voltage equal to 480 VAC;

• String inverters’ ambient operating temperature shall be in the range of -30 to +60°C (derating allowed at temperatures above 45°C);

• String inverters shall have a minimum of NEMA 4X (IP66) protection level;

• String inverters shall have certificates and comply with UL 1741, UL1998, IEEE 1547-2003, C22. 2 No. 107.1-01 and UL1699B;

• String inverters shall each be equipped with an arc fault circuit interrupter (AFCI) compliant with UL1699B;

• String inverters shall be equipped with integral DC and AC switches, DC reverse polarity protection, leakage current protection and overvoltage protection Type II for DC and AC sides;

• Each string inverter shall be equipped with a minimum of two 6 MPP trackers and 2 inputs per MPPT;

• Inverter CEC efficiency shall be equal to or greater than 98%;

• Inverter total harmonic distortion smaller than 3%;

• Inverters shall be capable of RS485 and Ethernet communication;

• String inverters shall have Modbus and SunSpec communication capabilities;

• String inverters shall have the following grid support capabilities: o LVRT, HVRT, active and reactive power control and power ramp rate control;

• The inverter shall be provided with an online remote monitoring system; and

• The District may decide to operate the PV and BESS system in a microgrid system in future. String inverters shall be capable of operating in a microgrid environment and communicating with and following the commands of a future microgrid controller.

3.4. Solar Transformer

• The step-up transformer for the PV output shall have the following configurations: Configuration: Yg-Yg, 4- or 5-legged core;

• Rated Power: 1 MVA;

• Primary Voltage: 8/25 kV;

• Secondary Voltage: 480 V; and

• Impedance: <6%

Details must be included with Proposal submissions as described in RFP Appendix C. Section 1.

3.5. Ground-Mount Racking System

The PV module racking system shall:

• Be ground-mounted racking with galvanized steel construction suitable for bifacial module installation;

• Provide a minimum clearance of 3 feet from the ground to the lower edge of the panels;

• Provide a minimum of 9.8 m pitch;

• Allow modules to be installed with 30° tilt angle and 180° azimuth in 2P orientation; and


• Be equipped with integrated module bonding that is UL2703 certified.

The Contractor shall provide mechanical support for cables.

3.6. Solar PV Wiring System

All DC, AC and bonding conductors shall be sized to comply with the Canadian Electrical Code (CEC), 24th edition.

3.7. Solar PV Dispatch Strategy

The BESS and PV systems shall be AC coupled. The PV system shall operate independent to BESS operation status and inject maximum PV power available to the grid at unity power factor (PF=1) when the grid is available and in normal condition (the grid frequency and voltages within the PV inverter’s operating range).

4. BATTERY ENERGY STORAGE SYSTEM SPECIFICATIONS

The BESS system shall include the following principal components:

• BESS shall be turnkey and lithium-ion chemistry based;

• BESS catalogue capacity shall be equal to or greater than 4.5 MWh, and the usable energy equal to or greater than 4 MWh. The BESS shall maintain 4 MWh usable energy capacity for the next 20 years assuming the peak-shaving application;

• The BESS shall be able to discharge from 100% to 0% of its usable energy at minimum 2 MWAC;

• The BESS shall be black-start capable;

• The District may decide to operate the PV and BESS in a microgrid system in future. The BESS shall be capable of operating in a microgrid environment, forming the grid and communicating with and following the commands of a future microgrid controller;

• The BESS cell manufacturer shall have the history of manufacturing a minimum 40 MWh of the cells proposed by the Contractor;

• A new grounding system shall be supplied and installed that is dedicated to the BESS structure and equipment as per Section 10 of the Canadian Electrical Code, 24th edition; and

• The BESS, including all equipment, shall be designed, rated, manufactured, and tested in accordance with the latest applicable CSA standards. If any equipment is built or tested outside Canada, the more stringent Canadian or International Standards shall apply.

4.1. BESS Structure

• The BESS shall be housed in a new insulated structure or structures;

• The structure(s) shall have exterior light and access doors to allow for access of the equipment, such as battery modules, in the event of equipment replacement or maintenance;

• The structure(s) shall contain the main components of the BESS system, such as the battery modules; battery racks; BMS; internal power distribution including circuit breakers, disconnects, contactors and other protection equipment; and a thermal protection system including air ventilation, access openings, insulation, fire suppression system, and heaters;

• The structure(s) shall be considered unmanned. If a walk-in enclosure is proposed, there shall be an option to interlock the door(s) with E-Stop;


• The battery enclosure(s) shall have provisions to protect the battery strings from environmental agents, including but not limited to dirt, dust, moisture, humidity, rain, etc. The solution uses the battery for the storage medium; therefore, proper fire protection measures must be in place;

• The BESS structure(s) shall have, at a minimum, PPE and safety signage on the exterior; and

• The Contractor is responsible to secure BC Building certification and any required District building permits on the completed structure(s).

4.2. Heating & Cooling System

• The heating and cooling system shall be capable of keeping dust and other environmental agents out of the BESS structure;

• The Contractor shall provide the structure’s heating and/or cooling monitoring system. The Contractor is required to indicate the anticipated electrical consumption for one year using the Pricing Form provided in RFP Appendix D, Annex B (O&M tab);

• The system shall be rated for operation based on ambient temperature of -25 to +50°C and keep the BESS structure at the requirements outlined by the battery cell manufacturer for warranty and operation of charging and discharging;

• The primary source of heating and cooling shall be electricity. A backup solution in case of loss of the grid (electricity) or primary heating or cooling system failure is required. The alternative may include provision for external genset connection and a redundant heating and/or cooling system and exhaust fans; and

• Where possible and/or practical, energy and carbon reducing specifications should be included.

4.3. Battery System

• Shall be installed inside the BESS structure(s);

• The battery system will consist of the battery modules installed in racks, along with proper cooling such as HVAC, and fire-suppression system for safety;

• Fire systems shall be self-contained and not require heating or cooling;

• Fire systems shall be connected to the District’s alarm system;

• Upon detecting smoke or a fire, the system shall alarm and automatically shut down, the power conversion system shall open AC and DC circuits and BESS structure’s ventilation shall be turned off;

• A battery management system (BMS) shall be present to monitor various operating characteristics of the battery system, for example energy in and energy out;

• The BMS shall prevent the BESS from operating outside the safe operation parameters;

• The system shall be able to provide the battery’s state of health (SOH), state of charge (SOC), cell voltages and currents, alarms, individual battery cell temperature, charge balancing, etc. to the master SCADA system;

• The BMS will be an integral part of the BESS and must be from the manufacturer of the battery cells; and

• The BESS shall be equipped with Emergency Stop (E-Stop). The E-Stop shall be capable of local and remote (via SCADA system) operation.


4.4. BESS Inverter System

• The BESS inverter rated AC output voltage shall be within the 480 to 690 VAC range;

• The system should be able to detect islanding or loss of phase, and not continue to operate if an islanding condition occurs when the inverter is in grid-parallel mode;

• The inverter system shall be black-start capable;

• The inverter system shall be grid-forming capable;

• Rated for operation based on ambient temperature of -25 to +50°C. No power derating allowed at or below 40°C ambient temperature;

• The inverter system shall have CEC efficiency equal or greater than 98%;

• Harmonic distortion levels shall meet UL1741/IEEE1547;

• Enclosure a protection rating of NEMA3R or higher;

• The inverter DC operating voltage range shall match or exceed the BESS DC voltage range;

• The inverter shall be certified for UL 1741 and C22.2 No. 107.1-16 for safety;

• The inverter shall be certified for IEEE 1547.1-2005 and CSA C22.2 for utility interconnection;

• The inverter system shall have the following protection features: o Contactors and/or motorized switches on AC and DC side; o Fuse protection for both DC and AC side; o Surge protection on DC and AC side; o AC/DC overvoltage; o Instantaneous and time delayed AC overcurrent; o Instantaneous and time delayed overtemperature; and o Ground-fault detection;

• The inverter system shall be capable of communicating with BESS BMS;

• The Contractor is responsible for compatibility of the BESS components including but not limited to BESS, BMS, inverter system and power transformer;

• The inverter control system shall have Modbus TC/IP interface with no more than 3 ms command latency and be integrated into the master SCADA system;

• The inverter’s minimum response time to accomplish full power step shall not be longer than 2 ms;

• The inverter shall have the following grid support functions: o Active/Reactive Control o Volt - Var Control o Hz - Watt Control o Volt - Watt Control o L - HVRT Control o Inertia Control o Ramp Rate Control

4.5. BESS Transformer

• Configuration: Compatible with District 8 kV system requirements and BESS inverter requirement;

• Rated Power: Equal or greater than the BESS AC output;

• Primary Voltage: three-winding or tap-change 25 kV/8 kV;

• Secondary Voltage: Compatible with BESS inverter output;

• Impedance: <7%;


• Foundations shall be proposed by the Contractor as part of the design process and be concrete pad-mount or throat-mount on foundations and grillage; and

• Transformer to comply with CSA C227.4 and CSA C88-M90, whichever applies, for all efficiency requirements.

4.6. Station Service Transformer

Padmounted station service transformer to be sized and priced accordingly to meet the power requirements determined by the Proponent.

• Configuration: Padmounted Single Phase Transformer;

• Rated Power: To be determined by Proponent;

• Primary Voltage: Dual voltage 8 kV / 25 kV;

• Secondary Voltage: 120/240 V;

• Impedance: <6%;

• Foundations shall be proposed by the Contractor as part of the design process and be concrete pad-mount; and

• Transformer to comply with CSA C227.4 for all efficiency requirements.

4.7. Master Onsite SCADA Equipment Requirements

• The SCADA cabinet in the E-House will house SCADA and communications equipment complete with: o Cable management; o Power distribution; o Patch panels (copper and fibre); and o Grounding details;

• Firewall/router/VPN appliance for the SCADA cabinet interface;

• Main Network Switch for SCADA cabinet complete with IP address list and VLAN assignments;

• Cellular internet access point for the E-House including firewall for client access only;

• WAN/internet connection;

• Security requirements to be determined and proposed by the Contractor as part of the design process;

• UPS/battery backup for SCADA cabinet;

• GPS clock, antenna, antenna cable, antenna cable surge arrestor;

• Main RTU (SEL-3555 RTAC) complete with: o Serial port adapter; o Local and web HMI (can be separate HMI device and/or software);

• Input and Output (I/O) collection device;

• Rackmount keyboard drawer and mouse;

• Historian integration software for District SCADA control centre use from RTAC; and

• Integration of the District’s supplied meteorological station. o See Annex C to this Appendix for information on the District-supplied meteorological station.


4.8. HMI Specification

• HMI graphics shall provide, at a minimum, the following screens with the requirements as defined below. o Single line diagram screen(s); o Alarm summary screen; o Device alarms screens; o Sequence of events (“SOE”) screen; and o Help file.

Single Line Diagram Screen(s)

• The SLD screen shall display a simplified electrical SLD of the Solar Facility, including all solar PV inverters, BESS inverters and medium-voltage equipment with key operational metrics. Equipment shall be appropriately colour-coded to indicate the device state. Clicking on a device shall access the device screen for that device as applicable.

• The colours used shall consist of red to indicate energized components, green to indicate de-energized components and blinking white to indicate that communications with the device have been lost. The energized state of components may need to be inferred from voltage readings and the open and/or closed state of relays and switches.

• The following devices shall be represented on the screen and shall display the specified live values: o Switch cubicle MVI relays;

Local and/or remote status; An indicator that shows if there are any active alarms associated with the relay; The following analog values: L-L and L-N voltages, current, real power, reactive power,

power factor, frequency; o Solar PV generation; o BESS power flow;

• The following additional information shall be displayed on the screen: o HMI version number; o Indication if active alarms exist; o Meteorological summary information: global horizontal irradiance (“GHI”), plane of array

(“POA”) irradiance, wind speed, wind direction, ambient temperature; o BESS voltage, state of charge, first and second maximum and minimum cell temperatures; o Solar PV summary:

Generation: daily, weekly, monthly, yearly, total; Number of inverters online; and Current real power.

Alarm Summary Screen

• One annunciator tile will be displayed for each device from which alarms can originate;

• The annunciator tile background will be red if the device has active alarms or green if the device has no active alarms; and

• Clicking on the annunciator tile will bring up the device alarms screen.


Device Alarms Screen

• A device alarms screen shall be provided for each device from which alarms can originate;

• One acknowledgeable annunciator tile will be displayed for each of the alarms that the device may raise;

• Tiles for active alarms will have a red background. Unacknowledged active alarms will flash; and

• The background colour of the tile will change to green when the alarm clears.

Sequence of Events (“SOE”) Screen

• All changes of state on the binary inputs will be displayed in the HMI SOE viewer; and

• Points designated as alarms in the master point list will be displayed as alarms in the SOE viewer. The master point list will also specify the alarm priority.

Help File

• A help file shall be provided that explains the operation for the HMI and provides details on all the features and functionality; and

• The help file shall be created in Microsoft Word and the MS Word document shall be provided to the District.

4.9. Security

• At minimum, three (3) accounts shall be configured for the HMI and RTAC control: o View only; o Onsite operator;

Only the operator account will be able to issue control commands; The HMI shall revert to view-only mode after ten (10) minutes; and

o Remote operation from District control centre.

4.10. Battery Logic Integration

• The Contractor shall work with the District and the District’s contractor for the SCADA Upgrade project to collect distribution feeder data information from both the primary meter and the Prairie Valley substation feeder breaker to develop charge and discharge logic for the BESS; and

• The battery charge and discharge logic shall be based on peak shaving of the distribution feeder load. Refer to Annex A to this Appendix for a high-level SCADA network and communication diagram.

4.11. Site Control System

The site controller shall perform all necessary controls and communication to the electrical system. The following is a list of specifications and proposed conditions for the BESS’s operation. It is not the complete list of features and operational states: the Contractor shall identify and design any necessary and/or additional controls to maximize BESS performance and ensure safety and operation.

• BESS operation shall be independent to the status of the PV system;


• If the BESS’s SOC is full, stop charging the BESS; if BESS is at minimum acceptable SOC, stop discharging the BESS;

• The site controller will be centralized and shall have the capability of being logged into remotely via the master SCADA system;

• The controller shall charge and discharge the BESS such that it imposes a ceiling on peak load for every 15-minute interval. The operating logic sets a target peak at 95% for of the load in the first 15 minutes of every month. If the load is higher, the BESS discharges to bring the load under this target. If the load is lower, the BESS charges. As the load increases during the day, the BESS may fail to maintain the target due to its limited duration. Consequently, the operating logic then revises the target for the rest of the month to the “missed peak,” as the District will be charged for this peak even if it maintains a lower peak during the rest of the month. The District shall have access to the logic and be able to adjust the target peak setpoint;

• The site controller shall allow the operator to override the automatic dispatch and send manual dispatch commands to the BESS;

• The control system shall include a local HMI, providing an interface to the system monitor and operator controls. It shall function both locally and remotely;

• This HMI shall be used to access data, troubleshoot at individual string level and monitor the set points and performance on site; and

• The site controller and BESS shall be equipped with minimum eight-hour UPS to provide status and alarm monitoring during power outages.

4.12. Monitoring

A monitoring and/or alarm system shall be provided to identify trips, alarms, faults, and any unusual events for both the PV system and the BESS. A data logger shall also be provided to capture the network conditions before, during, and after an event. The system should be capable of recording a minimum of two (2) years of information. Steady-state data can be fifteen (15)-minute interval information. Event data should be fast enough for event analysis. This data should be acquirable remotely via SCADA system.

• This monitoring shall be accessible locally through the site control system and be accessible remotely by the District’s SCADA system;

• The monitoring system should be able to show the following information: o Current status of the batteries such as SOC, state of health (SOH), charge/discharge/float, cell

temperatures, cell voltages, individual rack current and contactor status, etc. o Real-time power flow for the BESS and PV systems as well as the station service. o Trips, alarms, faults and unusual events. Alarms shall include but not be limited to the

following: Fire alarm; BESS high and low temperature alarm and temperature imbalance; BESS high and low temperature trip; Cell over-voltage and/or under-voltage; Cell voltage imbalance; Rack over charge; Rack over-current; and Door(s) alarm, if applicable, for external access into the BESS structure;


o Performance reports with customizable timeframes (15 minutes, hours, days, weeks, months, and years);

o PV system energy yield (daily, monthly, annual, and total); o BESS energy profile (daily, monthly, annual, and total); and o BESS structure temperature.

5. E-HOUSE BUILDING SPECIFICATIONS

• Small pre-engineered and constructed building for shipment and installation on site, must accommodate secondary SCADA rack with HMI for backup SCADA control center (to be installed by a District contractor);

• Metal roofing and wall cladding to be designed to CSA Standard S136;

• Standing seam roofing shall be fabricated in fluted, ribbed profiles;

• Roof and wall cladding assemblies shall be of “dry-joint” types, which do not rely on wet seal or caulking systems for weather tightness;

• All connection hardware shall be galvanized or protected against corrosion by a similar alternative;

• Building shall be designed for ambient temperatures of -25°C to +50°C;

• Single-door entry with door and frame fabricated from sheet steel conforming to CSA S136;

• The door shall be locked and equipped with a door-frame sensor for the SCADA system to trigger an intruder alarm;

• Building to have HVAC as primary heating and cooling source with redundant electric heaters and fans for ventilation as required;

• The Contractor shall design, procure, and install reliable and cost-effective foundations for the building. All foundations shall be designed according to the Geotechnical Engineering Assessment Report in Annex B to this Appendix.

• Where possible and practical, energy and carbon reducing specifications should be included.

6. BALANCE OF SOLAR FACILITY

The Contractor shall also be responsible for the following:

• Trenching and conduit for cables;

• Ground grid installation;

• Final grading;

• Rain drainage system and stormwater plan;

• Auxiliary power network;

• Construction site power;

• LV power and auxiliary cables and conductors;

• Communication and control cables;

• AC interconnection cables and conduits;

• DC power interconnect cables; and

• Fire alarm initiating system, installation and verification by a registered engineer.

7. NOISE LEVELS

The inverters and transformers shall not create ambient noise above eighty (80) dB when operating at steady-state.


8. AVAILABILITY AND RELIABILITY

• The BESS configuration shall provide a high level of reliability. Failure of an individual inverter module and/or lineup shall not result in the outage of the whole system;

• Should a failure happen, the redundancy incorporated in the BESS must ensure that the system can operate at a de-rated output;

• Should an individual inverter module and/or lineup fail, it shall automatically disconnect itself from the circuit and the remaining inverter modules and/or lineups shall continue to operate without interruption;

• Contractor shall as part of the design process state the expected average number and duration of scheduled outages per year.

• Contractor shall state the maintenance interval suitable for its equipment and shall describe any condition monitoring offered.

• Contractor shall outline a maintenance plan as per Section F – Preventative Maintenance; the District reserves the right to enter into negotiations with the Contractor for provision of some or all of the preventative maintenance work.

9. DOCUMENTATION

In addition to the Project reporting requirements identified, the Contractor shall also provide the following documentation in electronic and hardcopy format:

• Solar Facility specification;

• Solar Facility electrical connection drawings and/or schematics;

• Single line diagrams;

• Communication interface;

• Concept of control and/or applications;

• Dimensional drawings showing equipment dimensions, weights and conduit entrance locations;

• Manufacturer-provided installation manuals;

• Commissioning test reports for all Solar, BESS, and high-voltage equipment

• Warranty certificates and/or documents;

• Preventative Maintenance Plan and/or Program (see Section F - Preventative Maintenance)

• Operation and Maintenance Manual, including a functional description of the system, safety instructions, step-by-step operating procedures and maintenance guidelines and tests.


C. CONSTRUCTION, INSTALLATION & TESTING REQUIREMENTS

1. PERMITTING

The Contractor will be responsible for all permitting, including but not limited to transportation, development, building etc., with the appropriate authorities having jurisdiction, except for:

• Environmentally Sensitive Development Permit; and

• Wildfire Hazard Area Development Permit.

Refer also to RFP Section 2.2.

2. GENERAL CONSTRUCTION NOTES

The Contractor is responsible for:

• All access, including temporary and permanent access, material staging areas and laydown areas;

• The installation of all on-site Project signage (e.g., funder recognition, informational). The design and supply of the signage is to be handled directly by the District; however, input by the Contractor into signage materials, sizing, and other specifications may be requested;

• Overall site safety, including the installation of safety signage, as required;

• Completing a Hazard Assessment that meets all means health, safety, security and environment (HSSE) laws, and providing a copy of the completed Hazard Assessment to the District for approval prior to commencing work on-site;

• Complying with all environmental requirements per the Environmentally Sensitive Development Permit being completed by the District’s QEP , as well as other District environmental requirements and legislation and regulations applicable to the Project Site; o Note: the District’s QEP is developing a Construction Environmental Management Plan that will

outline additional Project-specific environmental management requirements and will provide specific mitigation measures to follow during construction phases of the Project.

• Ensuring appropriate fire watch protocols are in place during construction as per the BC Wildfire Act.

• Complying with all requirements per the Wildfire Hazard Area Development Permit being completed by the District’s Registered Professional Forester;

• Providing shop drawings for all components in advance of construction;

• Furnishing all materials, equipment and labour required to perform the work;

• Accommodation and transportation of labour resources performing work on-site;

• Commissioning activities at site; see Section D for testing and commissioning requirements, and additional details;

• Co-creating testing and commissioning plans with ATCO’s quality assurance representative for use in commissioning and milestone completion verifications;

• Properly packing and shipping all equipment and materials to Project Site. Site material storage must be approved by the District in advance, and the Contractor may need to arrange off-site storage;

• Providing details on how they intend to route, install and protect the cables prior to any cable installation;

• Providing site power during construction. Where possible and/or practical, energy and carbon reducing options should be utilized.

• Spraying galvanized metal cut on-site (e.g., uni-strut) with galvanizing spray to minimize future rusting;


• Ensuring that all outdoor-rated equipment and junction boxes are mounted per manufacturer specifications;

• Ensuring that all exterior cable ties are UV-rated;

• Ensuring that construction work complies with the District’s applicable bylaws and regulations (e.g. noise levels, hours of work, etc.);

• Ensuring that electrical boxes and inverters are cleaned and construction debris removed throughout the Project to minimize environmental impacts;

• Ensuring that all AC and DC wires are torqued to manufacturer specifications;

• Conducting insulation testing on all AC and DC wires to 2 GΩ and an insulation certification document shall be provided to the District;

• Providing as-built drawings, datasheets, equipment manuals and information to meet requirements of Safety Code Officers; and

• Ensuring that all packaging material and debris during construction and throughout the entire Project is cleaned up and disposed of. Tipping fees are now applicable to all waste brought into the Summerland Sanitary Landfill, including waste from District-related projects.

Waste should be source-separated and suitably prepared prior to being hauled to the Summerland Sanitary Landfill. An allowance for the Summerland Sanitary Landfill fees (“Landfill Fees”) has been included on the Pricing Form (refer to RFP Appendix D, Annex B). The Contractor shall not charge the District with any markup on the Landfill Fees. For more details on fees, please refer to the District of Summerland Solid Waste By-Law 98-001, Schedule L (as amended).

3. ADDITIONAL REQUIREMENTS

The Contractor shall also ensure that the following reporting requirements are met:

• Submit drawing packages and designs for 60% and 90% reviews;

• Submit daily construction reports that include but are not limited to notes on work progress, personnel on site, issues, deficiencies and photos; provide regular updates to the District (minimum of one (1) time per week);

• Produce a document that outlines how the site redevelopment incorporated the findings and recommendations of the Stage 2 PSI and Geotechnical reports provided in Annex B and Annex E to this Appendix; and

• Work collaboratively with the District to provide Project information, including language and photographs, that can be used for marketing materials, press releases, public information events, and Council presentations.

The Contractor must attend the following meetings, at a minimum:

• Project kick-off meeting. May be either remote or in-person;

• Detailed design planning meetings. Plan for a minimum of two (2) meetings where design considerations such as a pollinator understory, microgrid, public investment opportunity, recreational access points, feeder reconfigurations, and other optional design considerations can be explored. May be either remote or in-person; o Optional scope: Public engagement events to review these design considerations. Quantity is to

be determined;


• Council briefing meetings to provide Project progress updates. Plan for a minimum of three (3) briefings over the Project life. May be either remote or in-person.

• Daily on-site meetings during construction.

D. SYSTEM TESTING REQUIREMENTS

The Contractor is responsible to conduct all testing and commissioning of the Solar Facility; however, the Owner’s Engineer, ATCO, will have a quality assurance representative on site throughout the Project who will be involved in the co-creation of the testing and commissioning plans and will be responsible to verify that the Solar Facility is commissioned and completed in accordance with following testing requirements.

1. TRANSFORMERS

All transformers (BESS step-up, solar step-up, and station service transformers) have all been tested and documented per applicable standards.

2. GROUNDING

All grounding connectors, bonding connectors, clips, and straps have been tested. Testing will be completed to the required resistance condition defined in the grounding study performed by the Contractor.

3. SWITCHGEAR AND MEDIUM-VOLTAGE DISCONNECT

Test and document all switchgear and medium-voltage disconnect equipment and systems, which shall

include the following activities:

• Conduct insulation resistance tests for one minute on each bus section, phase to phase and phase to ground;

• Inspect bolted electrical connections using a low-resistance ohmmeter;

• Verify the operation of switch-cubicle space heaters;

• Verify the operation of all relay trip settings and successful operation of each medium-voltage disconnect;

• Apply voltage or current to all analog inputs and verify correct registration of the relay meter functions;

• Check the functional operation of each element used in the protection scheme, including: o Undervoltage and/or overvoltage; o Instantaneous overcurrent; o Time overcurrent; o Directional overcurrent; o Over-frequency and/or under-frequency; and o Control verification of all active digital inputs.

4. PRIMARY METER

Test and document all metering equipment and systems, which shall include the following:


• Ensure correct measurement and indication by applying voltage or current to each analog input;

• Confirm that measurements are consistent with loads present after initial system energization; and

• Ensure communication with the SCADA system and recording of metering trend data.

5. AC CABLES (>1000 V)

Test and document all switchgear and medium-voltage disconnect equipment and systems, which shall include the following:

• Conducting insulation resistance tests for one minute on each bus section, phase to phase and phase to ground; and

• Hi-Pot low-frequency high-voltage testing of AC cables.

6. SCADA & HMI

• A site acceptance test (“SAT”) shall be performed after final commissioning with the District and ATCO to demonstrate to the District (or to personnel designated by the District) the full functionality of the HMI using point-to-point testing as required. All features of the HMI shall be successfully demonstrated including, but not limited to, monitoring, control, alarming and sequence-of-events collection and display;

• The District (or personnel designated by the District) shall witness the SAT. All test results shall be recorded by the HMI Supplier. At the end of the tests, the HMI Supplier will provide a copy of the test results to the District;

• Communication and monitoring shall be established from all required devices, including accurate measurement of distribution feeder power; and

• Analog and digital points list shall be commissioned, ensuring that all measurement and controls are functioning properly.

7. BESS: FACTORY TESTING

A factory acceptance test (“FAT”) is an essential part of the BESS deployment, and the complete solution shall meet the requirements set for the system’s predetermined operation.

• A FAT testing plan must be submitted to the District for approval prior to the commencement of the FAT;

• The FAT shall be designed to demonstrate the compliance of the BESS with the District’s requirements as outlined in the RFP;

• A detailed FAT report shall be provided to the District for review and approval before the equipment is shipped;

• The District may request ATCO to witness the FAT on behalf of the District; and

• For all supplier equipment, type test or FAT shall be presented according to applicable standards.

8. BESS: FACTORY TESTING OF BATTERY CELLS AND MODULES

Per the battery manufacturer test procedures, logs, and tests are to be provided to the District following acceptance tests.


9. BESS: SITE ACCEPTANCE TESTING

Site acceptance testing (“SAT”) is an essential part of the BESS deployment, and the complete solution shall meet the requirements set for the system’s predetermined operation. The Contractor shall ensure that qualified personnel perform the following testing procedures during the SAT:

9.1. Test-Area Safety Checks

Proper test-area safety checks shall be conducted before proceeding with other steps involved in the SAT, including:

• Ensure that the BESS AC and DC breakers are opened and racked out if possible;

• Ensure that the main power feeders are opened and locked out;

• Lock out, tag out, and try out power sources to the BESS unit being tested before verifying power cabling connections;

• Check that the equipment being tested and structural support is solidly grounded to the ground grid or building ground; and

• Check that cable shields (e.g., signal) are properly earthed (if applicable).

9.2. Initial Inspection

Perform a visual and mechanical inspection of all the equipment to identify damaged components, materials, etc. if any. Upon completion of the initial inspection, a completed checklist shall be submitted to the District prior to moving to the next phase of testing.

• Check the bolted bus bar connections, if any, for the torque of bolted connections and that clearance distances are per applicable standards;

• Check cable connections for workmanship;

• Component and/or device configuration checks shall also be performed as outlined below: o Check that the rating and type of all installed auxiliary circuit breakers and fuses are as per

the circuit diagram(s) and bill of material; and o Check that the configurable protective devices, which do not require auxiliary power to be

applied, are set per the circuit diagram(s).

Other inspections and/or tests before placing the system in service shall include:

• Shipping and installation damage;

• Mechanical integrity;

• Grounding verification;

• Installation per manufacturer’s drawings;

• Auxiliary power system test and energization;

• HVAC system tests;

• Polarity check;

• Control wiring connection;

• Power wiring connection;

• Safety shutdown functionality;

• Programmable component/device loading and configuration;

• Auxiliary equipment functional testing;


• Emergency stops-circuit verifications;

• I/O verifications; and

• Communications validation including battery communications checks, battery voltage protection coordination and SCADA communications check.

9.3. Test Procedure: System Functionality

Before performing the testing requirements within this Section, the initial battery commissioning shall be completed. The verifications to be performed before operation testing in different operating modes include:

• Auxiliary power is available and tested;

• HVAC, fire detection and suppression system, and all other safety measures are available and functioning as expected;

• All protection devices are in place, configured and functioning as expected;

• BESS structure temperature is stable and within acceptable range;

• Test the normal startup of the BESS with all AC and DC power circuits open at inverters;

• Run a BMS report to ensure all cells are at 100% SOH, and cell temperatures and other parameters are within acceptable range determined by the manufacturer;

• Allow cells to complete balancing and send the initial BMS report to the District for review;

• Once the initial checklist is complete for both BESS and the inverter(s), and once the District permits, conduct a full battery charge and discharge testing. The batteries shall be charged to the charge and/or discharge limits.

• Supply all of the above documentation to the District to review.

The SAT is necessary to ensure that the system will be fully functional and operate as expected. Therefore, operation in all the different modes in which the system will be operated shall be verified.

Various control modes shall be tested, including PQ mode, voltage mode, current mode, and islanding mode (voltage and frequency.

Once the system successfully passed all the above tests, the peak-shaving function shall be implemented and tested.

Note: All testing shall be coordinated with the District to determine the permissible level of power dispatch at the site and the set points shall be determined accordingly. Also, all data from the testing procedure shall be logged.

In addition to the tests listed above, customer-requested tests shall be performed, including:

• Demonstration of maximum charge and discharge rate;

• Charge and discharge ramp rate;

• SOC stability; and

• Battery self-discharge.

At the end of the testing, the system shall be rebooted and the Contractor shall verify that all the devices have loaded up successfully. All SAT reports and data shall be produced and provided to the


District. In addition to other data, the reports shall include the corrective actions recorded during the SAT.

9.4. BESS: SAFETY

The Contractor shall provide documentation and identify all safety hazards and risks associated with BESS operation and maintenance as part of the Project post-completion handover documentation. The Contractor shall identify the minimum requirements for personal protective equipment (“PPE”) and technical training required for maintenance personnel – see Section G for further training details.

10. SOLAR PV: SITE PERFORMANCE ACCEPTANCE TEST

The site performance acceptance test (“PAT”) must show that the solar PV is capable of generating energy as expected, and shall be measured by the primary meter to the SCADA system. The site PAT shall be performed after all commissioning and start-up activities have been successfully completed and all deficiencies potentially affecting energy generation performance have been fully resolved. This also includes:

• Successful interconnection and synchronization to the District’s utility grid;

• Visual inspection of the modules to make sure that they are in a reasonable state of cleanliness and free from construction residues such as mud and dust;

• Open-circuit voltage (VOC), short-circuit current (ISC) and polarity test for each string and results sent to the District for review;

• Commissioning and calibrating metering equipment;

• Ensuring that the monitoring system is fully operational, and the District has access to all operational data via SCADA; and

• Performing thermal imaging for the PV modules after energization and confirming that there are no anomalies and/or hot spots.

The PAT period shall consist of a minimum of ten (10) days in the aggregate, where all the following conditions are met for each day:

• The global horizontal irradiance is an average of 400 W/m2 for each hour for at least three hours per day;

• Total daily radiation on the horizontal plane is at least 2 kWh/m2/day; and

• No error or warnings appear on the inverters.

The PAT period will be extended by one day for any day on which all the conditions above are not met.

After the ten (10) day aggregate data period, the Contractor shall demonstrate the generation capabilities of the solar equipment to the District for acceptance.


E. SPARE PARTS

The Contractor shall:

• Evaluate and provide the required spare parts for the first two (2) years of operation;

• Recommend a spare list for the following years, including part numbers, potential Suppliers, and storage requirements;

• Determine configurable spare parts and include the configurations and settings in the handover package; and

• Determine and provide any special tools required to operate the system or required to install spare parts.

F. PREVENTATIVE MAINTENANCE

A preventative maintenance plan and/or program shall be outlined by the Contractor in hardcopy as well as electronic media at the end of the Project. This includes all regular test(s); the type of tests including any Supplier identified tolerances. All unique tests or inspections required as part of the preventative maintenance plan and/or program will be shown to the District at the time of commissioning. The Contractor is responsible to provide all equipment for these tests and inspections at the time of commissioning.

Maintenance shall include but not be limited to the following, subject to actual site conditions and installed product platform:

• Examine the equipment for cleanliness and overall condition;

• Inspect for abnormal wear and identify environmental impacts;

• Visually inspect all power connections for any signs of overheating or arcing;

• Inspect devices for damage due to moisture or condensation;

• Inspect control and power wiring for discoloration and damage due to heating;

• Hand spot check terminals and connections for loose or damaged wires;

• Inspect for any signs of foreign entry of contamination, chemicals or debris;

• Inspect for proper ventilation openings, fans and speed references from control system;

• Inspect and replace air filters as needed (customer provided materials);

• Inspect insulators for damage and factory torque marks on copper bus bars;

• Verify the state of the converter system controller and system communications;

• Inspect each fan assembly;

• Inspect UPS and test with simulated power interruption (if applicable to design);

• Measure and calibrate control voltage levels at each power supply (as required);

• Inspect monitoring devices and simulate external safety components;

• Verify protections and relay response and associated alarms;

• Visually inspect step-up transformers and auxiliary power feeds;

• Complete a general inspection of AC and DC circuit breakers and operating mechanisms;

• Review and verify system performance and key established operationally targets;

• Download for review PV and BESS service logs, alarm screens and captured system data;

• Provided the customer with a final trip report with any identified system deficiencies; and

• Offer a detailed plan for any future service recommendations, including options for service providers.


G. SYSTEM ORIENTATION & TRAINING

It is expected that orientation and training will be provided in both on site and off site.

All off-site orientation and training shall be provided in a local facility. The Contractor is responsible to arrange and for all costs associated with the facility and to provide both printed and electronic formats of all training materials. Refer to RFP Appendix C Submission Requirements, Section 10.1.

1. SYSTEM ORIENTATION

The Contractor shall conduct at least one (1) orientation review session to engage all the key department heads responsible for site activities and construction. Orientation will outline site-specific commissioning schedules, site hazards, and safety topics that are pertinent to ensuring an effective transition from construction into the reliable operation of the system. These orientation sessions shall be suitable for managers, supervisors, and professional and technical personnel and each session will be limited to fifteen (15) attendees.

The Contractor shall also conduct at least one (1) orientation session with the District’s Fire Department and review safety topics for solar PV and BESS and review action plans in case of fire.

The orientation sessions shall be scheduled before commencing site energization and before commencing Project Commissioning.

2. SCADA OPERATION TRAINING

The Contractor shall conduct at least one (1) SCADA operation session with all key department heads responsible for operation activities. The on-site session shall include:

• SCADA system operation; and

• Protection logic for the protection relays.

3. MEDIUM-VOLTAGE EQUIPMENT OPERATION TRAINING

The Contractor shall provide training to the District’s utility workers on the operation of all medium-voltage 8 kV equipment including:

• Safe and proper operation of all load-breaking circuit interrupters in the switch cubicle using both local and remote operations;

• Safe and proper operation of fuses and the replacement of fuses in the event of a fault; and

• Meter operation.

4. BESS SYSTEM OPERATOR TRAINING

The Contractor shall provide the necessary training to demonstrate proper operation of the installed system and all associated related equipment. This training shall be conducted directly after the successful completion of Commissioning and SAT activities. Each training shall include hands-on operating experience delivered by qualified personnel. The training will include:

• System critical components;


• Switching procedures and site safety;

• Emergency response protocols;

• Review of alarms, annunciation and appropriate actions;

• System modes and setpoints;

• Remote monitoring; and

• Predictive tools operation.

5. SITE TRAINING AND PROJECT HANDOVER MATERIALS

The Contractor shall demonstrate the system and hands-on functionality using the fully Commissioned site equipment. The Contractor will use only existing Project-specific documentation, drawings, and platform manuals as instructional materials and full teaching aids, including:

• Safety procedures and identified hazards related to system and operators;

• Specific tools and test equipment required for system verifications;

• System overview with block-level operation and functional modes;

• Operation overview to include required routine maintenance items;

• Demonstrate functionality and serviceability through platform-specific manuals;

• Fault diagnostics basic and capturing service logs; and

• Unique tests or inspections related to the preventative maintenance plan and/or program.

H. WARRANTY

In addition to the minimum manufacturer warranties, the District requires the following warranties on all equipment:

• Provide a minimum of a twelve (12)-month warranty and support after final commissioning to fine-tune, change and/or modify the battery control system and dispatch strategy as the system goes through its first year of operational cycles to ensure the BESS appropriately provides peak shaving function meeting the District’s operational requirements;

• Provide additional warranties or extended warranty periods where required to qualify for rebate and incentive programs;

• Provide a minimum of a twelve (12) year manufacturer warranty for PV modules covering repair or replacement due to defective materials or workmanship; o Provide a manufacturer warranty for PV modules guaranteeing a minimum of 84.95% of rated

power output for thirty (30) years;

• Provide a minimum of a ten (10) year manufacturer warranty for the racking system covering repair or replacement due to defective materials or workmanship;

• Provide a minimum of a ten (10) year manufacturer warranty for PV inverters covering repair or replacement due to defective materials or workmanship;

• Provide a minimum of a two (2) year manufacturer warranty for the BESS covering repair or replacement due to defective materials or workmanship;

• Provide a minimum of an eighteen (18) month manufacturer warranty for solar AC combiner panel components covering repair or replacement due to defective materials or workmanship;

• The BESS manufacturer shall warrant the system against defects in workmanship and material for twelve (12) months after start-up of the system, or eighteen (18) months after the date of shipment, whichever occurs first;


• Provide a minimum of a twelve (12) month manufacturer warranty for 8 kV switch gear/switch cubicle covering repair or replacement due to defective materials or workmanship;

• Provide a minimum of a twelve (12) month manufacturer warranty for 8 kV primary metering covering repair or replacement due to defective materials or workmanship;

• Provide a minimum of a twelve (12) month manufacturer warranty for all transformers covering repair or replacement due to defective materials or workmanship;

• The E-House building manufacturer shall provide a warranty that the building system will perform as intended for a minimum of five (5) years from the date of final acceptance. The warranty shall include coverage against blistering, peeling, cracking, flacking, chalking and fading;

• The Contractor shall provide a two (2) year workmanship warranty for the E-House building, which must specifically include the coverage for the weather tightness of the building enclosure;

• The Contractor shall provide a minimum of twelve (12) months’ warranty following Project completion for balance of Solar Facility covering repair or replacement due to defective materials or workmanship.

• The Contractor is responsible for any warranty claim in the first year after project completion.

Refer also to RFP Appendix C – Submission Requirements, Annex C.


ANNEX A - EXAMPLE LAYOUT, SINGLE LINE DIAGRAM & SCADA NETWORK DIAGRAM

(ATTACHED)


ANNEX B – GEOTECHNICAL ENGINEERING ASSESSMENT REPORT

(ATTACHED)


ANNEX C – METEOROLOGICAL STATION INFORMATION

(ATTACHED)


ANNEX D – SUMMERLAND SITE LAYOUT KMZ FILE

(ATTACHED)


ANNEX E – SUMMERLAND SOLAR ARRAY STAGE 2 ENVIRONMENTAL PRELIMINARY SITE INVESTIGATION REPORT

(ATTACHED)


ANNEX F – CODES AND STANDARDS

(ATTACHED)

APPENDIX A – PROJE T SOPE Contents

Documents

Transcript of APPENDIX A – PROJE T SOPE Contents