work must be performed and supervised by skilled workers trained and experienced in the installation of the Systems in accordance with equipment manufacturers' installation requirements. Installer shall effectively manage the schedule and coordinate construction activities around Site Host's maintenance activities and other construction projects where applicable.
Commissioning
Installer shall conduct all activities required for proper testing and commissioning of the Systems and any related installations/systems. Commissioning will include testing of all systems to ensure proper operations per the design standards and testing parameters. Installer is required to verify that: (i) each of the Systems functions as expected within acceptable parameters and as designed at a nameplate capacity; (ii) meets expected production output; and (iii) meets expected performance requirements described within the Agreement. Installer shall manage all necessary final inspections with all Governmental Authorities having jurisdiction over the Project, the Distribution Utility, Site Host representatives, and any other required inspectors. Installer shall also be responsible for completing the Commissioning Schedule included as Attachment D and submitting it to Site Host for review and approval. Installer will notify Site Host no less than five (5) days prior to the commencement of any testing and/or inspections and Site Host and/or its representative will have the right to observe all such tests and/or inspections. As part of the commissioning activities, Installer must confirm that no negative impacts are experienced by existing facilities that connect or interface with the new installations and systems. Installer shall be solely responsible for resolving all issues that arise.
Distribution Utility Interconnection
Installer is responsible for coordinating and implementing all requirements related to the interconnection of the Systems with the Distribution Utility, which shall include Distribution Utility provided and installed facilities and Site facilities, at Installer's sole cost and expense. Installer will coordinate with the Distribution Utility and Site Host to meet all milestones for the Project required by any Interconnection Agreement. Installer is responsible for compliance with all milestones, including payment milestones to the Distribution Utility for design and installation services provided by the Distribution Utility. Installer shall be responsible for obtaining written Permission to Operate for the Systems from the Distribution Utility and activate the system to begin operating in compliance with the Agreement. In addition, Installer shall be responsible for all on -going terms, obligations and costs described in the Interconnection Agreement, and any other necessary permit signoffs from any Governmental Authorities having jurisdiction over the Project, to operate the Systems in parallel with the Distribution Utility grid.
Installer shall also be responsible for coordinating the desired rates and tariff changes with the Distribution Utility for each of the Systems. Desired rates and tariffs for each Distribution Utility meter are defined in the Site Assessment Table. Installer will be responsible for ensuring that each of the Systems meets the requirements for inclusion in the desired rates and tariffs and will promptly inform Site Host if there is any discrepancy between such requirements and the specifications for each of the System set forth in the Agreement. Rate and tariff changes shall occur as soon as possible following Permission to Operate. Installer shall be responsible for ensuring that the rate and tariff change has taken place for each Distribution Utility meter and providing confirmation of the rate and tariff change to Site Host.
Criminal Background Check
For any and all public school Project Sites, Installer shall comply with applicable provisions of the Agreement and laws, including Education Code sections 45125.1 and 45125.2, relating.to criminal background checks for its employees.
3. ENGINEERING AND DESIGN REQUIREMENTS
Installer shall, at its own cost and expense, (i) design, prepare and cause to be sealed all drawings and Engineering Design Packages, perform engineering studies and estimates and attend meetings as may be required (or arrange for design and engineering pursuant to a subcontract executed in accordance with the Agreement), for the construction of the Project and interfaces required by the Distribution Utility including, without limitation, sizing of equipment, communication systems and components, preparing specifications and calculations for equipment and material to be included in the Project, completing the work in accordance with the Agreement, providing administration and other services and items required to complete and deliver to Site Host and Distribution Utility the design and Engineering Design Packages, calculations, studies, and drawings necessary to construct a fully integrated and operational Project, and (ii) provide services, attend meetings and prepare all necessary documents and permit applications required to obtain all Governmental Approvals, including, without limitation, coordinating with the Governmental Authorities, the Distribution Utility and other agencies regarding Governmental Approvals necessary for the completion of the Project, completing the permitting process beginning from the permit application through to final approval and receipt of all applicable permits, all in accordance with the Agreement and its exhibits, applicable law, Governmental Approvals, Site Host requirements, Distribution Utility requirements, Engineering Design Packages, industry standards, the actual condition of the Sites and all requirements to be sufficient, complete and adequate in all aspects to enable the Systems to meet all operational requirements and obligations as outlined in the Agreement matching the warranty period for each of the Systems.
Design Codes
The Project shall be designed and installed in accordance with the relevant edition enforced by the Governmental Authority having jurisdiction of all applicable codes, standards, and recommendations including but not limited to the following agencies:
ACI — American Concrete Institute
AISC — American Institute of Steel Construction
ANSI — American National Standards Institute.
ASCE — American Society of Civil Engineers
ASME — American Society of Mechanical Engineers
ASTM — American Society for Testing and Materials
CAL OSHA — California Occupational Safety and Health Administration CBC — California Building Code
CEC — California Electrical Code
CFC — California Fire Code
CSI — California Solar Initiative
Distribution Utility Manuals and Standards
DSA — Division of the State Architect for public schools ETL — Electrical Testing Laboratories
IAEI — International Association of Electrical Inspectors ICEA — Insulated Cable Engineer's Association
IEEE — Institute of Electrical and Electronic Engineers 0
IPMVP — International Performance Measurements and Verification Protocol NEC — National Electrical Code
NEMA — National Electrical Manufacturers Association
NESC — National Electrical Safety Code
NETA — National Electrical Testing Association
NFPA — National Fire Protection Association codes, including but not limited to o NFPA 101 —Life Safety Code
o NFPA 855 — Standard for the Installation of Stationary Energy Storage Systems UL — Underwriters Laboratories
General Requirements
3.1.1 Licensing
a) In all cases, engineers are to be properly licensed by the State of California. b) Site Host requires a minimum of a Class B and Class C-10 license be held by Installer and/or their subcontractors.
c) Electrical, geotechnical, civil, structural and other engineering designs and reports are to be stamped and signed by a licensed engineer.
3.1.2 Solar Photovoltaic ("PV") Panel Orientation and Shading a) Solar PV panels will have a minimum shade free window between the hours of 10:OOAM and 4:OOPM (local time) on the winter solstice. b) Orientation of the solar PV panels shall be optimized for maximum financial benefit, but in all cases with an azimuth between 180 and 270 degrees unless otherwise explicitly approved by Site Host in writing.
c) Installer shall provide a PVSyst report in PDF and excel 8760 format at every stage of the design that shows that the Solar Facility design and installation will meet the Annual Production Estimate.
3.1.3 Site and General System Requirements
a) Inverters and batteries shall not be placed in locations subject to exposure to direct sunlight between the hours of 10:00AM and 4:OOPM. Where inverters must be placed in locations that would be subject to direct exposure to sunlight during this window of time, they shall be provided with shade coverings or otherwise protected from continuous exposure to the sun.
b) Where applicable, the Project shall require a study, recommendations and stamp and sign off from a licensed structural engineer and a licensed geotechnical engineer. c) Sufficient access pathways and space shall be provided to and around all existing rooftop equipment to allow for ongoing maintenance of the equipment. d) All roof penetration flashing and sealing methods are to be determined, designed and implemented in accordance with the requirements of Site's roofing Installer and/or roofing consultant. All Site roof warranties shall be preserved. e) Where the solar PV panels are part of a ground mounted installation, Installer shall clear and grade the site substantially in accordance with the site grading plans. All vegetation inside the array boundaries shall be permanently removed. f) The low -end clearance of ground mounted solar PV panels shall be a minimum of two feet (2') above grade.
g) Ground mounted solar PV panels shall include sufficient drive aisles to maintain the equipment and perform washing, including access for vehicles and cranes as needed to remove and replace equipment.
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h) All roads shall be designed and installed for all weather access. i) Installer shall address all Americans with Disabilities Act ("ADA' requirements when installing Solar Facility as part of shade structures. Installer shall be responsible for all costs associated with any ADA upgrades required.
j) Equipment pads shall be protected by bollards. Bollards shall be permanent unless removable bollards are required to facilitate access to equipment. k) Installer shall provide erosion control, weed abatement, and security for the Site throughout construction. Installer shall remove any weeds via mechanical removal methods only.
1) Installer shall be responsible for creating and performing all requirements of a Storm Water Pollution Prevention Plan ("SWPPP"), dust control plan, pollution mitigation plan, and all other plans required by all Governmental Authorities. At a minimum, any earthwork -related or fine grading activities are to be conducted at such times that minimize construction -related fugitive dust.
m) If adequate site fencing or equivalent is not in place, equipment pads, disconnect switches and all other equipment which is at risk for tampering shall be fenced. Fencing shall be eight feet (8') high with two inch (2") galvanized steel chain link fabric where in accordance with all local requirements. Fenced equipment pads shall have slats placed in the chain links of a color determined by the Site Host. n) Ground mounted Solar Facility arrays shall be fenced in accordance with the NEC, NESC and requirements of any Governmental Authority and shall include provisions for at least one locking gate. If adequate site fencing or equivalent is not in place, the fencing around ground mounted Solar Facility installations shall provide for a sixteen foot (16') wide clearance to allow for vehicular access and to limit shading impact on the solar PV panels.
o) Locks for all gates and electrical enclosures to be provided by Installer but must be approved by Site Host prior to procurement. All gates shall include provision for Site Host and Installer locks to allow for access by each entity. p) Equipment pads shall be provided with two (2) 120VAC, 20A GFCI receptacles where alternative outlets are not readily available.
q) Installer will evaluate whether the Site is in a floodplain and take appropriate precautions to prevent water damage to the Project, including determining and installing the Systems including all electrical enclosures and all other materials to be used in the Project at the appropriate height above grade to be above the 1-percent- annual-chance flood elevation.
r) Lighting requirements for Solar Facility and other Project equipment locations shall be discussed with the Site Host during design, and any lighting locations and fixture specifications shall be mutually agreed upon.
s) An arc flash study shall be performed by Installer. All required equipment labeling, fault current and coordination analysis, and recommendations for proper personal protective equipment ("PPE") shall be followed in accordance with the results of the arc flash study.
t) Geotechnical studies, where required, must include soil corrosivity and thermal resistivity testing and evaluation. All work must include consideration for the results of the testing and evaluation.
3.1.4 Conduit and Wiring
a) All conductors shall be in conduit. Installer shall not direct bury conductors unless explicitly approved by Site Host in writing. All conduits shall be installed according to the requirement of the NEC and all Governmental Authorities. b) Buried conduit shall be PVC and shall be covered and encased per NEC requirements. 11
c) All below grade horizontal and vertical bends of PVC conduit shall use long radius elbows. Bending of straight PVC conduit to avoid installation of long radius elbows will not be allowed.
d) Vertical risers of buried or encased PVC conduit shall transition to the metallic conduit type specified below no higher than twelve inches (12") above grade or top of concrete.
Any exposed PVC shall be Schedule 80. If transition to metallic conduit is installed as soon as or just before the conduit is no longer buried or encased, use the appropriate conduit adapter and wrap metallic conduit in 10mil corrosion protection tape where exposed to soil or concrete.
e) Where exiting from the ground, all conduits shall enter enclosures from below and be made watertight. Finish with a silicone sealing compound. f) All above ground conduit shall be electrical metallic tubing (EMT) where corrosion is not a concern, and rigid galvanized steel (RGS) where corrosion is a concern. g) All conductors 8 AWG or smaller shall be copper. Code compliant aluminum conductors may be used for conductors larger than 8 AWG. All wiring that interfaces with any of Site Host's equipment must be copper.
h) All wiring used for grounding shall be copper.
i) Ground lugs shall be mechanical or irreversible crimp, rated for direct burial, listed to UL 467 and/or UL 2703 and suitable for use with copper conductors. j) Unless otherwise approved by Site Host in advance, Solar Facility modules shall be grounded with hardware listed to UL 2703. Solar Facility module grounding shall be in accordance with all requirements of the NEC and the Governmental Authority. k) All wiring shall be minimally rated to handle the voltage and current of the designed system.
1) All wiring shall be listed and labeled by a Nationally Recognized Testing Laboratory NRTL") in accordance with Underwriters Laboratories standards for its purpose and location.
m) Solar PV panel string wire shall be UL listed and be appropriately rated for UV exposure where required.
n) All DC wire, other than module -to -module wire in a string that is spanning a gap less than three inches (3") wide shall be located in conduit. o) The Solar Facilities shall be equipped with DC arc -fault protection in accordance with the NEC.
p) Where there are more than two DC strings in parallel on an MPPT, DC wiring shall be protected by overcurrent protection rated for DC circuits and marked by the manufacturer for use in solar. Fuses shall be listed and labeled by an NRTL in accordance with UL 2579.
q) All termination equipment shall be rated for the conductor type, temperature, current and voltage of the conductor being terminated.
r) Locking connectors shall mate with solar PV panel terminations and shall be certified compatible by the manufacturer of the locking connector provided with the solar PV panel.
s) All conductors used for communication will be shielded cable with a drain. t) Communications wiring shall be in separate conduits from the high voltage DC and AC wiring with sufficient separation to prevent interference. u) Worst -case DC voltage drop shall be limited to 2.0% unless otherwise explicitly approved by Site Host in writing. The circuit shall be defined as all wiring from the solar PV panel connectors .to the DC input terminals at the inverter. Installer shall account for all horizontal and vertical distances and all wire gauge transitions. v) Worst -case AC voltage drop for an individual inverter shall be limited to 2.0% for the Battery System and 2.5% for the Solar Facilities at maximum power, and weighted 12
average AC voltage drop shall be limited to 2.0% at maximum power, unless otherwise explicitly approved by Site Host in writing. The circuit shall be defined as all wiring from the inverter output to the Delivery Point. Installer shall account for all horizontal and vertical distances and all wire gauge transitions.
3.1.5 Electrical Tie -In
a) The Production Meter for the Systems shall be identified on the preliminary and final drawings and shall be located within ten (10') feet of the Delivery Point unless an alternative location is approved in writing by Site Host. b) Where needed, in lieu of providing and installing a Net Generation Output Meter NGOM") on each existing and new Solar Facility, Installer may provide, install and program a UL 1741 CRD listed Power Control System ("PCS") that is capable of demonstrating to the Distribution Utility that the Battery System either does not export energy to the grid or is 100% charged by the Solar Facility, thereby ensuring that the Solar Facility will receive full net energy metering ("NEM") credits from the Distribution Utility. Installer is responsible for all scope, costs and designs relating to the PCS.
c) Where needed, if Installer is unable to gain approval from the Distribution Utility for their proposed PCS as described above, A Net Generation Output Meter shall be provided for each Solar Facility in accordance with the Distribution Utility requirements. Installer is responsible for all scope, costs and designs relating to any NGOM. Installer must coordinate installation of the NGOM with existing Solar Facility owner for Sites that have a Solar Facility.
d) Where financially beneficial for the Project, the PCS shall be configured to limit net export to minimize Distribution Upgrade costs.
e) Should relocation of any circuit breakers be required to meet requirements of the Agreement, all scope, costs and designs are the responsibility of Installer. f) If motorized circuit breakers or similar equipment is required to isolate the electrical loads from the Distribution Utility for islanded Microgrid operation, all scope, costs and designs are the responsibility of Installer.
g) If motorized circuit breakers or similar equipment is required to isolate non -critical loads from the islanded Microgrid, all scope, costs and designs are the responsibility of Installer.
3.1.6 Structural
a) Structural engineers shall determine all code requirements and the Project shall be designed and installed in accordance with the latest edition of all applicable codes and standards.
b) Structural engineers shall perform a structural review of the existing structures and mechanical attachment details for all equipment to be located on the roof. c) Equipment pads shall be a minimum of six inches (6") of concrete reinforced at twelve - inch (12") intervals with #5 rebar unless otherwise directed by the structural engineer.
Equipment pad layouts shall include adequate spacing to accommodate maintenance activities for all equipment. A housekeeping pad elevated three inches (3") above the remaining pad surface will also be required.
d) Where electrical enclosures will be mounted vertically to Solar Facility structural posts or other supports, two feet (2') minimum ground clearance and appropriate working clearances as required per NEC shall be maintained. In no case shall equipment locations create shade on any Solar Facility between the hours of 10:00AM and 4:OOPM (solar time) on the winter solstice.
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e) Structural engineers are to specify the grade of steel used in all support structures. Mill certifications showing the identification of the steel to be used on the Project and the quality thereof shall be provided to Site Host. Mill certifications shall be checked by Installer prior to accepting delivery of any steel.
Engineering Design Packages and Project Execution Plan
Installer and its subcontractors (as applicable) shall prepare and submit to Site Host for their review and approval all drawings, assessments, reports, specifications, and all other necessary documents setting forth in detail all requirements for the construction of the Project. Installer shall prepare Preliminary, 50%, 90% and 100% Engineering Design Packages as described herein. All engineering and installation drawings shall comply with current construction standards, codes and regulations, and adhere to all requirements of the Agreement. The system design will comply with all applicable laws and regulations. Site Host approval of any of the submittals provided by Installer, including drawings, does not excuse Installer from their responsibility to meet all safety requirements, applicable codes and standards requirements, requirements of all Governmental Authorities and the requirements of the Agreement including this General Conditions and Technical Specifications.
Engineering Design Packages shall at a minimum contain the information as outlined below for each milestone.
3.1.7 Preliminary and 50% Engineering_ Design Packages
a) Design Drawings depicting and identifying at a minimum:
i) Solar Facility layout, where applicable
ii) Tilt and azimuth for all Solar Facility, where applicable iii) The proposed locations of all other major Solar Facility equipment including but not limited to electrical point of connection, disconnects, panelboards, inverters, meters and dataloggers, where applicable
iv) The proposed locations of all major Battery System equipment including but not limited to electrical point of connection, disconnects, transformers, panelboards, inverters, batteries, meters, controllers and dataloggers, where applicable
v) The locations of all major existing equipment, including but not limited to Distribution Utility transformer and meter, main electrical service switchgear, System electrical point of connection(s), disconnects, panelboards, inverters, arrays, meters and dataloggers. ,
b) Product data sheets and copies of manufacturers' warranties for all major pieces of equipment.
c) Completed System Site Assessment Table in native and PDF formats. d) Where applicable, PVSyst energy production modeling report in PDF format and 8760 output file in MS Excel format. The energy production model report and 8760 output files must be in the same format and use the same assumptions as those used to determine the inputs to the Agreement.
e) Where applicable, Battery System performance modeling report in 4x8760 output file in MS Excel format.
f) System performance report detailing the Critical Loads and Estimated Microgrid Operation Duration, where applicable.
3.1.8 90% and 100% Engineering .Design Packages
a) All information required above for the Preliminary and 50% Engineering Design Packages, updated at each milestone.
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b) A full set of Design Drawings as described in a subsequent section. c) All required drawings, assessments and reports stamped and signed by an engineer licensed in the appropriate discipline — structural details shall not be stamped by an electrical engineer.
d) Where applicable, full structural details of the solar PV panel mounting system, Battery System pad and anchorage, equipment support racks and anchorage, fencing design and associated calculations.
e) Microsoft Project or equivalent construction schedule (providing Gantt chart output) showing milestones, equipment order and delivery dates, and staffing requirements.
Specific milestones such as conduit installation completion, material arrival dates, interconnection date, and commissioning timeline, shall be highlighted. f) A list of those changes made from the original proposal with the reasons therefore.
The Engineering Design Packages will be reviewed by Site Host. Comments shall be delivered to Installer within ten (10) business days of submission for review. Ensuring that the Project complies with all requirements and will be installed to meet all requirements of the Agreement remains the sole responsibility of Installer.
3.1.9 Project Execution Plan
A complete Project Execution Plan for each Site shall be provided for review, which shall at a minimum address the following:
a) Material storage location
b) Lay -down and layout yard location
c) Site office location
d) Access and mobilization
e) Crane locations and traffic control
f) Method of installation
g) Human resources and staffing
h) Communications
i) Anticipated Project risks
The Project Execution Plan shall be reviewed and approved prior to any work being performed on the Sites. The Project Execution Plan shall be submitted as soon as reasonably possible, and no later than two (2) days after the 90% Engineering Design Package due date.
Design Drawings
A drawing summary list shall be maintained by the Engineer of Record for tracking drawings and revisions thereof over the design and construction period, and the list shall be provided to Site Host on a bi-weekly basis or as requested. All Design Drawing submittals shall be according to the following:
3.1.10 Format
a) All drawings shall include a title block which at a minimum contains the Project name, Site address, Site Host logo, where applicable the DSA Identification stamp, Installer's name, engineer's stamp, engineer's name and drawing revision table. b) Any changes in the Engineering Design Packages from one Site Host submittal to the next shall be clouded.
c) Redlines shall be maintained on a not more -than -weekly basis. As -built drawings shall be completed in a reasonable amount of time following the Governmental Authority final inspection and sign off.
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3.1.11 Content
The descriptions of the sheets and sheet contents below shall be considered the minimum requirement. Additional sheets and details shall be included as needed to describe the project in adequate detail for construction and permitting needs. a) Title Page
Information on the title page shall include, but not be limited to the following:
i) Location of the Site
ii) Amount of land area to be occupied by the Project, expressed in square feet or acres as appropriate
iii) Project directory including contact information for all engineers, designers and consultants
iv) Index of drawings
v) Applicable codes and standards list including most recent CEC/NEC vi) A scope of work narrative description
vii) System size, which shall include kWDC, kW CEC-AC and kWAC for any Solar Facility, and kWAC and kWh for any Battery System viii) Existing Solar Facility size (kWDC and kWAC), where applicable ix) Interconnection type (NEM-PS, NEM-A, Rule 21)
x) Solar Facility module manufacturer, part number and quantities (proposed and existing where applicable), where applicable
xi) Solar Facility inverter manufacturer, part numbers and quantities (proposed and existing where applicable), where applicable
xii) Solar Facility module mounting hardware description (ballasted roof mount, ground mount, shade structure mount etc.), where applicable xiii) Battery manufacturer, part numbers and quantities, where applicable xiv) Battery System inverter manufacturer, part numbers and quantities, where applicable
xv) All other information required by all Governmental Athuorities and not explicitly listed here
xvi) Benchmarking / survey control data as applicable
b) Architectural Site Plan
Information on the site plan shall include, but not be limited to the following:
i) Property lines
ii) Required setbacks and/or yards
iii) Easements
iv) Existing buildings and structures
v) Proposed locations of Major Equipment
vi) Building code analysis justifying proposed equipment placement vii) Separation distances
viii) Fire access requirements
ix) Modifications for ADA compliance, where applicable
c) Single Line Diagrams
The single line diagrams shall accurately depict the physical electrical connections i.e., quantity, type, and size of conductors, quantity, size, and type of conduit) between all electrical equipment used in the system. Information on the single line diagrams shall include, but not be limited to the following items:
i) System size, which shall include kWDC, kW CEC-AC and kWAC for any Solar Facility, and kWAC and kWh for any Battery System 16
ii) Existing Solar Facility system size (kWDC and kWAC), where applicable iii) Interconnection type (NEM-PS, NEM-A, Rule 21)
iv) Solar Facility module manufacturer, part number and quantities (proposed and existing where applicable), where applicable
v) Solar Facility inverter manufacturer, part numbers and quantities (proposed and existing where applicable), where applicable
vi) Battery manufacturer, part numbers and quantities, where applicable vii) Battery System inverter manufacturer, part numbers and quantities, where applicable
viii) Distribution utility transformer, including size
ix) Distribution utility meter, including meter number and SAID x) Main electrical service switchgear, including bus amperage, main service disconnect amperage, voltage rating and interrupt rating xi) Solar Facility electrical point of connection, disconnects, panelboards, inverters, arrays, meters and dataloggers, where applicable xii) System interconnection tie-in scheme
xiii) All AC and DC disconnects including wiring and fusing within disconnects xiv) All overcurrent protection device sizing
xv) Switchgear, including bus amperage, main over current protection device OCPD") amperage, voltage rating and interrupt rating
xvi) Transformers, including kVA, primary and secondary voltages xvii) Solar Facility modules, inverters and batteries
xviii) Number of Solar Facility modules per string
xix) Number of Solar Facility strings for each inverter and/or combiner box xx) String labels per array or subarray
xxi) Net Generation Output Meter, Solar Production Meter, Battery System meter, Facility Load meter and any other meters, where applicable xxii) Wire type, conductor material, size and quantity used for each run xxiii) Conduit type, size and quantity of wires in each conduit for each run xxiv) Total wire length for each run
xxv) Complete electrical calculations, including voltage drop, OCPD and wiring ampacity, and Solar Facility string voltage
xxvi) Monitoring data communications and power wiring
xxvii) Controls diagram including low voltage, low current and power wiring xxviii) Security camera data communications and power wiring, where applicable xxix) Lighting, convenience outlets, and any auxiliary power circuit wiring and equipment where applicable
xxx) Make and model of all Major Equipment
d) Electrical Site Plan and Electrical Details
Information on the electrical layouts and details shall include, but not be limited to the following:
i) Plan view of locations of all electrical equipment shown on the Single Line Diagrams described above
ii) Location of the point of interconnection
iii) Enlarged views of the Battery System area, any other electrical equipment pads, and main electrical service area
iv) Elevation views of all electrical equipment
v) Locations of conduit runs
vi) Locations and sizing of spare conduits
vii) Solar Facility string map per array or subarray
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viii) Safety label details (including, but not limited to, arc flash) e) Grounding Diagram
All electrical equipment shall be depicted, including their capacity/rating, manufacturer, part number, quantity, and reference designator where applicable.
Diagram shall indicate equipment grounding connection points and grounding conductor size. Equipment shall include but not be limited to the following:
i) -Solar Facility Modules
ii) Solar Facility Inverters
iii) Batteries
iv) Battery System Inverters
v) Transformers
vi) Switchgear
vii) AC and DC disconnects
viii) Main electrical service switchgear
ix) Meters
x) Control and Monitoring equipment
xi) Distribution panelboards
f) Structural and Civil Sheets
Information on structural and civil sheets shall include, but not be limited to the following:
i) Equipment pad(s) structural details
ii) Equipment mounting rack structural details
iii) Equipment anchorage design
iv) Fence design and structural details
v) All civil work details
4. EQUIPMENT
The System is intended to be in operation for the full warrantied period of the Major Equipment, therefore, the life cycle costs (capital expenditures and operating and maintenance expenses) for all installations and systems must be considered in selection criteria for all materials and equipment. Installer shall purchase and cause to be delivered to each Project Site all equipment and materials required for the Project and as described in Site Host -approved final Engineering Design Package, specifications and data sheets and as required to construct a fully functioning Project. Any proposed changes or substitutions must be presented to Site Host in standard submittal format with detailed explanations and instructions for review, comment and approval. Minimum requirements for equipment are described below. Site Host approval of any of the submittals provided by Installer, including drawings, does not excuse Installer from their responsibility to meet all safety requirements, applicable codes and standards requirements, requirements of all Governmental Authorities and the requirements of the Agreement including this General Conditions and Technical Specifications.
Standards
All components shall be designed, manufactured, tested and listed in accordance with the latest applicable standards of NEMA, ANSI, NEC, IEC and UL. Installer shall verify listing and labeling of equipment by a NRTL prior to installation. In all cases NEC and Governmental Authority rules shall apply.
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Factory Testing
Any equipment that is required to be factory tested to an applicable standard shall be accompanied by the results of those factory tests, and further those results will be submitted to Site Host as part of the Final Binder.
Acceptance and Care
Equipment shall be stored, handled and installed in accordance with manufacturer's requirements.
Material received shall be identified by serial number. A report recording make, model and serial numbers of the material and equipment received shall be prepared and shall be forwarded to Site Host within ten (10) days of the material and equipment being received.
NEMA RatinL3
Enclosures mounted outdoors shall be rated a minimum of NEMA 3R. If any Site is within two (2) miles of any body of salt water or other potentially corrosive water, enclosures shall be NEMA 4X in stainless steel and all other enclosures exposed to the elements shall be NEMA 4X.
Nameplates and Labeline
All Major Equipment, panels, boxes, and associated equipment shall be clearly labeled. Reference ANSI Z535.4-2011 for guidelines describing suitable font sizes, words, colors and symbols for labels.
Nameplates and map placards shall be engraved phenolic placards made of red stock with white lettering sized appropriately for the size and purpose of the label. Installer shall submit the proposed labels for approval prior to installation. The following minimum labeling shall be installed:
A. Install engraved signs for instruction and warning identifying that the Systems are operational on the premises at appropriate locations and that there are potentially multiple power sources on the premises — submit wording and location to Site Host for approval. In all cases NEC and Distribution Utility requirements shall dictate.
B. Install all required signage per NEC (including arc flash requirements per NEC Article 110).
C. Install engraved phenolic placards identifying emergency disconnecting means.
D. Where applicable, provide identification of all Solar Facility DC power circuits on switches, combiner boxes and/or inverters. Clearly identify individual Solar Facility module strings within the equipment at which they terminate. Use appropriate wire color codes (i.e., red and black) for positive and negative conductors.
E. Solar Facility modules must include serial numbers in such a position as to be easily visible after installation.
Products — Approved Manufacturers and General Product Requirements Only products that meet the requirements below shall be used in the construction of the Project, unless otherwise explicitly approved in writing by Site Host.
4.1.1 Approved Solar Facility Modules
Please refer to Attachment F: Major Equipment
4.1.2 Approved Solar Facility Module Manufacturer
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Please refer to Attachment F: Major Equipment
Site Host's General Guidelines for Solar Facility modules Thin-film, concentrating solar technologies, etc. technologies are not accepted by Site Host.
All Solar Facility modules must be included on any required rebate -related approved module list as well as on the California Energy Commission's ("CEC'l List of Eligible Photovoltaic Modules.
All Solar Facility modules shall be listed on the most recent Tier 1 Solar Panels List as determined by BloombergNEF.
All Solar Facility modules must have anti -reflective (AR) glass surfaces.
All Solar Facility modules used on the Project shall include a minimum twenty- five (25) year linear power output warranty and a minimum ten (10) year product warranty.
All array layouts, Solar Facility module related submittals, and Solar Facility module data sheets must include cell and module efficiency ratings, and define the guaranteed production degradation over the warranted life of the module.
Installer will provide flash test data for all Solar Facility modules to Site Host in MS Excel format upon procurement of Solar Facility modules. Site Host, at its sole discretion, may randomly select up to fifty (50) Solar Facility modules for delivery to a third -party for quality verification testing. The costs of such verification testing shall be the responsibility of Site Host.
4.1.3 Approved Solar Facility Inverter Manufacturer
Please refer to Attachment F: Major Equipment
Site Host's General Guidelines for Solar Facility Inverters Central and string inverters with a maximum input voltage of 1,000VDC are allowed where in compliance with the NEC for rooftop and shade structure mounted Solar Facility. For rooftop mounted Solar Facility, the inverter shall be certified compatible with the Approved Rapid Shutdown solution described in a subsequent section, and shall have the rapid shutdown initiation device integrated.
Central and string inverters with a maximum input voltage of 1,500VDC are allowed where in compliance with the NEC for ground mounted Solar Facility. Microinverter solutions may be proposed. All inverters must be included on any required incentive - related approved inverter list as well as on the CEC's List of Eligible Inverters.
Inverters must meet all Distribution Utility requirements. All inverters must have a minimum 20-year warranty.
Inverter Manufacturer Preventative Maintenance and Support Services Site Host requires preventative maintenance support services which may be provided by Installer or the inverter manufacturer, as well as comprehensive and highly responsive repair service offerings. In addition, Site Host will be monitoring the inverters' performance remotely,.and require that the inverters utilize an open interface and documented protocols for third party monitoring software. 20
4.1.4 Approved Mounting Hardware — Ground Mount
Please refer to Attachment F: Major Equipment
Site Host's General Guidelines for Solar Facility Module Mounting Hardware for Ground Mounts
Ground mounted fixed tilt Solar Facility module mounting systems shall be NRTL listed to UL 2703. Ground mounted tracking systems shall be NRTL listed to UL 3703.
The Approved Solar Facility Modules listed above shall be on the tested and approved Solar Facility module list maintained by the mounting system manufacturer to ensure compatibility with the mounting system's integrated grounding components. Ground mounted arrays shall meet all DSA requirements.
Site Host requires that all Solar Facility module mounting solution descriptions clearly identify the mounting hardware and any engineering services related to the mounting solution. Installer shall provide full mounting solution specifications, warranty details, etc.
4.1.5 Approved Battery System Inverter Manufacturer
Please refer to Attachment F: Major Equipment
Site Host's General Guidelines for Battery System Inverters All Battery System inverters must be included on any required incentive -related approved inverter list. Inverters must meet all Distribution Utility requirements. All inverters must have a minimum ten (10) year warranty.
Inverter Manufacturer Preventative Maintenance and Support Services Site Host requires preventative maintenance support services which may be provided by Installer or the inverter manufacturer, as well as comprehensive and highly responsive repair service offerings. In addition, Site Host will be monitoring the inverters' performance remotely, and require that the inverters utilize an open interface and documented protocols for third party monitoring software.
4.1.6 Approved Battery Manufacturer
Please refer to Attachment F: Major Equipment
Site Host's General Guidelines for Batteries
Lithium -ion battery chemistry is preferred. Lead acid battery chemistries are not acceptable. All batteries must have a minimum ten (10) year warranty.
Battery Manufacturer Preventative Maintenance and Support Services Site Host requires preventative maintenance support services which may be provided by Installer or the battery manufacturer, as well as comprehensive and highly responsive repair service offerings.
4.1.7 Approved Data Acquisition System
Please refer to Attachment F: Major Equipment
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4.1.8 Performance Monitoring and Reporting Service Installer
4.1.9 EPC Partner/A1soEnergyInverter Monitoring Installer EPC Partner
4.1.10 Approved Solar Facility Module Temperature Sensors AlsoEnergy
4.1.11 Approved Ambient Temperature Sensors
AlsoEnergy
4.1.12 Approved Irradiance Sensors (Pyranometers
AlsoEnergy
4.1.13 Approved Wind Speed and Direction Sensors
AlsoEnergy
4.1.14 Approved Battery System Meter
AlsoEnergy
4.1.15 Approved Solar Production Meter
AlsoEnergy
4.1.16 Approved Safety Switches
Eaton
4.1.17 Approved Transformers
EPEC Solutions
Site Host's General Guidelines for Transformers
Any dry -type transformers shall meet the latest Department of Energy efficiency requirements, shall have copper windings, 220°C insulation rating and 115°C maximum temperature rise rating.
Any oil -filled transformers shall be filled with a non -toxic, non-bioaccumulating, biodegradable fluid.
4.1.18 Approved Grounding Devices
Calpico, Eritech, Galvan, Nehring
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5. COMMUNICATIONS AND MONITORING SYSTEMS
Installer is responsible for the complete and fully functional installation and operation of the SCADA system. Any labor, communications devices, wiring and or other materials shall be included in Installer's cost and scope. The SCADA system shall meet all the requirements outlined in the Agreement.
Performance Monitoring & Reporting Service
Installer shall provide a Performance Monitoring and Reporting Service ("PMRS') as part of the SCADA system to monitor and collect data from the Facility Load Meter, Critical Load Meter, Battery System Meter, Solar Production Meter, inverters, batteries, and all other data points applicable to the operation of the Systems. Installer shall be responsible for procuring, installing, and commissioning all SCADA equipment, and for entering into a contract with a third -party Performance Data Installer PDP'). The monitoring service requirements are as follows:
A. Installer shall provide operator and administrator level training to Site Host for using the PMRS software interface as part of commissioning activities.
B. The PMRS software interface must allow for access via a link from Site Host's website and must allow the users to view and download real-time and historical electricity usage, solar production, and Battery System power flow data, where applicable, at each Project Site over a variety of timescales including but not limited to a minimum of a year of fifteen 15) minute interval data. Installer shall coordinate and obtain approval of all data points to be displayed on the public webpage with Site Host prior to implementation.
C. The PMRS software interface must allow Site Host to programmatically download via an Application Program Interface ("API') the real-time and historical electricity usage, solar production, and Battery System power flow data, where applicable, at each Project Site over a variety of timescales including a minimum of one (1) year of fifteen (15) minute interval data. The API must include the ability to reference most recent inverter, meter and alarm status readings.
Equipment and Components
Below is a list of the minimum equipment and components that must be included as part of the PMRS.
All equipment shall be installed to equipment manufacturer's recommendations and best practices for the Systems.
A. Facility Load Meter(s)
Revenue grade energy meters shall be installed to measure the total (not net) energy usage, instantaneous demand, power factor, etc. at each main switchboard where the Systems is interconnected. The load side revenue grade energy meters shall be included as part of the PMRS system, send data through the PDP and be displayed on the PMRS software interface.
B. Critical Load Meter(s)
For projects containing Critical Loads to be serviced by the Battery System, revenue grade energy meters shall be installed to measure the energy usage, instantaneous demand, power factor, etc. at each Critical Load distribution panel. The load side revenue grade energy 23
meters shall be included as part of the PMRS system, send data through the PDP and be displayed on the PMRS software interface.
C. Battery ystem Meter
For projects containing Battery Systems, revenue grade energy meters shall be installed to monitor power and energy flows of the Battery System at each Site. The Battery System Meter shall be located within ten feet (10') of the Delivery Point unless an alternative location is agreed to in writing by Site Host. The Battery System Meter shall be included as part of the PMRS system, send data through the PDP and be displayed on the PMRS software interface.
D. Solar Production Meter
For projects containing Solar Facilities, revenue grade energy meters shall be installed to monitor power and energy production of any Solar Facility present at each Site. The Solar Production Meter shall be located within ten feet (10') of the Delivery Point unless an alternative location is agreed to in writing by Site Host. The Solar Production Meter shall be included as part of the PMRS system, send data through the PDP and be displayed on the PMRS software interface.
E. Datalogger/Internet Gateway
F. Inverter Monitoring
If inverters are not provided with communications as part of the standard package, then the communications option shall be ordered. Where various communication package options exist, those options shall be discussed with Site Host prior to ordering.
G. Solar Facility Array Monitoring
For projects containing Solar Facilities, if DC combiner boxes are installed within the array field and not integral to the Solar Facility inverters, DC monitoring shall be provided for each home run from the combiner boxes to the inverters.
H. Protective Relays, Medium Voltage Circuit Breakers and Transformers All available data points shall be provided through the PMRS system.
I. External Device Communication
Installer must arrange for and provide Site Host a secure and reliable internet connection adequate to allow for uploads of all data points from the PMRS system every fifteen (15) minutes at their sole cost. Installer shall provide this internet connection via a cellular modem with data service. Installer shall make this information available to Site Host through the PMRS system.
Remote Access Monitoring Portal
5.1.1 Power and Energy Data
Each Project Site's PMRS web portal should display the following minimum information over a variety of timescales:
a) Battery System inverter instantaneous power (kW)
b) Battery System state of charge (%)
c) Battery System instantaneous energy remaining (kWh)
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d) Solar instantaneous power output (kW)
e) Solar energy production (kWh)
f) Facility entire instantaneous load without the System (kW) g) Facility instantaneous load net of Solar Facilities (kW) h) Facility instantaneous load net of Battery Systems (kW) i) Facility entire energy consumption (kWh)
0) Critical loads instantaneous load (kW)
k) Critical loads energy consumption (kWh)
1) Billing cycle peak demand without the Systems (kW)
m) Billing cycle peak demand reduction due to the Battery System (kW) n) Billing cycle peak demand reduction due to the Systems (kW)
5.1.2 Battery System Alarms
For projects containing Battery Systems, each site should have at least the following custom alarms:
a) Whenever the billing cycle peak demand exceeds the programmed demand threshold set at the beginning of the billing cycle.
b) The battery state of charge remains below a programmed value for five (5) consecutive days. An example is to set the value to 66% of the Battery System kWh rating in an attempt to identify if/when the Battery System is malfunctioning. c) Any meter reports a magnitude of less than 0.1 kW for one day.
5.1.3 Solar Facility Alarms
For projects containing Solar Facilities, each site should have at least the following custom alarms:
a) Inverter produces less than ten percent (10%) of the inverter capacity over the course of an hour between 10:00AM and 3:OOPM. The upper limit of the alarm should be set to twice the inverter capacity.
b) Any meter reports a magnitude of less than 0.1 kW for one hour between 10:00AM and 3:OOPM. The upper limit of the alarm should be set to twice the site capacity.
5.1.4 Solar Facili , Analytics Pages
For projects containing Solar Facilities; each Solar Facility PMRS should have the following tabs configured in the monitoring analytics page. They should be labeled uniformly at each site. The tabs should be labeled as follows:
a) Load Profile
i) Solar Production Meter Power (kW)
ii) Battery System Meter Power (kW)
iii) Facility Demand (kW)
iv) Net Consumption (kW)
b) Inverter Output
Energy generation (kWh) per inverter. Each inverter shall have a unique identifier matching the naming convention in the as -built drawings.
c) Predicted Power
i) Solar Production Meter Power (kW)
ii) Predicted Power (kW)
d) Inverter vs. Solar Production Meter Power
Power output per inverter displayed with the Solar Production Meter Power 041
5.1.5 Settings
All System information should be filled out completely and correctly on the monitoring platform to match the as -built drawings and allow for easy identification of equipment and other System information.
6. CONSTRUCTION
Installer is required to conduct all construction and construction management work for completion of the Project. Installer shall perform all work in accordance with generally accepted industry practices, all applicable laws, regulations, codes, rules, ordinances, Government Approvals and permitting requirements, equipment manufacturer's requirements, and quality control inspection protocols so that the System meets or exceeds (i) all requirements of applicable laws, Government Approvals and licenses; (ii) equipment manufacturer's installation specifications, and compliance with the terms and conditions of all applicable warranties and guarantees; (iii) complies with all requirements of the Interconnection Agreement; (iv) all established safety protocols for operation and maintenance, and labeling / marking requirements; (v) all requirements of the commissioning procedures and performance validation herein; (vii) all requirements for any applicable federal, state or other environmental or financial rebates and incentives. All work must be performed and supervised by skilled workers trained and experienced in the installation of the Systems in accordance with equipment manufacturers' installation requirements. Installer is encouraged to utilize local subcontractors and source materials and resources locally should they provide requisite qualifications and competitive advantages.
Site Safetv and Securi
Installer shall be solely responsible for compliance with all applicable occupational safety and health standards, rules, regulations and orders established by local agencies, the State of California, and Cal OSHA, including obtaining permits required by California Code of Regulations, Title 8, Section 341 and 341(a). In addition, Installer and all subcontractors shall comply with applicable provisions of Federal, State, and municipal safety, health, and sanitation statutes and codes. In the event there is a conflict between the provisions of the Safety and Health Regulations for Construction promulgated by the U.S. Department of Labor in Title 29 CFR Part 1926, OSHA, or Cal OSHA, the more stringent provision shall prevail.
Installer will develop a site -specific OSHA approved Site Safety and Security Plan for each Project Site and submit it for review and approval prior to the start of construction. The Site Safety and Security Plan shall include an evaluation and appropriate documentation of the safety record for all subcontractors that will be performing work on the Project, a traffic control plan, and an Injury and Illness Prevention Program plan. The Site Safety and Security Plan shall also include the location of emergency utility shutoffs and an evacuation plan. No work shall be performed on the Project prior to written confirmation that the Site Safety and Security Plan has been accepted.
A safety conference shall be scheduled prior to the start of construction to review the experience modification rating, the respective safety requirements, and to discuss implementation of all health and safety provisions related to this project. Representatives from Installer and every subcontractor shall be present at the safety conference. Installer shall ensure the Site Host informed of the safety conference at least five days in advance and provided the option to attend.
Following the commencement of work on the Project, safety meetings will be held once a week with all Installer and subcontractors' employees attending. Printed names will be taken of those attending the meeting. No individual will start work at any Project Site without having attended a safety briefing on the dangers and protocols of the Project Site. Records of this training will be kept and provided for 26
review. No individual will operate a piece of equipment on which they have not had certification training. Certification shall be carried on the operator at all times.
Security of the Sites is the sole responsibility of Installer, including any security monitoring equipment, fencing or other precautions that Installer may deem reasonably necessary. The Site Host will not be liable for theft or damage of equipment or materials stored at the Sites.
Access to and Use of Proiect Sites
The Site Host shall provide access and area at each Site for the performance of the work on the Project, including lay -down area and storage area. The Site Host will grant Installer access to each Site to perform all work associated with the Project and on -going operation and maintenance during regular business hours, or such other reasonable hours requested by Installer and approved by The Site Host in accordance with the Agreement. Access points to the Sites must be closely coordinated with the Site Host and approved in advance before construction begins. The Site Host will issue the necessary keys to Installer to access Sites once all related requirements have been met. Installer shall return keys to the Site Host at any time upon request by the Site Host. Installer shall reimburse the Site Host for the cost of re -keying all of the Site Host's locks if keys are not returned to the Site Host.
Installer agrees not to bring, keep, or permit to be brought to, or kept at or near any Site, any hazardous materials, or materials which are prohibited by the Site Host or prohibited by the standard form of Site Host's insurance policy. Installer agrees not to commit or suffer to be committed any waste upon the Sites.
Installer shall install signage at each front gate or Site entrance to identify the Project and Installer's name and contact information upon Site Host approval of all proposed signage. Installer shall submit a prototype of the construction signs to Site Host for review and approval before posting the signs at the construction sites. After approval, actual sign placement and location shall be coordinated with Site Host.
Drawings
Installer shall maintain one complete Engineering Design Package at each Site including one full set of full-size plans marked to show any deviations that have been made from the approved plans, including but not limited to buried or concealed construction features or utilities which are revealed during the course of construction. Current as -built record drawings shall be accessible to Site Host at all times during the construction period. They shall be reviewed with Site Host at regular intervals. Upon completion and prior to final inspection of the Project, Installer shall submit the complete as -built Engineering Design Package for review and shall make such revisions or corrections as may be necessary for them to be a true, complete, and accurate record of the Project in the opinion of Site Host.
Work -Time Constraints
Great care shall be taken to avoid interruptions to the Site Host activities and neighboring properties.
Construction activities shall take place between typical working hours of 7:OOAM to 4:30PM, Monday through Friday, excluding recognized holidays. Reasonable efforts must be taken to minimize disturbance to persons living or working nearby, and to the general public. All local ordinances shall be adhered to regarding noise limits, otherwise a maximum of 65dB shall not be exceeded when measured at the property line. Deliveries shall take place, outside high traffic times and must be coordinated with Site Host's personnel. Preferred hours for deliveries are 8:OOAM to 4:OOPM, Monday 27
through Thursday. Installer shall manage construction activities around and with consideration to the other projects occurring at the same time where applicable. Installer will be required to provide necessary weekly updates of scheduled activities at each Site to Site Host.
A shutdown plan must be provided to Site Host at least two months in advance to allow for electrical shutdowns to be carefully coordinated with Site Host's personnel. All interruptions in power shall be subject to Site Host approval and must be coordinated to take place during a time period that will minimize disruptions to Site activities. This requirement will typically mean, and Site Host reserves the right to request, that shutdowns shall occur on weekends or after working hours. All efforts must be taken to minimize the amount of time required to complete interconnections. If required, backup power will be provided by Installer's generators during shutdowns, at Installer's expense. Notice of all pending shutdowns shall be provided thirty (30) days in advance, followed by two (2) weeks in advance, followed by forty-eight (48) hours in advance.
General Requirements
6.1.1 Conduit and Wiring
a) Locations of all junction boxes shall be reviewed with the Site Host prior to start of construction. Junction boxes shall not be installed in or near playgrounds and playfields at any school sites.
b) No trenching is allowed inside playgrounds and play fields at any school sites. c) No wire splicing shall be allowed.
d) All exposed wire shall be secured every three and a half feet (3.5') minimum. e) When terminating aluminum conductors, all terminations shall be brushed and coated with an oxide inhibitor.
f) Underground cabling shall have electrical warning tape installed approximately twelve 12") inches below finished grade in the backfill.
g) Installer shall use GPRS and potholing to survey for underground utilities and use best practices when boring or trenching, including hand digging near buried lines.
Trenching or boring in potentially high -risk areas (gas lines) shall be coordinated with Site Host.
h) Installer shall carefully preserve all benchmarks, monuments, survey markers, and stakes and shall be solely responsible for resetting if required. i) Installer shall ensure parasitic loads (lights, security cameras, etc.) are not installed on the same circuit as the System's Production Meter and are installed so that their load shall be included with the overall site's Facility Load Meter measurement. j) Installer shall confirm that each of the Systems is interconnected to the correct Distribution Utility meter at each Project Site by validating the meter and service account identification numbers (SAID) with the Distribution Utility. k) All exposed wiring shall be properly rated for direct sun exposure. 1) Exposed wiring shall be restrained utilizing wire clips per NEC requirements and best practices to eliminate strain on Solar Facility module junction box connections, wire pinch points and wire kinks. Strain -relief devices shall be rated and labeled for exposure to UV (direct sunlight).
m) Conduit entry locations shall be made in manufacturer provided/specified locations only.
n) All ground conductors shall be protected from physical damage as specified in the NEC.
o) Grounding wire connections must be made at closest point possible between concrete and steel, sharp edges removed, and painted to match.
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p) Power and data lines shall be located in separate conduits with appropriate separation to avoid interference.
q) All junction boxes, condolets, etc., are to be sealed with a silicone sealing compound and made watertight.
r) H-20 rated concrete handholes with cast iron or galvanized steel lids shall be used for all underground junction box locations unless Site Host approves an alternative approach. Lids shall be bolted or welded in place with an appropriate permanent marking such as "ELEC" or "COMM" on the lid depending on the contents of the junction box.
s) Aboveground junction boxes must have tamperproof screws and shall not be placed in areas where water ponding is anticipated.
6.1.2 Equipment
a) Equipment shall be stored and handled in accordance with manufacturer's requirements.
b) Inverters and battery enclosures, where applicable, shall be placed away from all buildings where the operational noise would disturb the occupants. c) Inverters and battery enclosures, where applicable, shall not be placed in locations where fences or other barriers would obstruct replaceable air filters or prevent access for regular service and cleaning.
d) All high voltage and high amperage equipment must be installed in secure, tamper- proof, and locked enclosures to prevent unauthorized tampering for safety and theft prevention.
e) Locks for all gates and enclosures to be provided by Installer but must be approved by Site Host prior to procurement.
f) Where necessitated by birds nesting underneath solar shade structures and/or ground mounted racking systems, Installer shall be responsible for providing a means of deterring birds from nesting that is acceptable to Site Host. g) Safety labels are required for high voltage and high amperage equipment. h) All enclosures shall be detailed as part of the punch list work to ensure that any scratches, etc. are properly covered with paint as appropriate. i) Solar PV panels shall have their serial numbers recorded as they are installed, grouped and listed by DC string.
0) The Project will include installation of conduits at each Site sufficient to allow for fixture installation of security cameras at locations agreed upon with Site Host during Project design. Should Installer choose to install cameras as part of the overall security plan for any Site, camera selection and location shall be coordinated Site Host.
Integration of any installed safety and security systems with the SCADA system shall be reviewed with Site Host and options provided.
6.1.3 Site Work
a) It is Installer's soleresponsibility to ensure that all work on the Project complies with all federal, state, and local code requirements, all applicable industry codes and standards, and all other requirements in the Agreement including the requirements in this General Conditions and Technical Specifications.
b) Temporary security fencing around construction areas shall be provided throughout construction, to be removed at end of construction, and permanent fencing and bollards added as required.
c) Prior to the start of any work on Site, Installer shall take pre -construction videos and photographs of any and all areas that may be impacted as part of the Project 29
construction and shall provide the pre -construction videos and photographs to Site Host for review and reference.
d) Following the finish of construction, Installer shall take post -construction videos and photographs of all areas that were impacted as part of the Project construction and shall provide the post -construction videos and photographs to Site Host for review and reference.
e) Installer is solely responsible for locating and avoiding all existing underground utilities, including irrigation lines, and shall ensure the existing underground utilities and installations are not impacted by Project construction. In the event Installer damages or makes inoperable any underground or above ground utilities, it will be Installer's full responsibility to notify Site Host immediately and make damaged/inoperable utilities whole and fully operational to Site Host's standards and to Site Host's satisfaction, at Installer's sole cost and expense. f) Installer is responsible for the repair of any damage to any Site that is caused by Installer at their sole cost and expense. Installer shall assess the condition of all areas to be used in the construction of the Systems prior to construction and shall alert Site Host if any such area cannot accommodate wear and tear caused by ordinary construction activities. In such event, Installer shall propose a reasonable remedy or remedies to such conditions for Site Host's consideration. g) Damage to Site Host's facilities and/or the Systems shall be reported to Site Host within twenty-four (24) hours with photographs.
h) All parking lot wheel stops that are damaged during construction shall be replaced at Installer's sole expense.
i) All areas within the limits of construction or otherwise impacted by construction of the Project shall be restored to pre -Project conditions at Installer's sole cost and expense including but not limited to existing rooftop equipment, fine grading, rock and concrete spoils removal and vegetation remediation.
j) For roof mounted Solar Facilities, no metal cutting shall occur on the roof, with the exception of conduit, which shall be cut over a carpet or similar filing collector and taken off the roof in whole at the end of the Project. In no instance shall metal filings blow or otherwise end up on the surface of any Solar Facility module or the roof. k) For roof mounted Solar Facilities, the roof shall be loaded in a manner prescribed by the structural engineer so as not to overload any particular point on the roof during construction.
1) Installer will coordinate with Site Host when boring or trenching is performed, when laydown areas are determined, when major shipments are planned, or any other activities that might impact Site Host's operations.
m) Installer shall correctly torque all such equipment or assemblies requiring torque and mark torqued bolts to designate status of having been torqued. Site Host or Site Host's representative may at any time request a test of marked bolts. Failure of a bolt designated as torqued to show that torque may require all assemblies to be re -torqued in the presence of a third -party inspector — such inspector to be paid for by Installer. n) Installer shall maintain a clean and workmanlike construction site. Loose debris and unsafe conditions shall not be tolerated at any time.
o) Installer is responsible to obtain all necessary Site data, perform all required investigations and reasonably determine all Site data required for the design and construction of the Systems at their sole cost.
p) Installer shall be responsible for the removal and disposal of all excess soil and construction related debris generated by Installer or subcontractors in accordance with applicable law.
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q) Appropriate safety signs are required to caution drivers for speed or path restrictions near equipment pads.
r) Signage shall be provided at all drive aisle locations that coincide with a Solar Facility shade structure clearly indicating the clearance height of all shade structures. s) Safety bollards or traffic pylons with reflective strips shall be installed where any part of the Project is adjacent to a road.
t) Safety bollards or traffic pylons with reflective strips shall be installed at the corners of ground mounted Solar Facility and around all electrical equipment pads. u) Signs and barricades shall be provided and maintained by Installer and shall be in accordance with jurisdictional regulations for accident prevention and in accordance with the Site Safety and Security Plan.
v) Installer shall ensure to reasonable extent and availability of installation space that solar structures are built away from the line of sight of neighboring properties, where applicable.
w) Where applicable, installer shall identify and remove trees that would cause shading and reduce production of Solar Facility or are in direct path of construction. Installer shall mark each tree and review with Site Host and Arborist prior to removal. Installer shall remove the tree stump, grind to twelve inches (12") below grade and provide a surface flush with surrounding grounds using the same material as the surrounding area.
x) Where applicable, installer shall remove light posts (including complete concrete bollards and rebar cages above and below grade) and other non -building fixtures that would cause shading and reduce production of Solar Facility. Where light post removal is required, Installer shall mark each light post and fixture and review with Site Host prior to removal. After removal of the light post, Installer shall electrically secure the termination point at ground level in an H-20 rated concrete handhole with cast iron or galvanized steel lid. Lids shall be bolted or welded in place with a permanent marking such as "ELEC" or "LIGHTING" on the lid. Installer shall use best efforts to remove the light posts and deliver to Site Host at the Project Site in existing condition so Site Host can re -install in other areas.
y) Installer shall verify all required clearances in the field prior to construction and is solely responsible therefor.
z) Driveways in parking lots must stay open during construction. Any parking lot driveway closure must be temporary (i.e., a few hours for heavy material delivery) and shall be coordinated with Site Host.
aa) Installer is responsible for providing drinking water and sanitation facilities for all workers.
bb) Where applicable, temporary power for construction shall be arranged and paid for by Installer.
cc) Installer must apply for fire hydrant meter permit and cover all expenses for construction water use where applicable.
dd) For water district sites, Site Host has the option to supply a fire hydrant meter providing recycled water for use by Installer for construction water use where applicable.
Installer shall be responsible to provide means of pumping, piping, transport, etc. for such water from Site Host supplied fire hydrant meter to the construction area. ee) All cut edges of galvanized strut or other support structure materials shall be cold galvanized.
ff) Saw cut concrete shall be replaced joint to joint and match nearby area. gg) Installer shall backfill all trenches with engineered fill and compact to 95 percent minimum.
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hh) All asphalt cuts shall be made in square or rectangular cuts to avoid inconsistent repair work. Installer shall cover asphalt trenches with hot mix asphalt, roll for compaction, and cover the width of the trench with a slurry seal after the cure period. All repairs shall be made to match existing. Any repainting of striping required to return the site to original or better conditions shall be the sole responsibility of Installer. ii) Installer shall reseed or provide sod for all areas where existing grass was damaged. 6j) Installer shall conduct harmonic testing and install necessary line filters if Site Host or the Distribution Utility detects electromagnetic interference (EMI) following the installation of the Systems. Detection of EMI includes noticeable power interruptions in previously functional electrical equipment.
7. FINAL PROJECT CLOSEOUT
Closeout Activities
Prior to completion of work at any Site, Installer will perform the following tasks:
Complete all unfinished work described on a punch list approved by Site Host in a timely manner.
Complete final clean-up of each Site, which shall include a thorough washing of the solar PV panels for Solar Facilities. All solar PV panel washing shall be completed in accordance with the manufacturer's recommendations.
Confirm minimum 30-day continuous operation for the entire system, all sub -systems, and ancillary equipment without downtime following the final commissioning for projects.
Assemble and provide Site Host with the Final Binder containing all documents outlined below and all other required submittals.
Provide training for Site Host personnel on emergency shut -down procedures as well as standard inverter restart procedures.
Demonstrate the successful operation of the Microgrid while disconnected from the Distribution Utility grid where applicable.
Final Binder
A complete set of Project documentation in digital format, unless otherwise noted below, shall be provided to Site Host at the finish of construction for record keeping purposes (the "Final Binder').
The Project documentation shall include, at a minimum, the following documents:
Copy of executed Agreement(s) and all amendments
Copy of the Notice to Proceed to design
Copy of the Notice to Proceed to construction
Copies of all reports and studies completed, including but not limited to:
o Underground Utility Surveys
o Title Reports / ALTA Surveys
o Geotechnical Studies
o Environmental Studies
o Bore logs including GPS location coordinates and depth dimensions for all Project underground utilities
o Glint and Glare study
o Arc Flash / Coordination Study
Final design drawings as approved by any Governmental Authorities having jurisdiction over the Project in PDF and AutoCAD
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Copy of all Governmental Approvals required for the Project to be constructed Copy of all Governmental Approvals required for the Project to be operational Letter to the Distribution Utility requesting final inspection in advance of Permission to Operate
Completed Commissioning Report - Attachment D
Permission to Operate notice from the Distribution Utility All incentive related documents
All final executed Distribution Utility agreement(s) — interconnection, special facilities, etc.
As -built drawings in PDF and AutoCAD
Equipment data sheets, installation & user manuals, and warranties for all Major Equipment including but not limited to Solar Facility modules, Solar Facility module mounting systems, inverters, batteries, transformers, controllers and monitoring systems Final System Site Assessment Table in PDF and MS Excel formats Where applicable, final Battery System performance modeling report in 4x8760 output file in MS Excel format
Where applicable, final Solar Facility PVsyst modeling in PDF and 8760 MS Excel format Where applicable, final system performance report detailing the Critical Loads and Estimated Microgrid Operation Duration
Final punch list showing proof of completion of all items Letter stating Commercial Operation Date achievement and date Contact Information for all key Installer personnel including:
o Installer's name
o Installer's main office mailing address, phone, fax, and email o Employer Identification Number ("EIN'
o Installer's main contact person's name, job title, mailing address, phone number, fax number, and email
o Operations and Maintenance contact person's name, job title, mailing address, phone number, fax number, and email
Two (2) sets of keys to all locks, equipment, enclosures, fence gates and boxes Operations and Maintenance manual
Site Host training completion date, including list of personnel trained in inverter shutdown and restart procedure
Monitoring system information including:
o Monitoring system hardware and internet portal specification sheets o Meter calibration records with serial numbers for all meters o Website access and operation instructions
o List of public monitoring websites
o IP addresses and login information of the data logger o Network configuration documentation
o PMRS installer contracts
Site photographs of all items listed below (electronic version only):
o Solar Facility arrays, where applicable
o Batteries, where applicable
o Inverters
o Combiner boxes
o Transformers
o Disconnects
o Panelboards/switchgear
o Motorized circuit breakers, where applicable
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o Electrical point of connection to existing distribution equipment o Distribution Utility meter
o Battery System Meter, Facility Load Meter, Critical Load Meter, Solar Production Meter and any other meters, where applicable
o Battery System controller, where applicable
o Microgrid controller, where applicable
o Monitoring equipment including weather sensors where applicable
8. OPERATIONS AND MAINTENANCE
Installer shall be responsible for all operations and maintenance of the Systems if included in the Agreement. The operations and maintenance shall include at a minimum:
A. All preventative maintenance required to maintain all equipment warranties.
B. Installer shall provide erosion control, weed abatement, and security for the Site throughout the Term at their sole expense.
C. Ground mounted arrays shall include the application at the completion of construction and as required through the Term of the Agreement of a dust control polymer additive coating within the Solar Facility area to limit solar PV panel soiling.
D. Installer shall maintain one complete Engineering Design Package throughout the Term of the Agreement and update with any changes made from the as -built drawings provided at the completion of construction.
E. A minimum of one annual solar PV panel washing shall be required at all sites if operations and maintenance is included in the Agreement. The timing of the washing(s) shall be coordinated with Site Host to ensure beneficial production impact.
F. Where painted steel is used for the structural components of the array, Site Host shall be provided with a hex color code and an adequate amount of touch up paint to address minor aesthetic maintenance.
34
ATTACHMENT A - PRELIMINARY ENGINEERING DESIGN PACKAGE
TO GENERAL CONDITIONS AND TECHNICAL SPECIFICATIONS
35
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GENERAL NOTES:
PROCEDURAL NOTES:
P1. PRIOR TO COMMENCEMENT OFANY WORK, THE CONTRACTOR SHALL NOTIFY
HOLT OFANY DISCREPANCIES DISCOVERED BETWEEN THESE PLANS AND THE SITE CONDITIONS: SUCH AS DIMENSIONS, EXISTING CONDITIONS, STRUCTURE,
ELECTRICAL RUNS (SPECIFY EXISTING ITEMS), WALLS, PARAPETS, FLASHING,
MANUFACTURER RECOMMENDATIONS OR CODES, REGULATIONS OR RULES OF AHJ.
P2 ALLDIMENSIONS OR EXISTING CONDITIONS MUST BE VERIFIED PRIOR TO COMMENCING WORK.
P3. THECONTRACTOR IS RESPONSIBLE FOR ALL BRACING AND SHORING OF EQUIPMENT DURING INSTALLATION.
P4. CONTRACTOR SHALL BE RESPONSIBLE FOR ALL SAFETY PRECAUTIONS. OSHA
REQUIREMENTS AND SAFETY MEASURES ON SITE THE ENGINEER HAS NO
OVERALL SUPERVISORYAUTHORITY AND NO DIRECT RESPONSIBILITY FOR THE SPECIFIC WORKING CONDITIONS OR FOR POSSIBLE EXISTING HAZARDS.
P5. CONTRACTOR QUESTIONS SHALL BE SUBMITTED TO HOLT PRIOR TO MAKING ANY CHANGES. HOLTWILL PROVIDE RFTS TO ENGINEER AND PH RESPONSES TO CONTRACTOR AS REQUIRED. ALL DOCUMENT CONTROL WILL BE ADMINISTERED BY HOLT.
GENERAL NDTES:
GI. ALLWORK SHALL BE PERFORMED IN A SAFE, EFFICIENT, AND WORKMAN LIKE MANNER
G2. THE ELECTRICAL CONTRACTOR IS RESPONSIBLE FOR INSTALLING ALL EQUIPMENT
AND FOLLOWING ALL MANUFACTURER'S OR ENGINEER'S DIRECTIONS AND INSTRUCTIONS SHOWN HERE.
G3. THE ELECTRICAL CONTRACTOR IS ADVISED THAT ALL DRAWINGS, COMPONENT MANUALS, ESPECIALLY THE INVERTER MANU ALS.RGIZI TOBEREAD UIPUNDERSTOODPRIORTOINSTALLATIONORENERGIZINGOFANYEQUIPMENT. THE
CONTRACTOR IS ALSO ADVISED TO HAVE ALL COMPONENT SWITCHES IN THE OFF
OPEN) POSITION AND FUSES REMOVED PRIOR TO INSTALLATION OF FUSE -SEARING COMPONENTS.
64, INSTALLATION CREW IS TO HAVE A MINIMUM OF ONE JOURNEYMAN LEVEL
ELECTRICIAN PER THREE APPRENTICES ON SITE AT ALL TIMES WHEN ELECTRICAL WORK 15 BEING PERFORMED.
BE. CONTRACTOR SHALL HAVEA NABCEPCERTIFIED INSTALLER DIRECTLY SUPERVISE ALL PV SYSTEM INSTALLATION WORK.
GB. FOR SAFETY IT IS RECOMMENDED THE INSTALLATION CREW ALWAYS HAVE MINIMUM OF TWO PEOPLE WORKING TOGETHER.
G7. THIS SOLAR PHOTOVOLTAIC SYSTEM SHALL BE INSTALLED FOLLOWING THE CONVENTIONS OF THE DEC. ANY LOCAL CODE WHICH MAY SUPERSEDE THE CEC SHALLGOVERN.
GB. ALL COMPONENTS TO BE INSTALLED WITH THIS SYSTEM ARE TO BE USTEO BY THIRD PARTY TESTING AGENCY (UL ETL, ETC.). EQUIPMENT SHALL BE NEMA 3R OUTDOOR RATED OR BETTER, UNLESS LOCATED INDOORS.
G9. THE ENGINEER SPECIFIES THE MINIMUM REQUIRED EQUIPMENT AND
SPECIFICATIONS TO ACCOMPLISH THE PROJECT AND THE ELECTRICAL
CONTRACTOR IS RESPONSIBLE TO ENSURE THAT THESE SPECIFICATIONS ARE
MET OR EXCEEDED WITH GOOD QUALITY EQUIPMENT, WORKMANSHIP AND SKILL G10. DC VOLTAGE FROM THE ARRAY IS ALWAYS PRESENT AT THE OC DISCONNECT
ENCLOSURE AND THE OC TERMINALS OF THE INVERTER DURING DAYUGHT HOURS. ALL PERSONS WORKING ON OR INVOLVED WITH THIS PHOTOVOLTAIC
SYSTEM MUST BE WARNED THAT SOLAR MODULES ARE ENERGIZED WHEN EXPOSED TO DAYLIGHT. THE LINE AND LOAD TERMINALS ON THE DC
DISCONNECTS MAY BE ENERGIZED IN THE OPEN POSITION AND THE SWITCH IS TO BE LABELED TO COMPLY WITH ARTICLE 690.17 OF THE DEC.
G71. ALL PORTIONS OF THIS SOLAR ELECTRIC SYSTEM SHALL BE CLEARLY MARKED IN ACCORDANCE WITH CEC ARTICLE 690.
G12 FOR PROPER MAINTENANCE AND ISOLATION OF INVERTERS, REFER TO ISOLATION PROCEDURE IN INVERTER OPERATION MANUAL. CONTRACTOR PERFORMING THE MAINTENANCE IS RESPONSIBLE TO FOLLOW ALL LOCKOIIUTAGOUT PROCEDURES.
G13 THIS PHOTOVOLTAIC SYSTEM UTILITY INTERCONNECTION POINT SHALL MEET THE SPECIFIC REQUIREMENTS OF DEC ARTICLE 705.12. FOLLOW THE SPECIFIC INSTRUCTIONS IN THIS DRAWING SET TO MEET THIS CODE REQUIREMENT.
G14. THEO OUNDING OF THE PHOTOVOLTAIC SYSTEM SHALL COMPLY WITH DEC 690.45 AND DEC 690.47. IF THE REQUIREMENTS DESCRIBED IN THIS DRAWING SET
ARE CLOSELY FOLLOWED, THE GROUNDING REQUIREMENT SHALL BE MET, ANY
CHANGES SHALL BE REVIEWED AND DEEMED ACCEPTABLE BY THE ENGINEER, MANUFACTURER AND LISTING AGENCY FOR PRODUCT SAFETY.
G15. TESTING AND COMMISSIONING WITH HOLT. .
G16. THE CONTRACTOR IS RESPONSIBLE FOR MOUNTING ALL EQUIPMENT PER THE ENGINEER'S REPORT OR MANUFACTURER'S SPECIFICATIONS. IF SPECIFICATIONS
ARE NOT APPARENT, THE CONTRACTOR SHALL USE DINGENT EFFORTS TO
MOUNT EQUIPMENT SUCH THAT IT WILL BE CLEAN, LEVEL AND SOLID IN ORDER TO LAST THE LIFETIME OF THIS SOLAR ELECTRIC SYSTEM.
G17. ANY METAL SHAVINGSRESULTING TRESUGFROM0SITE WORKALL CLEANED FROM
ENCLOSURE INTERIORS TOP SURFACES OF ENCLOSURES, THE GROUND
SURFACE ROOFS AND ANYSHAVINGS MAY AL AREAS WHERE OXIDIZED ORCONDUCTIVEMETALSHAVINGSMAYCAUSERUST, ELECTRICAL SNORT CIRCUITS - OR OTHER DAMAGE.
GIB, THE ELECTRICAL CONTRACTOR SHALL CONSI DER THE WEATHERING OF EQUIPMENT OVERTIME AND ELIMINATE 7HE POSSIBILITY OF DEGRADATION OF EQUIPMENT DUE TO WATER ENTRY AND UV EXPOSURE. AS A RESULT, HOLT
REQUIRES THE USE OF UNISTRUT OR SIMILAR MOUNTING SYSTEMS TO MOUNT ENCLOSURES, PULL BOXES. LOAD CENTERS, FUSE BOXES OR OTHER EQUIPMENT TO ROOFTOPS AND WALLS TO PREVENT WATER BUILD-UP. WEEPHOLESSHALL
NOT BE PROVIDED IN ENCLOSURES THAT WOULD CAUSE A REDUCTION IN THE ENCLOSURESNEMA RATING. SEALING CONDUIT WITH A FIRE RETARDANT FOAM OR
CAULK AT ENCLOSURE ENTRY POINTS IS RECOMMENDED TO MINIMIZE CONDENSATION AND PESTS IN ENCLOSURES. FOR CONDUIT LOCATIONS RUNNING THROUGH
WALLS FIRE RETARDANT FOAM OR CAULK MUST BE USED TO MAINTAIN THE CURRENT FIRE RATING OF THE WALLAND MUST COMPLY WITH UL 1479 A UL 723 STANDARDS FOR THROUGH PENETRATIONS. G19. ALL
MATERAL SHALL BE NEW AND RATED FOR UV EXPOSURE WHERE EXPOSED TO SUNLIGHT. G20.
CONSTRUCTION
STAGING OF CONCENTRATED LOADS ON ROOF SHALL BE MINIMIZED. SPECIAL
ATTENTION SHALL BE PAID TO ROOF LOADING DURING INSTALLATION SUCH
THAT HEAVY ITEMS ARE NOT LOADED IN A MANNER THAT WOULD OVERLOAD THE ROOF. G21. CONTRACTOR
SHALL COORDINATE SOLAR ARRAY INSTALLATION WORK WHERE MINIMAL DAMAGE
OCCURS TO LANDSCAPE CONTRACTOR SHALL RESTORE ALL DAMAGED LANDSCAPE TO ORIGINAL CONDITION. G22. CONTRACTOR
SHALL RESTORE INTERIOR/EXTERIOR FINISHES TO ORIGINAL OR BETTER CONDITION.
G23. EXISTING
TREES REMOVED AS PART OF CONSTRUCTION SHALL HAVE THEIR STUMPS GROUND T012' BELOW GRADEAND COVERED WITH NATIVE TOPSOIL TOPSOIL SHALL BE FILLED AND COMPACTED TO MATCH EXISTING GRADE. G24. PROVIOEAND
INSTALL GROUNDING TYPE BUSHING WITH GND WIRETO ENCLOSURE ON ALL CONCENTRIC OR ECCENTRIC KNOCKOUTS. ELECTRICAL NOTES:
E1. NEVERY
PULL BOX, TERMINAL BOX, AND AT ALL PLACES WHERE CONDUCTORS MAY NOT
BEREADILY IDENTIFIED BY NAMEPLATE MARKINGS ON THE EQUIPMENT TO WHICH THEY CONNECT. IDENTIFY EACH CIRCUIT WITH A PLASTIC LABEL OR TAG FOR NUMBER, POLARITY OR PHASE. E2 THE
LAYOUT OF CONDUIT SHOWN IN THESE PLANS IS INDICATIVE ONLY. CONTRACTOR SHALL
ROUTE AND LOCATE THE CONDUITS TO SUIT SITE CONDITIONS BUT
SHALL NOT EXCEED THE MAXIMUM CONDUCTOR LENGTHS IDENTIFIED ON THE CONDUCTOR SCHEDULE. CONTRACTOR SHALL COORDINATE ALL CHANGES IN CONDUCTOR AND CONDUIT WITH THE ENGINEER VIA AN RFI. E3. WHERE
CONDUCTOR AND CABLE ROUTING IS NOT SHOWN, AND DESTINATION ONLY IS INDICATED, CONTRACTOR SHALL DETERMINE EXACT ROUTING AND LENGTHS REQUIRED.
A SHOP DRAWING OF PROPOSED INSTALLATION SHALL BE SUPPLIED PRIOR TO INSTALLATION. E4. BENDSSHALL
NOT DAMAGE THE RACEWAY OR SIGNIFICANTLY CHANGE THE INTERNAL DIAMETER OF RACEWAYS (NO KINKS). ES SUPPORTCONDUCTORS
IN VERTICAL CONDUITS IN ACCORDANCE WITH REQUIREMENTS IN DEC 30D.19. EB INSTALL
ALL CONDUCTOR MATERIALS INA NFATWORKMANUKE MANNER. USE GOOD TRADE PRACTICES AS REQUIRED BY CHAPTER 3 OF THE DEC. E7. INSTALL CONDUIT TO MAINTAIN PROPER CLEARANCES AND IN A NEAT INCONSPICUOUS MANNER.
RUN PARALLEL AND AT RIGHT ANGLES TO STRUCTURAL MEMBERS
OR OTHER CONDUITS. PROVIDE BOXES, FITTINGS AND BENDS FOR CHANGES IN DIRECTION. FASTEN CONDUIT SECURELY IN PLACE. E8. SUPPORT CONDUIT USI NO STEEL PIPE STRAPS(OAE), LAY4N ADJUSTABLE HANGERS, CLEWS HANGERS OR SPLIT -HANGERS. HANGER SPACING SHALL BE INSTALLED PER CEC REQUIREMENTS FOR THE TYPE OF CONDUIT BEING INSTALLED. USE APPROVED BEAM CLAMPS FOR CONNECTION TO STRUCTURAL MEMBERS. E9.
PROVIDE
PULL,JUNCTION, OR CHRISTY BOXES WHERE REQUIRED TO FACILITATE THE INSTALLATION OF CONDUCTOR IN ADDITION TO THOSE SHOWN ON THE DRAWINGS. BENDS
IN CONDUITS BETWEEN PULL BOXES SHALL NOT EXCEED THE EQUIVALENT OF FOUR 90 DEGREE BENDS EID. RACEWAY
N EXPA CONTRACTIONSHALLREINSTALLED TO ALLOW FOR .7(6). THERMAL EXPANSIONANDCONTRACTIONWHERENECESSARY, PER DEC 300CES MANUFACTURER INSTRUCTIONSSHALLBEFOLLOWEDANDALLACCESSORIESSHALLBE INSTALLED TO ENSURE PROPER FUNCTIONING OF FITTINGS. E71. WHEN FIELD CUTTING IS REQUIRED, THE CONDUIT SHALL BE CUT SQUARE AND DEBURRED. E12.
CONDUIT
SIZES NOT SPECIFIED SHOULD CONFORM TO CEC SPECIFICATIONS, TO INCLUDE FILL FACTOR AND DERATING FOR NUMBER OF CONDUCTORS. E73, THE
POWER CONDUCTORS MINIMUM SIZE SHALL BE#12 AND. E14. SAFETY REGULATIONS (LOCK OUT. TAG OUT, ETC.) IS THE FULL RESPONSIBILITY OF THE CONTRACTOR DURING CONSTRUCTION. E75. THE
CONDUCTOR SIZE IS BASED ON THE ESTIMATED CONDUIT ROUTING AS SHOWN IN
THIS DRAWING PACKAGE SHOULD THE CONDUITS LENGTH INCREASE DUE TO
RELOCATION OF SOURCE ANDIOR ROUTING, THE CONDUITS AND THE CONDUCTORS MAY NEED TO BE RESIZED. SUBCONTRACTOR SHALL CONTACT HOLT PRIOR TO MAKING ANY FIELD CHANGES. E16. ALL
CONDUCTORS IN CONDUIT SHALL BE THWN2. XHHW-2, RHW-2,PVWIRE, OR XLPE. USE BARE COPPER FOR GROUND FOR ALL EXTERNAL GROUNDING. PVWIRE OR APPROVED EQUIVALENT SHALL BE USED FOR ALL EXPOSED OR HOMERUN CONDUCTORS. E17.
FOR
INTERCONNECTION VIA BUS TAP: A. OVERCURRENT
PROTECTION (SWITCHING DEVICE AND MEANS OF DISCONNECT)MUST BE LOCATED PER DEC 24021. 8. THE
CONDUCTORS SHALL BE CRIMPED WITH A CRIMPCN TERMINAL LUG, MANUFACTURED BY ILSCO, BURNDY, ONE. THE TERMINAL LUG SHALL HAVE IDENTIFICATION OR COLOR CODING TO MATCH THE CONDUCTOR SIZE. TERMINAL LUGS SHALL HAVE LONG BARRELS TO PROVIDE 2 CRIMPS PER TERMINAL LUG PER CONDUCTOR C. CRIMPEOTERMINAL
LUGS SHALL BE CONSTRUCTED OF PURE COPPER AND TIN-PLATED FOR HIGH CONDUCTIVITY AND RATED FOR 600V AT 90°C WHEN USED WITH COPPER CONDUCTORS. D, THECRI
MPMUST BE MADE WITH THE MANUFACTURER'S APPROVED TOOL DEVICE TO ACHIEVE THE PROPER CRIMP CONNECTION. E. USE
STAI NLESS STEEL HARDWARE WITH THE FASTENER TORQUED TO MANUFACTURER'S
RECOMMENDATIONS ON ALL THREE PHASES TO COMPLY WITH ARTICLE 110.14 OF THE CEC. F. MINIMUM
BEND RADIUS SHALL BE OBSERVED TO MAINTAIN GOOD CONDUCTOR QUAUTY
AND CONDUCTOR MANAGEMENT IN THE LOAD CENTER OR
TRANSFORMER IF THIS BEND RADIUS IS TOO CONSTRICTING, USE A 90'CRIM1-ON LUG MANUFACTURED BY ILSCO, BURNDY, ONE. 90° CRIMP -ON
LUG MUST BE INSTALLED WITH RATED INSULATION THAT MEETS OR EXCEEDS THE CONDUCTORS' INSULATION R IS BEING USED WITH. IT IS RECOMMENDED THAT
ACCEPTABLE CLEARANCES ARE MAINTAINED WITH THIS BUS
TAP FOR SAFE, CONTINUOUS OPERATION . G. FOLLOW
MANUFACTURER'S GUIDEUNES, OR THE APPLICABLE AHJ, FOR MODIFICATION OF BUS BAR(S). E78. ALL
CONDUITS SHALL BE FREE OF ANY OBSTRUCTIONS AND PROPERLY SECURED BEFORE CONDUCTOR IS PULLED. E19. ELECTRICAL
CONTRACTOR SHALL PROVIDE SIGNAGE TO ALL ELECTRICAL BOXES, JUNCTION BOXES,
PULL BOXES, OC DISCONNECTS, CONDUIT RUNS, AC DISCONNECTS, SUB PANELS AND MAIN SERVICES PER CEC ARTICLE 690. E20. THE
ELECTRICAL CONTRACTOR SHALL PERFORM INITIAL HARDWARE CHECKS AND CONDUCTOR CONDUCTMTY CHECKS PRIOR TO TERMINATING ANY CONDUCTORS. COMPLETE
MEGGER (INSULATION RESISTANCE) TESTING IN REFERENCE TO
GROUND AND TO EACH CONDUCTOR IN THE SAME CONDUIT ON ALL AC AND DC POWER CONDUCTORS. VERIFY AND DOCUMENT RESISTANCE OF AT LEAST 1DOM0 ON EACH CONDUCTOR USING 1009V RAMP -UP TEST FOR ONE MINUTE. OO NOT MEGGER THE SOLAR MODULES. MEGGERING IS INTENDED FOR ALL POWER CONDUCTORS INSTALLED BY THE ELECTRICAL CONTRACTOR. E21. ENSURE
THAT ANY EXISTING LIGHTNING PROTECTION AIR TERMINALS EXTEND MINIMUM OF 10' ABOVE THE TOP OF THE PV MODULES. THIS CAN BE ACCOMPLISHED BY
EXTENDING THE EXISTING AIR TERMINAL OR BY INSTALLING NEW, TALLER AIR TERMINAL WITH RATINGS EQUIVALENT TO THE EXISTING AIR TERMINAL E22.
TORQUE:
ALL CONDUCTORS LANDING W SCREW CONNECTIONS MUST BE PROPERLY TIGHTENED
TO THE MANUFACTURER'S TORQUE REQUIREMENTS, ALL BOLTED CONDUCTOR
TERMINATIONS MUST BE TORQUED TO THEIR RATED VALUE IT IS
THE SUBCONTRACTOR'S RESPONSIBILITY TO ENSURE ALL CONDUCTORS WITH TORQUE
REQUIREMENTS HAVE BEEN MARKED WITH PAINT PEN OR PERMANENT MARKER AT THE TIME THAT THE TORQUE TEST WAS DONE E23. ALL
METALLIC ENCLOSURES SHALL BE GROUNDED PER DEC ART. 250. E24. EQUIPMENT USED HALLBERATED FOR THE ENYIRONRIENT IN WHICH IT IS BEING INSTALLED O.
E.NEMA 1 3R 4 4% 12 . E25. CONTRACT
OR SHALL COMPLY WITH THE GENERAL DC CONDUCTOR CONDUIT MAX FILL OUTLINED IN THE TABLE BELOW, A SINGLE #6 THWW2 EGO HAS BEEN INCLUDED IN THE FILL CALCULATIONS. lDAWOPVWJIT CONDUIT
FILL CONDTBILE EMT
IMC RMC PVC40 HOPE. LFMC 314' 2
3 2 2 2_ 2 5 5
5 4'- y - - 5- 10.- __ B -
9. - 1-112° -- -
15 14 - 13-- _-_12 12 _12_ 22 24
22 22 22 21 45 34
33 31 31 33 US. CONTRACTOR
SHALL NOT USE IMPACT DRIVERS ON INVERTERS ORWIRING BOXES. ROOFING AND SEALING NOTES: (IF APPLICABLE) R7. A
POLYURETHANE BASED ADHESIVE SHALL BE APPLIED TO ANY DRILLED HOLE FOR FASTEMONG.
R2. ALL
STANDOFFS SHALL BE MADE WATERTIGHT USING APPROVED METHODS BY THE ROOFING MATERIAL MANUFACTURER, DISTRIBUTOR OR ENGINEER OF RECORD, R3.
CONTRACTOR
SHALLBE RESPONSIBLE FOR PROVIDWGANYTRANSITON MATERIAL WHERE DIFFERENCE OF 14' OF HEIGHT OR MORE BETWEEN THE ROOF AND STANDOFF BASE. R4. CONTRACTOR
SHALL BE RESPONSIBLE FOR INSTALLATION OF RIGID FOAM OR SPRAY FOAM
TO FILL ANY VOID AROUND THE STANDOFF, FROM THE BASE UP TO VABOVE THE ROOF. MODULE INSTALLATION
NOTES: M7. REFER
TO THE MODULE MANUAL FOR DETAILS ON RIGGING. UNPACKING, HANDLING, PLANNING, AND INSTALLATION. M2. THE
MODULES MAY BE SHIPPED WITH SEVERAL MODULES PER BOX TAKE CARE WHEN OPENING THE BOX TO ENSURE THAT ALL MODULES ARE SECURELY HANDLED. M3.
NEVER
LEAVE A MODULE UNSUPPORTED OR UNSECURED. CONTRACTOR IS RESPONSIBLE FOR ALL MATERIAL HANDLING ON THE JOB SITE. GENERAL SAFETY
NOTE: THE ARRAY
LAYOUT INCORPORATES DESIGN CONSIDERATIONS SET -FORTH BY THE CALIFORNIA DEPARTMENT OF FORESTRY AND FIRE PROTECTION, THE CFC AND THE IFC. THESE GUIDEUNES
INCLUDE OFFSETS AND AISLE -WAYS TO ACCOMMODATE MOVEMENT ACROSS THE ROOFTOP IN THE EVENT OFAFIRE. THERE ARE ALSO CONSIDERATIONS FOR MAXIMUM DIMENSIONS OF A CONTINUOUS ARRAY OR SUBARRAY. SINCE PHOTOVOLTAIC PV) SOURCE
AND OUTPUT CIRCUITS WILL BE ENERGIZED AS LONG AS THERE IS VISIBLE LIGHT, LABELING IS SPECIFIED IN THE PLANS TO DISTINGUISH PV CONDUITS FROM EXISTING SITE CONDUIT.
BEYOND CAL -FIRE, THESE PLANS INCORPORATE OCCUPATIONAL SAFETY AND HEALTH ADMINISTRATION (OSHA) GUIDELINES. THIS MAINLY PERTAINS TO MINIMUM OFFSETS FROM PARAPETS OR THE ROOF EDGE. ELECTRICALLY, THE
DESIGN SHALL MEET ALL EQUIPMENT WORKING CLEARANCES AS DIFINED IN DEC ARTICLE 110.26 AS WELL AS CAREFUL CONSIDERATION OF EGRESS PATHS WHEN EQUIPMENT DOORS ARE OPENED. EQUIPMENT ELEVATION DRAWINGS INCORPORATE TRUE -SCALED
DIMENSIONS OF TRAOESVE CONDUIT BODIES AND SWEEPS TO ENSURE PROPER CONDUCTOR BEND RA0II. THIS MEASURE WILL ENSURE THAT THE CORRECT CONDUIT FITTING WILL FIT THE ALLOTTED SPACE. FURTHER, ALL EQUIPMENT SPECIFIED SHALL BE USTED BYA NATIONALLY RECOGNIZED TEST LAB ILL IEEE, ETC.). THE PLANS
ALSO INCORPORATE EQUIPMENT AND GROUNDING DETAILS TO ENSURE PROPER INSTALLATION
AS WELL ASA COMPLETE SHEET OF THE REQUIRED LABELS AND MARKINGS, THE
LABELS ADDRESS PERTINENT ARTICLES OF THE DEC AS WELL AS STANDARDS ADOPTED
FROM PAST PROJECTS WITH VARIOUS UTILITY COMPANIES AND LOCAL AUTHORITIES HAVING JURISDICTION. 1301 Cp.
0 TX Hvy S MIS AuIh, TX
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n G1003
3 >, (
1202) MODULES (2DUMMIE5)
2) CHINT INVERTERS
1 CHIM AC COMBINERS
s= XE0. LTGROUND MOUNFlTIt n
Y,.
i -
s s
x 11800) MODULES (O DUMh9ES)
PV SOLAR SYSTEM SUMMARY
TOTAL MODULE COUNT) MODULE MANF.O MODEL NUMBER ISTC DC RATING 3000 OCELLS CREAK DUO XUGI IB 31BFG 595 595W PLUS 1101 DUMMY MODULES
TOTAL STRINGS OF MODULES PER STRING 120 STRINGS OF 25 MODULES PV ARRAY RACKING STYLE I MANUFACTURER AND MODEL FIXED -TILT GROUND MOUNT!TERRASMART GLIDE AGILE TOTAL STC DC SYSTEM SIZE 17BS.00 kW
TOTAL INVERTER COUNT) INVERTER MANE. AND MODEL 5)CmNT CPS SCH275KLT-DOIUS-800-36.250kW AC INVERTER CEC EFFICIENCY 985%(275k"
SITE LATITUDE 38' 16' 33' N
ARRAY AZIMUTH MODULE TILT 180°/20° -
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TX 787d6 E
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NAMES AND NUMBERS TO BE INDICATED ON a INIV.OS 12II
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UTILITY METER LABELED 'PHOTOVOLTAIC SYSTEM ARRESTOR- GROUND ROD MONITOR.'
CT COMPARTMENT
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THE MODULE MANUFACTURER OR ARTICLE 338.24, WHICHEVER
IS MORESTRINGENT, y VIMNO 11. MATING
CONNECTORS FOR PV SOURCE CIRCUITS, PV A JUMPER CABLES, AND
MODULE LEVEL POWER ELECTRONICS TO BE LISED
AND IDENTIFIED FOR INTERMATABIUTY, AS DESCRIBED IN MANUFACTURER'$ INSTRUCTIONS. MATING g a CONNECTORS THAT ARE
NOT LISTED ARE NOT TO BE UTILIZED FOR PROJECT.
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SHEET NOTES HOLT' mow'?
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CONOUITABOVE GRADE SHALL BE EMT. ALL CONDUIT BELOW GRADE SHALL BE PVC OR HOPE VATH RMC RISER. USE SCHEDULE
40 FOR BELOW GRADE CONDUIT RUN UNDER GRASSY
AREAS. 1301 Cap. 0 TX Hwy S 411315 ANK
TX 78746 2,
ALL COPPER(CUI CONDUCTORS IN CONDUIT SHALL BE THWN-
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TORQUE: ALL CONDUCTORS LANDING IN SCREW CONNECTIONS
MUST BE PROPERLY TIGHTENED TO THE MANUFACTURER'
S TORQUE REQUIREMENTS. ALL BOLTED FOR REWEW ONLY CONDUCTOR
TERMINATIONS MUST BE TORQUED TO THEIR RATED
VALUE. IT IS THE SUBCONTRACTOR'S NOT FO0. RESPONSIBILITY
TO ENSURE ALL CONDUCTORS WITH CONSTRUCITON TORQUE
REQUIREMENTS HAVE BEEN MARKED WITH A PAINT PEN
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SOIARENERGY PRODUCTICNMONITORINGSHALLSE INSTALLED
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IMPACT DRIVERS ARE NOT APPROVED FOR USE ON INVERTERS
OR WIRE BOXES. 0
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LABELED 'PHOTOVOLTAIC SYSTEM ACCOMBINER- S.
UTILITY METER LABELED'PHOTOVOLTAIC SYSTEM FL MONITOR'
CT COMPARTMENT PER EUSERC 31Z 330. METER 1.
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TO BEVISUAL OPEN AND ACCESSIBLE AND N
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DISCONNECT ALL SOURCES BEFORE SERWCINW B.
POWTOFINTERCONNECTION SHALL BE IN ACCORDANCE B WITH
CEC 705.11. 9.
PROVIDE IDEMIFICATIONALONG WITH POSITIVE A NEGATIVE CONDUCTORS PER CEC 210.5¢1(2). 10.
MINIMUM BENDING RADIUS OF PHOTOVOLTAIC MODULE LEADS
SHALL CONFORM WITH IMMUM BENDING RADIUS A SET
FORTH BY THE MODULE MANUFACTURER OR ARTICLE 33824,
WHICHEVER IS MORE STRINGENT. 11.
MATING CONNECTORS FOR PV SOURCE CIRCUITS, PV JUMPER
CABLES, AND L4000LE LEVEL POWER ELECTRONICS TO
BE USED AND IDENTIFIED FOR INTERMATABIUTY, AS DESCRIBED IN MANUFACTURER'S INSTRUCTIONS. MATING a a CONNECTORS
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AC POWER CONDUITS TO CONVEY (3) CURRENT CARRYING CONDUCTORS AND AN EGC. NO NEUTRAL REQUIRED. a.
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ALL INVERTERS ARE TO HAVE THE MAX 250kW AC OUTPUT ANSIo-mm OPTION SELECTED. REFER TO INVERTER DATA SHEETON SHEET
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GENERAL SHEET NOTES
1. CONDUITABOVE GRADE SHALL BE EMT. ALL CONDUIT BELOW15) CIONT CPS SCH275KTL-0ONSa003fi INVERTERS- 2SOKW AC SELECTED RACKINGSHALLBEUL2703USTEDASANEW 01, iv GRADESRALLSEPVC ORHOPEWITHRMCRISER USE EARE6AWGEGCATTACHEOTORAIL ENDSWITHWEEBLUGS Si.R uE SCHEOULE40 FOR BELOW GRADE CONDUIT RUN UNDER 15MV PVWiREFORALLSOURCEWIRING GRASSYAREAS.
E
BATTERYBAESOCOECSUNSTORAGE SYSTEM REERGYSTORAGESYSTEMSPWR N00•SBCAB114801(SIIJUN20I+OIRIS qG WAREICRQPCS NEMI g410 CU BOND TO
GROUND RING (iYPJ-
1) 3M-X 1W GROUNDING
EXOTHERMIC BOND (TYP) ELECTRODES (TVP OF ALL
GROUND RODS)
ALL CO PER(CU. CONDUCTORSALL BE2. ALLCOPPER(CU)CONDUCTORS CONDUUIT CTORSSHALLB CONDUCTORSSHALLBEE USOCOMECSUNSYSHESL(GCAB+4PWR MOD+S&CAB11480VI(511JUN20I+DINS DIGIWARE ICRD.PCS NEMI iY_I'Razularn_FR 1- _ PVWIRE ALLALUMINUM (AL) CONDUCTORS IN CONDUIT ' SHALL BE XFM.2, OR XLPE I
ESSS
PVSBESSSWRCHGEARISWGR0,1 n„Y ° J. ALUMINUM CONDUCTORS SHALL BE BRUSHED AND TREATED US OA 1 I IiXSTj YlfDi ANTIOXIDANT COMPOUND AT TERMINAL POINTS. GROUND ROD NEMA 3R, 30,4W, 65 KAIC O7
PER CEC B 3 3)() I I'G 4. TORQUE: ALL CONDUCTORS LANDING IN SCREW ENTRY SERVICEENTRY RATED Ex
SUr•la _ O CONNECTIONS
MUST BE PROPERLY TIGHTENED TO THE MANUFACTURER'
S PADMOUNTEDYGSrHE_iCR I M Z TORQUE REQUIREMENTS. ALL BOLTED CONDUCTOR TERMINATIONS MUST BE TORQUED TO THEIR c
IC
IA
I
PVTRANSFORMER
1500kVA,
NEMA 3R, D-YG, Z=
5.75%YJR = 7.5 PAD
MOUNTED TO
PV SWITCHGEAR, K 9B2.5A BOOV 480V 2500A SEESHEETWP601.
01 Bry-0NaPVXFMR.
O, 400V (
BA MCOV) LIGHTNINGARRESTOR
SECTION4-
PV
SERVICE FUSEDDISCONNECT
SECTION
3- PV
METER 4B0V,2500A,30 SECTION
2- BESS
SERVICE BREAKERS
SECTION
I -MAIN BREAKER
MAIN
25OGA5
211DAS 400AF 400AF BREAKER 2500AF
2500AF 430AT 3SDAT 3000AF,30DOAT, 3P
3P 3P 3P ELECTRONIC TRIP, 65kAIC
WITH480V, GFCI PER VIEWING
CEC
230.95 WINDOW
IF O REQUIREDO
BYAHI) M NOON
PERPG&E SPECS
Elcilnl"
as' RATED VALUE. R IS THE SUBCONTRACTOR'S INTERCONNECTION RESPONSIBILITY TO ENSURE ALL CONDUCTORS WITH 2
6 3000AF
I 3000A,
480VAC, 3m TORQUE
REQUIREMENTS HAVE BEEN MARKED WITH A PAINT P
0 3000AT
DETAP
VIA PEN OR
ERMANENTMARKERATTHE TIME THAT THE 2196.9A
3000A 31n4.9a jI 3P
O SOLAR
BOLAR READY70ROVE TEST
WAS GONE TORQUE LSIGBREAKER
SECTION 5. SOLAR ENERGY PRODUCTION MONITORING SHALL BE ACD.af PER CEC 705.11 INSTALLEDATINTERCONNECTION. PV UTILITY
DISCONNECT a'•A AF f D EATON PRWgEBOLTEDPRESSURESWITCHCB3034. 8-12B-0e0G.0AEI <V9AI fi. MAIN
BREAKER
FOR IMPACTORNERS ARE
NOTAPPROVED FOR USE ON 4BOV,3000A
FUSIBLE W/]BOpA FUSES, I SERWCEOF METER INVERTERS OR
WIRE BOXES. NEMA3R,3P,
aW, VUMM.E,LOCKABLE, 2SGDA1 I R1010078883 PAD MOUNTED
WRHW 10 OF INTERCONNECTION mmr
O F-(
Iti IINv 125L1.W P _ cEA
RA1Ds
iar l P II
Fx`snNe,
I ,-- o.usI I
L
1654,
JA 4B0VAG3PH,4W I 4000ABUS. 4000A MA1N(EXST1 GROUND ROD I TO i M701.OA I\I\\\
11SEE
BHFWPW12
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241.0A BUS EE SHEET
WPNH.3 GROUND ROD aN•.
a, s.,
ryA4•u4 Y ww• Am rmm Wt•
J Suit' W rN141 A) A00 u•W Vr,MwIW LmM VU Wb•INw FUGn•• mn4W Trp fmWA duA ww 4aM•R a'wl%1 A 'Str;ngs, 025mo4UhA 0-t-0NVXQ 120 15.E 10.8 25 1447.2 275. C. PV M PVC401REE See E251GIO03 1 10 6 See E25/GXXU 137 AC Aggregation Table XumWrw Fmr4wN Oww4nM •
un•I VMSW Ar••A•
4b w•JVMe H
Ln raMNf4bbNW votY•P'W r..o T•
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ACCAT -
ACRC.
Ol --'-M 0.99 RIS8.5 A
397.0 500_,-
315_„----AID N NIIW-2_
XHHW2 ^3YLL 3
N/A WA
1/0 -^
1 i----WC40 3 31.3% O.6S_ H A.1.
01 ROD 01% 595.5-750 SO At mIfW.2 3 3 500 No WA 310 3 PVC40 3 32.5% 0.17 A[002 000
0.99 997.5 1350 BUS BUS BU$ aUS BUS BUS i X ACG02
XFMR.01 E00 0.99 991.5 1150 670 AI XHHW-2 3 3 -S00 No N/A 3SO 6 PVC40 4 36.8% 1.15 t XFMRAI SWGgA1 430 0.99 3654.9 2500 20 At 3 r- _ _. 3 600
Yet
600 10 PVC40 4• 34.7% 0A5 M BIHO-1
SWGR.O1 480 0,93 301.0 400 35 XHHNJ 2 AI
AHHW2 3
3 300 Y41 600 3w 1
2 NC40 3 27.1% 0.14 N_ BESi02 SWGR.
Ol 480 0.99 241.0 E 350 EO Al- X/IHW3 J 3 a--- -___---
3?
50 Ye1
150 1 2 - P/C40 3 136% 0.13 P SWGROI AC0.
01 480 0.99 2196.9 3000 ms At 2 3 3 7M Yes 700 600 10 FVC60 5 - 24514 0.50 p- AC0.01 WTFRCONNELTlON 4B0 0.99 2196.9-3000 20-_- N THWW1 3 - 3 SOp '____Y-_._. AMC-4_ 30.1%0.07 Al ELECTRICAL SLD- P01 SCALE:NTS USHEETKEYNOTES
1. EQUIPMENT SHALL
BE INSTALLED AND LABELED IN ACCORDANCE WITH THE
CEC AND ALLAPPLICABLE REQUIREMENTS OF THE SERVING
UTIUTY COMPANY AND LOCALAUTHORITY HAVING JURISDICTION (AHJ).
2. DISCONNECTS MUST COMPLYWITH
CEC 590ASANO PROVIDE WARNING SIGN PER CEC
MAL13. C 3. USTING AGENCY NAMES
AND NUMBERS TO BE INDICATED ON POWER INVERTER AND SOIAR MODULES PER CEC IID.3(B). 4. LABELED 'PHOTOVOLTAIC SYSTEM AC COMBINER' S. UTILITY METER LABELEDPHOTOVOLTAIC
SYSTEM MONITOR'CT COMPARTMENT PER
EUSERC 3ZZ. 330. METER DOOR PER EUSERC 333.
METER SOCKET IS 1SJ. 6. LABELEDPHOTOVOLTAIC SYSTEM UTUTY
DISCONNECT' SWITCH TO BE VISUAL
OPEN AND ACCESSIBLE AND CONFORM TO CEC 705.
22. 7. LABELED WARNING. THIS
PANEL SUPPLIED BY MULTIPLE SOURCES OF POWER: 1.
UTILITY POWER, 2 PHOTOVOLTAIC SYSTEM -DISCONNECT ALL SOURCES BEFORE SERVICING.' 8. POINTOF INTERCONNECTION SHALL
BE IN ACCORDANCE B WITHCEC70SAI. S. PROVIDED FICATION
ALONG
WITH POSITIVE & NEGATIVE CONDUCTORS PER CEC 210.
5(C)(2). 10. WMNUM BENDING RADIUS
OF PHOTOVOLTAIC MODULE LEADS SHALL CONFORM WITH
WMMUM BENDING RADIUS SET FORTH BY THE
MODULE MANUFACTURER OR ARTICLE 33824, WHICHEVER IS MORE STRINGENT. 11. MATING CONNECTORS FOR
PV SOURCE CIRCUITS, PV JUMPER CABLES, AND MODULE
LEVEL POWER ELECTRONICS TO BE USED AND
IDENTIFIED FOR INTERNATABILITY. AS DESCRIBED IN MANUFACTURERS INSTRUCTIONS.
MATING CONNECTORS THAT ARE NOT
LISTED ARE NOT TO BE UTILIZED FOR PROJECT. 12.
AC POWER CONDUITS
TO CONVEY (3) CURRENT CARRYING A CONDUCTORS AND AN EGGNONEUTRALREQUIRED. A 13. ALL INVERTERS ARE TO RAVE THE MAX 2SOSW AC OUTPUT OPTION SELECTED. REFER TO INVERTER DATA SKEET ON SHEErWK801. 01 C.p.
0 TX Hwy S 48315 Austin, TX 78746 rmw.
Aduenewabhs.mm FOR
REVIEW ONLY NOT
FOR CONSTRUCTION SLD -
PDI WP601.
3
1 2 3 4 5 6
f Al —Energy w> ,. `"- AlsnFi,ery9 tim
t-/OL
DAS System HardwareY
Overview
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iaol can. o Tx R.,y s 9B315
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DATA SHEETS •MONITORING
Scale: NTS
DATASHEETS-RACKING
Scale: NTS
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Scale: NTS 1 2
3 4 5 6 wKeat
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SUNSYS HES L" SUNSYS HEN L" 4UNSYS HES L` SUNSYS HES L° Macular gMidocr Energy Sigroge System
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l
I.
Al DATASHEETS-CPS AC COMBINER
Scale: NTS
Ocps _
pHrww.^
vcPs
In -Line Cluster Mounting Bracket
Deslgned for CPS 2501275 kW Inverters & NOW, AC Combiners
DATA SHEETS -INVERTER RACKING
Scale: NTS
I OCFPs
ugI caa. o Tx Nvry s Heals
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FOR REVIEW ONLY
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DATASHEETS
WK802
ATTACHMENT B - SITE ASSESSMENT TABLE
TO GENERAL CONDITIONS AND TECHNICAL SPECIFICATIONS
36
Section 1: Site and System Information
Site Name Waterman Treatment Plant
Site Designator A
Service Account ID 7605929944
Meter Number 1010078883
Service Address 0
Site Address 2900 Vista Grande Circle, Fairfield, CA 95434 Solar Facility Target "Annual Production Estimate"(kWh) 3110442 Target Battery System Size(kW) 450 (200 kW + 250 kW)
Target Battery System Size(kWh) 1860
NEM-A(Y/N) N
NEM-A SAIDs N/A
Annual Meter Consumption (kWh) 3659981
Annual Ex -Solar Meter Consumption (kWh) 3659981
Meter Max Demand (kW) 768
Ex -Solar Max Demand (kW) 768
Current Rate Schedule B-19
Post Construction Rate Schedule B-19-S
Interconnection Point Rating (Volts / Amps) 480V
Distribution Utility Transformer Size (kVA) TBD
Existing Other Generation Back-up Generation
Section 2: Solar Facility
Array Structure OEM r TxerrraSwiartr;
Installation Type(GM, SS, RM etc.) FaxedjittGMl;.
1 Azimutht
Tilt(-) khtX'.Z,
Minimum Clearance Height (ft) ry"'$;*a
Solar PV Panel OEM
Solar PV Model # Q£CELLS;PEADU OX^L G11S - `,
Solar PV Panel Rating(W);'a
r$ x
la 595 f
4 Solar PV Panel Quantity(#) @ y'''..aa'f 3©®,©` ate,= 3 t—A
Solar PV Panels Per Strin #Yg()f ryf,'1OSiings ©f25 Mdulers '_ Solar Facility Capacity (kWSTC-DC) NTT
Inverter OEM
Inverter Model # Chin; SCH2%5K T- 1z1 80036i0 Aowutp„t, Inverter Quantity
Total Inverter Capacity (kW -AC)
DC/AC Ratio 7.14
AC Inverter voltage V' Y "' a •,;
e `"
80©
Solar Facility Transformer Size (kVA) j 15.00
Year 1 "Annual Production Estimate" (kWh) ' 3,066 0©5,
Solar PV Production Annual Degradation(%) 0.5%
Year 1 Annual Production Estimate to Target "Annual Produg 0.985713686 Section 3: Battery System
Battery System Size (kWh)
Battery System Inverter Size (kW -AC) 450, (20,0+ 25 1)) Duration(hrs.)
Battery OEM Saco, me;c
Battery System Inverter OEM Sbco:me_:C:
Battery System Round Trip Efficiency
Additional System De -rate (%) 2.010%
Anticipated Annual Full Discharges (Yr.1 #) 329i
Battery System Transformer Size (kVA) 20ahl2.50
Capable of Exporting for NEM Credits(Y/N) N!//h
Battery System WarrantyTerm(YRS) 1&00)
Section 4: EVCS
of Future L1 EV Chargers Planned NUA1
of Future L2 EV Chargers Planned N%IA
of Conduits Needed for Future Installation of L1 EV ChargerItN/lAl of Conduits Needed for Future Installation of L2 EV Charger' Section 5: System Offer Costs
Total "De eiop n Co in i Pr <E ) 385,000.00
00- pa0,46 ,,a Uip d C o s c ucied l ' Contract S'um'(f$j d S` a lest i S U C i i"
1 $,
Si te El e.c rcaSys erxv[1 grad os ts lrlcluded rn Gont a t1y t d ©lst - tP$ 4„00QO Power Pr'
c Incentive Amount($)
I- N, IkA, Incentive Program
N!//A\ ITC Percentage(%)
W/16) SolarFacility
Cost($) i Rund,Ued] iinl PPA Battery System Cost ($)
I B;undfie-,d] ini PPjA PPA Te m
Y ) 2.5 Solar Faci,li
Pow -, , ice' -4 IT S e7nax' i 01..121:D Soi r ac''
i ' P WNMPRRM s a o (°o) 0.0% B tery S em
eruiees R 4e' o ) i M/)A, 0.0% S s.
e ' I ' :,, ,
U.l. e ( 1
S stem' errm i t Y 4;:721,702
Increase to Solar Facility "Power Price" due to XXX($/k 01:0005 . remental Cost for Solar Facility Extended Inverter Warranty ff Incremental Cost to use all Copper Wiring($) N/A,
Incremental Cost to add Backup Power Solution($)
Incremental Cost to add XXXXX($) NM
Section 6: Utility Billing (assume 0% escalation for rates) YR 0 Existing Utility Bill
YR 0 Existing Utility Bill Demand Charges($) 423-,265`; YR 0 Existing Utility Bill Energy Charges($) 6:04;90i7
YR i Total Utility Bill($) Please, reference Saui:ngs_ Analysis Repor ; Utility Bill Energy Charges Post -Solar PV ($) Please; refe.re'nceSavfjng .,An aly5 isR'ep'ort; Utility Bill Demand Charges Post -Solar PV($) Please; reference! Sa,Wbos,A , alysi'& R:ep.ort.
Utility Bill Energy Charges Post -Battery System ($) Pl'ease ref'erence Savi',ng-sjAnal'y i5 Report:
Utility Bill Demand Charges Post -Battery System($) Pease referencel Sauings'Analysis Rep o'rt i Plea`sejreferen'ce S'avi'ngs,A rralys,t's;Report;
P1'eased;refereecejS_b )njg s3AnaAGysils,R'epo;rf?
Pleaserefere,nce)S1a i'ngs,A nalsysiis;Regorrte
Section 7: Other Cost Savings (assume 0% escalation for rates) Demand Response Revenue (YR 1$) j Please: refe.ren:ce Saui'ngs;An'alysi's Repo.rit? Other
Section 8: Performance Guarantee
So . Fa11OM , Up WIGK a R
r nRate(YR`1$IkVuh)
ola F i'lity 0 tp Ge A a E t lo) 0.0%
ol ar F I t rjO t i aka' e R t A'nnua Escal`at,or v
0 S'a a`ty ©ui Giaranee(iYR1rUNhj 0
53'/cycl'e
B Affeerj -v ,te' R'ate(INSE TIINITS)
tter S m GRLAIMEMMIUM /on 0.0%
B'atlGer C a . 1teR%a GeA nut"Ea anon(%i) t.. 0.0%
B bte y S m c a C le '( R 1 ) 2961
M;at ter i Cut arnt'eed(Ccles(YR#)4 i 29,6j
Battery Sy t ' G a a C cle t C =e °°) Se:e; S;ocomec Spec Sheet for'd'egrced'afiuycu!rve, Ba tety e i Ccr; ee 'Cycle annualChange(,I',_6,) See Soc.o:m:ec,$pe:c She;et f' d'egredati'onftrue. teySsemC u e'(R h 1674
I b.S sfe iiGuat ot($) J
ATTACHMENT C - PROJECT SCHEDULE
TO GENERAL CONDITIONS AND TECHNICAL SPECIFICATIONS
37
ATTACHMENT D - COMMISSIONING SCHEDULE
TO GENERAL CONDITIONS AND TECHNICAL SPECIFICATIONS
IID T '
T sk !Task Name
l.. _... FO M_de_. -
1 I ql City ofFai
T _,__
Duration Stan iFinish (Predecessors .Successors Fab 1124 ,Feb 18,24 Geb2S 2d Mar3'2A .Mar10,'24 Mt17 '2a JMar24,'24 i —M.. T_LW . T ..F.„_$-.5..,,M_. L ,.wLL_ J...S 51.M ..7 . w l T_I.f_.. 5 ..5-M.LT . W:..T.:_F $ $.. I.M.L7-i W T_•_.5_ 5 M _T_LW.I T! F_'.S. t.5 i M T 2 1 Award Date 0days Wed 4124124 Wed 4/24/24 32
3 Q Engineering Notice to Proceed 0 days Fri 8/23124 Fri 8/23/24 34 4 4 50% Design Drawings due to Site Host 0 days Mon 30/7/24 Mon 10/7/24 39,47,57,38 1 5 R 50% Drawings Site Host Review 0 days Mon 10/14/24 Mon 10/14/24 40,48,58 I 6 4 90%-Design Drawings due to Site Host 0 days Thu 31/7/24 Thu 11/7/24 41,49,59 7 4 90%Drawings Site Host Review _ 0 days Thu 11/14/24 Thu 11/14/24 42,50 iB g 100% Design Drawings due to Site Host 0 days Thu 11/28/24 Thu 11/28/24 43,51 9 4 10D%drawings Site Host Review 0 days Thu 12/5/24- Thu 12/5/24 44,52 10 R IFCStamped Drawings 0days Mon 12/16/24 Mon 12/16/24 45,53 i 11 S Design & Engineering Completed 0 days Mon 12/16/24 12/16/24 36 12 On Interconnection Sign-offwith the Utility 0 days
Mon
Mon 5/5/25 Mon 5/5/25 62
1t31 Permits AHl Approval Completed 0days Mon S/5/25 Mon 5/5/25 61 14 4 Major Equipment Order Date 0 days Tue 9/17/24 Tue 9/17/24 6755 is '' tl Procurement Completed 0 days Fri 10/3/25 Fri 10/3/25 67 j t6 j 4 Site Preparatilon Start 0 days Fri 8/22/25 Fri 8/22/25 80SS I 17 I r% Site Preparatilon Completed 0 days Tue 9/16/25 Tue 9/16/25_ 1 18 t'. Construction Start 0 days
80 lid 8/22/25 Fri 8/22/25 79SS
19 Mechanical Installation Completed - 0 days Tue 10/7/25 Tue 10/7/25 84 j 20 k Electrical Installation Completed 0 days Mon 2/2/26 Man 2/2/26 90 21 ` 4 Interconnection Sign off 0 days Mon 1/19/26 Mon 1/19/26 109 22 N PV Completion 0 days Tue 2/3/26 Tue 2/3/26 110
23 Utility Meter and Rate Switch Submittal 0 days Thu 12/5/19 Thu 12/5/19 24 + S Permission to Operate (PTO) 0 days Wed 4/29/26 Wed 4/29/26 117 A 25 S Testing & Commissioning Completed 0 days Wed 5/13/26 Wed 5/13/26 118 26 I S Commercial Operation 0 days Mon 6/15/26_ Mon 6/15/26 122 27 Date _ _
Commercial Operation Deadline 0 days Thu 12/5/19 Thu 12/5/19 28 14 Final Completion 0days Tue7/7/26 Tue 7/7/26 130
j 29
3Di I
4 04 Contract
31 n Proposal Submission
Contract Execution
33 j 1t Gty uncd Protect Approva
j 34 Q 4 Engineering Notice to7Fra eed.
35 Pre -Construction
36 1 4 Design & Engineering
i 37 T. Electrical Design
38 R Due Diligence Analysis
4 39 4 50% Design Drawings due to Site Host
40 4 50% Drawings Site Host Review
41 4 90% Design Drawings due to Site Host
l 90% Drawings Site Host Review
43 4 100% Design Drawings due to Site Host
44 a 100% drawings Site Host Review
j 45 i IFC Stamped Drawings
1 46 R Structural Design
j 47 r6 Due Diligence Analysis
48 S 50% Design Drawings due to Site Host
49 1 44 50% Drawings Site Host Review
i5D I 90-A Design Drawings
51 4 90% Drawings Site Host Review
j 52 100% Design Drawings due to Site Host
53 I 4 100% drawings Site Host Review
54 I IFC Stamped Drawings
206 days Wed 11/8/23 Fri 8/23/24
1 day Wed 11/8/23 Wed 11/8/23 32
105 days Thu 11/30/23 Wed 4/24/24 31 2
286 days Mon 8/26/24 Fri 10/3/25
80 days Mon 8/26/24 Mon 22/16/24 - 11
80 days Mon 8/26/24 Mon 22/16/24 66
15 days Mon 8/26/24 Mon 9/16/24 34 4,39,73
15 days Tue 9/17/24 Mon 30/7/24 38 40,4
5 days Tue 10/8/24 Mon 10/14/24 39 41,5,60
18 days Tue 10/15/24 Thu 11/7/24 40 42,6
5 days Fri 1118/24 Thu 11/14/24 41 43,7
10 days Fri 11/15/24 Thu 11/28/24 42 44,8
5 days Fri 21/29/24 Thu 12/5/24 43 45,9,71
7 days Fri 12/6/24 Mon 12/16/24 44 10,62,77
75 days Mon 8/26/24 Mon 12/9/24 65
15 days Mon 8/26/24 Mon 9/16/24 34SS 48,4
15 days Tue 9/27/24 Mon 10/7/24 47 49,5
5 days Tue 10/8/24 Mon 10/14/24 48 5016
15 days Tue 10/15/24 Mon 11/4/24 49 51,7
5 days Tue 11/5/24 Mon 11/11/24 50 52,8
10days Tue 12/12/24 Mon 11/25/24 51 5319
5 days Tue 11/26/24 Mon 1212/24 52 54,10
5 days Tue 12/3/24 Mon 1219/24 53
Task summary Inactive Mdenane Duration -only start -only E 6lemal Mil-oneO Manual Progress — Dat:
Project: Project Schedule
Date: Tue 7/30/24 spit ............................. Plujttbummary t-'—'—'1 udaie summary r'-'---"'t Manual 5umnwry Ratlup Finish -only 7 txamine a Milestone • Inactive Task Mama] Task ttil Manual Summary Winnal Tasks - Progress
J (Task 'Task Name
I
Duration Start rFin sh (Predecessors Successors I Feb
55 Mode
R Site Prep/Analysis
i
45 days Mon 8/26/24 Mon 20/28/24 64
56 4 Due Diligence Analysis 15 days Mon 8/26/24 Mon 9/16/24 34SS 57SS 57 _.
I
4 Geotech Report 15 days Mon 8/26/24 Mon 9/16/24 56SS 58,4 58 { 4 Environmental Studies 15 days Tue 9/17/24 Mon 10/7/24 57 59,5 59 4 SWPP Reports/Anyalsis 15 days Tue 10/8/24 Mon 10/28/24 58 6 f 60 j 4 ProcuremenD& Pemihng Noticeto Proceed Lday Tue 10/1 /24 ue 10 1S/24 40 72,74,75,76 67 4 Permits & Interconnection 135 days Tue 10/29/24 Mon 5/5/25 13 62 4 Utility Interconnection Application and Initial Review 100 days Tue 12/17/24 Mon 5/5/25 45 12 63 4 AHl Permitting and Approvals 95 days Tue 10/29/24 Mon 3/10/25 78FS*11S do Site Permit 60 days Tue 10/29/24 Mon 1/20/25 55
65, 4 Building Permit 60 days Tue 12/10/24 Mon 3/3/25 46 4 Electrical Permit 60 days Tue 12/17/24 Mon 3/10/25 3765 -1 67 4 Procurement Major Equipment Ordered (After Approved Submittal) 271 days Tue 9/17/24 Fri 10/3/25 15,14SS f 68' 12 4 Solar Modules Provided by Onyx 50 days Wed 6/25/25 Thu 9/4/25 78SS-40 days 88 Inverters 40 days Wed 6/18125 Wed 8/13/25 78SS-45 days 92 70 ] 4 Racking 45 days Wed 6/25/25 Wed 8/27/25 78SS-40 days 87,86 f1 71 4 AC COMBINER 100 days Fri 12/6/24 Thu 4/24125 44 98 72 { 4 PV SWITCHGEAR 150 days Wed 1O/16/24 Tue 5/13/25 60 99 J 73 i 4 SOCOMECSUNSYS HES provided by Onyx 200 days Tue 9117/24 Tue 6/24/25 38 103 74 i 4 PV TRANSFORMER 150 days Wed 10/16/24 Tue 5/13/25 60 100 75 1 4 PV & BESS SWITCHGEAR 250 days Wed 10/16/24 Fri 10/3/25 60 102 76 4 PV UTILITY DISCONNECT 250 days Wed 10/16/24 Fri 10/3/25 60 101 77 4 Data MONITORING System "DAS" 40 days Tue 12/17/24 Mon 2/10/25 45 78 4 Construttton Notice to Protoed i day Thu 8/21/25 Thu 8/21/2S 63FSr115:days S1,fi8S5-40 79 4 Construction 216 days Fri 8/22/25 Mon 2/2/26 110,1855 1 110 4 PV Mechanical Completion 1 day Tue 2/3/26 Tue 2/3/26 79 22,112,113 111 j P AHl & Utility Inspections 20 days Wed 2/4/26 Tue 3/3/26 112 1 4 Building Inspection 50 days Wed 2/4/26 Tue 4/14/26 110 113-1 4 Electrical inspection 50 days Wed 2/4/26 Tue 4/14/26 110 I
114
115 B 4
Submiss. not leteetdCatC
Utility Inspection
116 4 tgh "Ft. role t Deadly. e
117 4
118 J 4 Testing&Commissioning
lt9 J 4 DC Commissioning
120 4 AC Gear Commissioning
121 4 DAS Commissioning
112 8 4
123 1 4 Post -Construction (Close Out)
124 'Q 4 Project Walkthrough/ Punchlist
125 t 4 Prepare As Built Plans
126 4 Deliver O&M Manuals
127 J 4 Owner/Operator Training
128 4 Punch List Signoff
129 I 4 Deliver Final Submittals
130 4 Final Completion
Project: Project Schedule
Date: Tue 7/30/24 split
Y—'—
Milestone
41 days Tue 3/3/26 Tue 4/28/26
10 days Thu4/30/26 Wed5/13/26 117 224,25
10 days Thu 4/30/26 Wed 5/13/26 117
30 days Thu 4/30/26 Wed 5/13/26 117
10 days Thu 4/30/26 Wed 5/13126 117
37 days Thu 5/14/26 Mon 7/6/26
2 days Thu 5/14/26 Fri 5/15/26 118
15 days Tue 6/16/26 Mon 7/6/26 122
15 days Tue 6/16/26 Mon 7/6/26 122
15 days Tue 6/16/26 Mon 7/6/26 122
15 days Tue 6116/26 Mon 7/6/26 122
15 days Tue 6/16/26 Mon 7/6/26 122 130
1 day Tue 7/7/26 Tue 7/7/26 129 28
Summary r --------- I Inanne Mileslone Duration -only stanonly Projectsummary, r'---------1 Inacive Summary r - --1 Manual Summary aollup Finish only Inactive Task—`_ —_ _ _ - Manual Task _ t Manual Summary _ r Fatemal Tasks
I Feb IR'24 Feb25.'24 Mills,(24 Mar 10,24 _ Mr17.'24 (Mar 24,74 C hten,al Milestone o Manual Progress
7 Deadline L
I= Progress
ATTACHMENT E — OPERATIONAL OBJECTIVES
TO GENERAL CONDITIONS AND TECHNICAL SPECIFICATIONS
Solar Facilitv Sizin
If Solar Facilities are part of the project scope, it is the responsibility of the Installer to ensure that the sizing of the total installed system capacity at each Site (kWDC / kWAC) achieves the Annual Energy Production Target as defined in the Site Assessment Table as closely as practical for each Site and the Operational Objectives. The total installed system capacity per Site shall not increase or decrease the Annual Production Estimate without prior written approval of Site Host.
Battery System Sizing
If a Battery System is part of the project scope, it is the responsibility of the Installer to ensure that the sizing of the total installed system capacity (kW and kWh) per Site meets and the Operational Objectives.
Battery Systems Operation
1. Battery Systems shall charge one hundred percent (100%) from the Solar Facility.
2. Battery Systems shall prioritize operations in the following order:
a. Demand Reduction
b. Maximize savings from energy arbitrage
c. Maximize revenue from Grid Services Programs
NEM2 Interconnection Agreement
Installer is responsible to complete the Project within the requirements of the NEM2 interconnection applications and agreements with the Distribution Utility including addressing any and all notices of deficiencies and applying for new or revising the NEM2 interconnection agreement for addition of Battery Systems.
W
ATTACHMENT F - MAJOR EQUIPMENT
TO GENERAL CONDITIONS AND TECHNICAL SPECIFICATIONS
40
AlsoEnergy
DAS System
Overview
Hardware
AlsoEnergy wants to make it as easy as possible for you to plan and install your monitoring system hardware. That's why we provide your core hardware devices conveniently mounted and pre -wired in a weatherproof enclosure.
The operating system for the
grid of the future
DAS Assembly
Complete with all necessary DAS
system hardware
Preconfigured for plug -and -play
capability with the PowerTrack
Platform
Hardware mounted and pre-viired
NEMA 4 rated enclosures for exterior
mounting
Indoor mounting hardware included
Built to your specifications
ETL listed
End -to -end DAS systems from AlsoEnergy
are tested, configured, assembled, and wired
in our ETL listed facility in Boulder, CO.
To find out more or schedule a
AlsoEnergy, Inc / 5400 Airport Bvd. Ste. 100 Boulder, CO 80301 USA / 866.303.5668 demo, contact us at alsoenergy.comPage 314 of 1141
AlsaEnergy
Hardware Components
Data
Pre -configured for use with PowerTrack
Accepts data from RS-485, RS-232, or
Ethernet connected devices.
Includes internal storage capacity and a
touch screen LCD display.
Energy Meter
Get revenue grade accuracy,
as required by many clients.
Accepts single phase, split phase, and
three phase loads.
Includes LCD display.
Weather Stations and Environmental Sensors
The operating system for the
grid of the future
Our high quality weather stations can accommodate any solar or wind metric requirements. t Weather stations can fit into the main monitoring communications enclosure or have their own dedicated enclosure.
Anemometers Module Temperatures Sensors
Pyranometers (Hukseflux, Apogee, Basic and full weather station packages Kipp and Zonen) High temperature weather stations
a
Ambient temperature sensors Remote and portable stations Cellular Modem
4G network
Low power consumption
Remote management and configuration
Works with most major North American cellular providers Wireless Communications
1 j T Ethernet radio
Suitable for outdoor mounting
Intra site communication
Y, Integrated antenna
Remote oversight
To find out more or schedule a
AlsoEnergy, Inc / 5400 Airport Bvd. Ste. 100 Boulder, CO 80301 USA / 866.303.5668 demo, contact us at alsoenergy.comPage 315 of 1141
OCPS
800 Vac 3:1 AC Combiner Solution for CPS Inverters
The CPS 800 Vac 3:1 AC Combiner Box is designed for CPS 250/275 kW three-phase string inverters to optimize system design, installation, and wire management. The units combine the output of (3) CPS 250/275 kW inverters allowing a cost-effective solution for simplifying system designs and minimizing AC wire losses. This solution enables savings on labor and material costs by reducing the amount of wires needed to connect CPS string inverters to the grid.
Solutions Supplier
CPS can supply inverter and BOS equipment for 1500 V applications, which enables advantages for project logistics, shipment, and warranty management.
Decreased Wiring Costs
Combining CPS inverters with an AC Combiner Box reduces the amount of wires needed to connect the PV system to the grid.
Optimized Design
The AC Combiner Box is designed specifically for use with CPS 250/275 kW inverters.
SA-'
s
I
III
iii
II
I •
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a
II
Internal View of AC Combiner Box
n,tasheet
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0CPSacmxc|oam
T --- ------'--''-------'----- -- --' -- - ' ' Model Name CPS DPA03-80OWUS Number of circuits 3 .
ocpo type' Fuse
z---__-- __---_ __- '_--- .-_
Disconnect ! Yes
Compatible inverter(s) i cpssc z7sx oo/usuoo
Rated voltageuouvac
Rated input ,u aonx
Input | conductor size so*5oo mUCU/AL(1 z,et l_- --_--Input conduit knockout size Removable bottom plate Rated
output current !___________ 6OOA_____________________ Output conductor . aon»o mUcU/AL pm4se) Output
conduit knockouu,me / nrmovab botuonp Interruptingasmv
Disconnect
rating oonA Output
fuse rating / lnnn* 55x36.
2x14J5in(1400x920x375mm) . iWeight
264 lba/12Vkg_____ Padlockable
enclosure (LOTO) Yes Grounding
bu,ba y's Breather
vent' Yes ' Enclosure
protection degree NEMA Type 313 Operating
humidity 0% to 95%, non -condensing Standard
2 years Ocps;
AMERICA
FAM
To
MVT and/or Recombiner
rl
Datasheet
In -Line Cluster Mounting Bracket
Designed for CPS 250/275 kW Inverters & 800 Vac AC Combiners CPS In -Line Cluster Mounting Bracket
The CPS In -Line Cluster Mounting Bracket is designed to provide a simple, low-cost mounting solution for CPS 250/275 kW inverters and CPS 800 Vac 3:1 AC Combiners. (3) CPS 250/275 kW and (1) 800 Vac AC Combiner can be mounted onto piles to easily install the equipment for ground mount PV applications. This solution enables savings on labor and material costs for system designs and installation.
Key Features
Easily mount (3) 250/275 kW inverters and (1) 800 Vac AC Combiner Simplifies Inverter and Combiner installation
Cost-efficient mounting solution
Includes mounting bracket for CPS 800 Vac AC Combiner
In -line design to allow efficient working space
o CHINT POWER SYSTEMS AMERICA 2023/01-MKT NA Chint Power Systems America 1380 Presidential Drive, Suite 100, Richardson,TX 75081 Tel:855-584-7168 iVlail:[email protected] Web: www.chintpowersystems.com
0cps Tecmnia|oata
T----------------------------------'--- ---'----- el Name CPS In -Line Cluster Mounting Bracket Material ` [s1D Om78o ee|
Dimensions 0HxVVxu/ 46.3x231.4x6nU 5x 877x17unnn) U-_ Dimensions of total Cluster Mounting Bracket including r----' -----------'----------- — ' ------ jTotal
weight of Cluster Rack 204lbs/120kg________ Compatible
inverters| [PS ScHz7sKTL-o Usuoo T---'--'---------'---'---- - -------- - -- --- ---' i[v |b| combiner[p5DpAos-uuoV/us T----'-----'--------'—'-'------'---'''------- ~ Installationmethod . Mounted nu3piles (piles not included) Standard' z years Cluster Components
I Equipment
installation vertical beam 8 3 Vertical
beam 6 4 Pile
connector 3 5 Pile
3 (user supplied)
Datasheet
250/275kW VZ 1500Vdc String Inverters for North America I
CPS SCH275KTL-DO/US-800 V2
The 250/275kW high power CPS three phase string inverters are designed for ground mount applications. The units are high performance, advanced and reliable inverters designed specifically for the North American environment and grid.
High efficiencies, wide operating voltages, broad temperature ranges and NEMA Type 4X enclosure enable this inverter platform to operate at high performance across many applications. The SCH275KTL inverters include a selectable Active Power of either 250kW or 275kW (factory default) with 12 MPPTs and are available with either 36 fused PV string inputs or 24 unfused PV string inputs. The CPS FlexOM solution enables communication, controls and remote product upgrades.
Key Features
Anti-PID function
Reactive Power at Night function
CPS FlexOM Gateway enables remote FW upgrades
Integrated DC disconnect switches
Protection functions for enhanced reliability and safety Selectable Max AC Active Power of 250kW or 275kW
UL 1741-5A certified to CA Rule 21, including SA14-18
S A e14 rhAderke- pliesWth
C us ,
PM is o(the FCC Rules
12 MPPTs with 36 fused inputs or 24 unfused inputs
Copper and Aluminum compatible AC connections
NEMA Type 4X outdoor rated, tough tested enclosure
Full power capacity up to 42°C
Standard 5 year warranty with extensions to 20 years
Supported comm protocols (Modbus RTU,TCP/IP, PLC, CAN)
UL 1741-58 and IEEE 1547-2018 certified
0CHINT POWER SYSTEMS AiMERICA 2023/10-iMKT NA Chint Power Systems America 1380 Presidential Drive, Suite 100, Richardson, TX 7508 Tel:855-584-7168 Mail:[email protected] Web: www.chintpowersystems.com
Technical Data
Model Name CPS SCH275KTL-DO/US-800-36 V2 CPS SCH275KTL-DO/US-800-24 V2 D
Max. DC Input Voltage 1500V
Operating DC Input Voltage Range 500-1450Vdc
Start-up DC Input Voltage/ Power 55OVdc 50OW
MPPT Voltage Range Q PF>0.991 900-1300Vdc
Number ofMPP Trackers 12 12 -
Max. PV Input Current 30A per MPPT 30A per MPPT
Max. PV Short -Circuit Current 6.0.0A,_50A per MP_PT__ 600A, 50A per MPPT Number of DC Inputs 36 Fused Inputs, 3 per MPPT 24 Non -Fused Inputs DC Disconnection Type Load -rated DC switches
DC Surge Protection Type 11
Max AC Output Power (Selectable) @ PF>0.99 250kW / 275kW Max. AC Apparent Power 27 .. kVA
Rated Output Voltage 800Vac
Output Voltage Range 2 704-880Vac
Grid Connection Type 3-Phase / PE
Max. AC Output Current @_800Vac 198.5A
Rated Output Frequency 60Hz
Output Frequency Range 2 57 - 63Hz
Power Factor 0.99 (±0.8 adjustable)
Current THD @ Rated Load 3%
Max. Fault Current Contribution (1 Cycle RMS) 215.2A
Max. OCPD Rating 300A
AC Surge Protection Type 11
System and Performance
Max. Efficiency 99.0%
C" E-C-Efficiency' 9 8-.--5-%--
Stand-by / Night Consumption 5W
Enclosure Protection Degree NEMA Type 4X
Cooling Method Variable speed cooling fans
Operating Temperature Range 3 22'F to +1 40'F -30°C to +60°C (derating from +1 07'F +42°C) I :-Operating Humidity 0 to 100%
operating Altitude 8202ft / 2500m (no derating)
Audible Noise 80dBA @ 1m and 25°C
User Interface and Display LED indicators, WiFi + APP
Inverter Monitoring
4ModbusRS485PLC / CAN
Site Level Monitoring CPS FlexOM (1 per 32 inverters)
Modbus Data Mapping SunSpec CPS
Remote Diagnostics / FW Upgrade Functions Standard / (with FlexOM Gateway) Dimensions (HxWxD) 27.2 x 41.3 x 15.7in (690 x 1050 x 400mm) Weight Approx. 262lbs / 11 9kg
Mounting Installation Angle Vertical installation
AC Termination Stud Type Terminal (Wire range: 4/OAWG — 750kcmil AL/CU, lugs not supplied) 36 Fused Input; Screw Clamp Fuse Holder (Wire range; #14 - #8 AWG CU) i DC Termination 24 Non -Fused Input: Screw Clamp Terminal (Wire range: #14 - #8 and #6 - #4 AWG CU)1 Fused String (3 25A fuses provided (Fuse values up to 30A acceptable) Safety
Certifications and Standards UL1741-SAISB Ed. 3, CSA-22.2 NO.107.1-16, JEEE1547a-2014, IEEE1547-2018, FCC PART15 Selectable Grid Standard IEEE 1547a-2014, IEEE 1547-2018, CA Rule 21, ISO -NE Smart -Grid Features Volt-RideThru, Freq-RideThru, Ramp -Rate, Specified-PF, Volt-Var, Freq-Watt, Volt -Watt Protection Functions
iieaciive Power at Night Yes
Xnti-P-_I_D,fin_ct_i_o_n_ Yes
Insulation Resistance Monitoring Yes
Onboard Fault Oscillography Yes
PV MPPT Current Monitoring Yes
Residual Current Monitoring Yes
Output Overcurrent Protection Yes
Output Short -Circuit Protection Yes
Output Overvoltage Protection Ye.
Warranty
Standard 5 Years
Extended iTerms 10, 15 and 20 years
1) See user manual for further information regarding MPPT Voltage Range when operating at non -unity PF 5) One threaded hole per MPPT for connecting #6 - #4 AWG CU 2) The "Output Voltage Range" and "Output Frequency Range" may differ according to the specific grid standard. 6) Fused string inputs only applicable to the SCH275KTL 36-input model. 3) See user manual for further requirements regarding non -operating conditions. 4) CPS AC -PLC Kit required for AC PLC communication.
ForeFront Power Design & Engineering Standards
V2.1
Change History Record
VERSION
NUMBER
EFFECTIVE
DATE
DESCRIPTION OFGHANGE APPROVED BY
1.0 05/18/2017 Initialversion Dan Jordan
Director of Engineering
1.4 3/8/2019 New Version Aaron Sanders
Director of En2ineerniiz
2.0 Updated version Aaron Sanders
Director of Engineering
2.1 9/12/2022 Updated Version Aaron Sanders
Director of Engineering
1. Table of Contents
ChangeHistory Record.....................................................................................................................2 Tableof Contents..............................................................................................................................4 Section1: Introduction.....................................................................................................................5 Section 2: Design Codes & Standards.............................................................................................. 6 Section3: Site Information...............................................................................................................7
3.1: Site Information for Rooftop Projects................................................................................7
3.2 Site Information for Ground Mount Projects...................................................................... 8
3.3 Site Information for Canopy Mount Projects .................... :................................................. 8 Section 4: Drawing Requirements..................................................................................................10 Section 5: Design & Engineering Review........................................................................................12
5.1- Design Mobilization...............................................................................:.......................... 12
5.2 - Design Review..................................................................................................................12
5.3 - Construction/Term-Out..................................................................................................13 Figure 1: Design Engineering Process................................................................................14 Section6: Design Standards...........................................................................................................15
6.1 - Module Layout................:................................................................................................15
6.1.a - Existing Site Features...............................................................................................15
6. Lb - Define Useable.PV space..........................................................................................15
6. Lc - Module Array Design................................................................................................16
6.2 - Electrical Requirements..................................................................................................17
6.2.a - General Specifications.............................................................................................17
6.2.b - Inverter Sizing/Selection.........................................................................................18
6.2.c -Equipment Selection................................................................................................18
6.2.d - Equipment Locations...............................................................................................18
6.2.e -Grounding .................................................................................................................19
6.21- Disconnecting Means................................................................................................ 20
6.2.g - Interconnection................................................:......................................................20 Figure 2: Example POCC Identification Process................................................................. 22
6.2.h - Metering/Monitoring................................................................................................22
6.2.i - Labels & Markings..................................................................................................... 23
6.2.j -Wiring ........................................................................................................................ 24
6.3 - Structural......................................................................................................................... 27 Section 7: Equipment Specifications............................................................................................. 29 Section 8: Glossary of Terms 30
1 Introduction
This Design Standards document is intended to provide an overview of expectations and standards for which we strive to implement across all projects. Above all, regulatory agencies such as NEC, LIL, and local jurisdictions/utilities set the minimum standard; however, additional guidance has been provided to drive project design to meet the requirements of ForeFront Power's entire operations, including Service and Safety.
Additionally, some requirements are those deemed of highest importance from our investment partners and their corresponding Independent Engineering consultants. (In the event of a conflict between statutory/regulatory requirements and this document, statutory and regulatory requirements take precedence.).As each project varies from region to region, and customer to customer, processes are in place to approve variances from this design guide; however, these efforts must be communicated early in the design phase, to allow time for qualification and due diligence efforts. Every effort will be made to work closely with the EPC Contractor or Design Build Contractor (referred to as "External Design Team") to make the design process seamless and optimal for all parties involved. FFP design specifications must be followed unless deviation is approved by FFP in writing.
The driving factors in creating these standards are as follows: 1) Designing for 20+ year operational timelines and the serviceability of systems post -installation, 2) Meeting all applicable code and regulatory compliance, 3) Optimizing cost and production, 4) Ensuring both installation and service safety, 5) Meeting the objectives and requirements of the system owner and their consultants, 6) Delivering a ForeFront Power caliber system, 7) Creating new opportunities by excellence in delivery and operation.
POWER
Section 2: Design Codes & Standards
The following documents apply to this standards document. Version of code will be dictated by jurisdiction and local adoption i.e. NEC version. Additionally, some local incentive programs may have special requirements as part of the solar program that may go above and beyond local code or ForeFront Power guidelines - it is the responsibility of the External Design Team to be aware of these requirements, and to design accordingly.
Codes:
0 National ElectricCode
National Electric Safety Code
0 International Building Code
National Fire Protection Agency
Applicable State Specific Building/Electrical Codes and Fire Codes Local Fire Requirements
ADA
DSA
Standards:
ASTM
ASCE
IEEE
UL
Other Requirements:
Project Specific Power Purchase Agreement or other customer agreement EPCAgreements
ForeFront Power Service Inspection/Acceptance Inspection ALTA/ASCM Standard TableA
Equipment NamingConvention
ForeFront Power Project Minimum Submittal List
Utility Specific Interconnection Guidelines and Minimum Technical Requirements Incentive Program Technical Requirements (if applicable)
3: Site Information
ForeFront Power will require certain site information as outlined below. This document is only intended to provide External Design Team with a general overview of what is typical; project specific documentation should be discussed during the pre -engineering phase of a project.
The due diligence will be a coordinated effort, with site information and data gathering performed by the External Design Team, or in certain cases by ForeFront power, and a combined effort to bring a design to final approval stages.
Site Information for ALL Projects
External Design Team to perform on -site evaluation of existing conditions, with the following deliverables for all projects:
Arc Flash hazard Analysis and labels for all DC and AC equipment in the PV System above 50 volts
Load flow calculations required when interconnection to non -linear bussing with a breaker. These will also be required on any interconnection when either the sum of existing breakers or sum of existing breakers + amperage from PV System equal or exceed the rating of the bussing.
Coordination Study for any Site that requires medium voltage gear or POCC, for system sizes of 1 MW AC and larger, "campus" type settings, multiple interconnections for a single host, "critical" load at site (data center, hospital, prison, water treatment facility, etc.), and any site that will make use of settings for protection devices, or modify/replace any programmable protection devices in the existing facility equipment.
Site Photos and other Site Specific Information uponrequest.
3.2 Site Information for Rooftop Projects
External Design Team to perform on -site evaluation of existing conditions, with the following deliverables for rooftop projects:
Preliminary Structural Report demonstrating that the existing structure can withstand the additional loading from the PVsystem.
Written approval to install PV system from roof warrantyholder.
Roof report of existing conditions
Lightning revalidation is required for any site where existing lightning protection systems exist on the roof. These systems typically are made up of air terminals (small or large `lightning rods') connected to each other and large metal equipment with a network of bare, braided aluminum cable. When installing new equipment on these roofs, the lightning protection certification is invalidated and must be revalidated. The revalidation usually involves addition of some equipment (air terminals and cable) to tie' the new PV system equipment to the existing lightning protection system.
3.3 Site Information for Ground Mount Projects
If not already provided by Forefront Power, the External Design Team shall perform on - site evaluation of existing conditions, with the following deliverables for ground - mount projects, to the extent required by the external design team's scope of work::
Geo-technical study (See Section 3.4 for detailed report requirements) Interconnection path and any required access, easement, and ROW (right of way) approvals required to secure identified routing to POCC.
ALTA or boundary survey referenced to all ownership, easements & ROW's - reference document for ACSM Standard Table A specifications, including underground utility location via ground penetrating radar. (Title search will be provided by ForeFront Power).
Legal access and easement crossing license(s) as required.
Environmental due diligence items including wetlands orfloodplain studies, site specific environmental approvals, Phase 1 ESA studies, CEQA/FAA/NEPA, or other regulatory approvals as required.
All local and jurisdictional permit requirements must be identified as part of the overarching permit process and should be communicated and planned as part of the master project schedule. Typical permits that may be required for ground projects include, but are not limited to: Zoning and/or Planning, T&E Species, Storm Water Management, Fugitive Dust Permit, Land Disturbance, State Lands - Historical, EPA .
Section 401, USFWS, Grading/Erosion Control permits, DSA,etc.
3.4 Site Information for Canopy Mount Projects
If not already provided by Forefront Power, the External Design Team to perform on - site evaluation of existing conditions, with the following deliverables for canopy projects, to the extent required by the external design team's scope of work:
Geo-technical study (See Section 3.4 fordetailed report requirements) Interconnection path and any required access, easement, and ROW (right of way) approvals required to secure identified routing to POCC.
Underground utility location, completed via ground penetrating radar, will be plotted and mapped on the site plan drawings.
ALTA or boundary suvey referenced to all ownership, easements & ROW's - reference document for ACSM Standard Table A specifications. (Title search will be provided by ForeFront Power).
Snow Loading requirements. Canopies in regions with snow load of 10 PSF or greater must be Y-style so that snow does not shed onto persons and materials in the parking lot. External Design Team and Forefront Power can collaborate on the implementation of T-Structures with arresting devices as an alternate solution to Y-style structures.
FOREFRONT
DER
Geotechnical Report Requirements for Ground & Canopy Projects If not already provided by Forefront Power, Geotechnical Reports must be no more than 1 year old and prepared for the PV installation. If older, or geotechnical reports not specifically prepared for the PV installation are to be used, the Geotechnical Engineer of Record must state in writing that the report is applicable
to the PV installation. The geotechnical investigation must include a sufficient subsurface exploration (roughly one exploratory bore or test pit per acre, excavated to twice the anticipated foundation depth). Geotechnical Reports will be completed in accordance with the approved Forefront Power geotechnical scope of work. Geotechnical report must, generally, contain thefollowing:
Soils report for foundation design
Recommendations for foundation types and design parameters Boring maps and testing results
Ground water and subsurface conditions (note level of wet -season high water depth if ground water is not encountered)
Soil resistivity
Site development recommendations (if site grading isincluded) Parameter of seismic design (site class at a minimum)
Corrosive properties of soils to concrete (structural calculations should note concrete type and reference geotechnical findings)
Corrosive properties of soils to buried metal for projects with piles (structural calculations should note that foundation materials and coatings (screws, piles, etc) are consistent with 30+ year life in soils with corrosive properties called out in geotechnical findings)
Soil classification, geotechnical hazards, and risk mitigation strategies (e.g., settlement potential, expansive soil, liquefaction, collapsible soil, frost heave/adfreeze, etc.)
For projects with medium voltage interconnections, field electrical resistivity testing or assumptions used for design and documentation of resource for all medium voltage projects (electrical calculations should showhow grounding design is related to soil electrical resistivity measured in soil during geotechnical investigation) For projects with medium voltage interconnections, thermal resistivity testing of soils or assumptions used for design and documentation of resource all medium voltage projects (electrical calcs should show that temp rise due to ohmic losses for any underground conductors will not exceed temperature rating of wire, and should be tied to measured thermal resistivity of soil in geotechnical results.
Contractors Construction - QA/QC plan forfoundations
Infiltration Testing on ground mounted projects. Infiltration testing will be completed on the ground surface soils located within the array footprint. Infiltration testing will be performed in accordance with relevant ASTM guidelines.
Pile testing observation, tension and laterals are required for ground mount system designs. Pile foundation designs should be predicated upon results published in the geotechnical report
Site Information for Landfill Proiects
Contained within the geotechnical report:
Evaluation and recommendations for incorporation of total and differential settlement of the waste fill, with and without influence of the PVsystem Evaluation of landfill slope and soil stability, with and without influence on thePV system
Impact of the PV system foundations and/or ballast on the landfill cap and geomembranes (are penetrations of the landfill cap proposed?) Evaluation of the effect of the PV system installation on landfill gas, leachate and groundwater collection and monitoring systems, and recommendations for mitigation, if necessary
Grading and drainage:
Evaluation of the PV system on the effect on any vegetation layer and recommendations for mitigation
Evaluation of changes in drainage and recommendations for additional erosion control needed as part of the PV system installation
Evaluation of land -fill As -Built drawings and confirmation that any items requiring excavation are placed clear of the landfill cap or buried waste. Test pits to confirm as -built limits, and in locations of planned excavations, are required Review of the Post -Closure Use Permit (PCUP) and verification that the design and reporting requirements will be complied with as part of the EPC process.
Section 4: Drawing Requirements
External Design Team must provide both preliminary and permitting drawing packages in PDF format as a singular file. Unless otherwise specified by ForeFront Power, the External Design Team can assume only one set of drawings is required per site, even if a given site contains multiple interconnections. In the case where a given site contains multiple interconnections, it is possible for each interconnection to be considered a single asset and two assets at a single site may be financed by different investors or in different investment tranches. Thus, ForeFront Power reserves the right to request that each interconnection have its own set of drawings if deemed necessary by ForeFront Power.
All Issue For Permit or Issued for Construction drawings must be stamped/sealed by a licensed professional in the relevant discipline and state.
All drawing changes throughout shall be noted in a changelog in excel format. All milestone design sets must be accompanied by a changelog including initial design listing changes from original FFP design (if applicable). FFP shall provide a changelog template in excel, if desired.
Changes required to be noted:
Change in system size or equipment quantities
Changes in tilt, azimuth, or spacing of array.
Changes in location of array(s) or other equipment locations.
Changes to engineering calculations.
Changes to electrical configuration or wiring design.
Change in equipment make or model.
Change in sheet count (this includes sheets added with natural design progress).
Any error that has been corrected.
Any change resulting directly from a comment from FFP, customer, or any other third party reviewer.
Any other change not listed that may help reviewers with design context.
Additionally, the following "ground" rules must be followed during the design phase:
All preliminary drawing packages should include, but are not limited to, thefollowing (if not otherwise clarified by the requestor):
o Module Layout
o Electrical Site Plan
o Line diagram illustrating both DC and AC side of the solar system, as well as the
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SCADA and or DAS components required for the project
o Module racking system specs
All permitting drawing packages should include, but are not limited to, thefollowing:
o Title Sheet including drawing index, applicable codes, system size (DC and AC), breakdown of module quantities/wattages, and PE license numbers with expiration dates
o Site Plan and Elevations (if required byAHJ)
o Electrical and structural details, required for a successful permit from the relevant AHJ, including the California Division of State Architects, (DSA) o DSA permit sets will also include all existing A -Numbers for all existing building on the school campus.
o Module Layout including tilt/azimuth, nearby obstructions with their full dimensions, any obstructions distance to the array, perimeter setbacks,row spacing, array fence/gates (ground projects only), and service access paths ground projects only)
o ALTA or Boundary Survey (all project types (ground, canopy, and rooftop), with the only exception being rooftop projects where the POCC location is in or on the same building that contains the solar arrays)
o Civil Plan (ground and canopy projects, as applicable) - Include applicable sitepreparation requirements, site survey, grading, cut and fill requirements, compaction requirements, soil stabilization, storm water management, erosion control, drainage, trench details, roads details,etc. For building permits include SWPPP, NPDES and N01 information needed for each relevant permit.
o Fire Aisle Locations and vehicle means of egress and ingress o Electrical Site Plan to include locations of all equipment such as modules, disconnecting combiner boxes, conduit/raceways/trenches, disconnect switches, inverters, transformers, POCC, and string/disconnecting combiner box layout boundaries with all equipment labeled per Naming Convention. o Table showing number of modules per string, number of strings per combiner or string inverter, number of combiners per inverter (for central inverters).
Table should also include module wattages, tilt angle, azimuth, or structure type if any of these vary on multiple arrays.
o 3 line diagram including number of modules in series, number of strings in parallel per combiner, disconnecting combiner box part number/fuse size/amperage, DC/AC disconnect manufacturer and part numbers,existing o Structural and electrical calculations for the entire project o Wire schedule in table format to include location (between POCC and AC disconnect, etc.), design ampacity, voltage, conductor type, conductor size, conductor quantity, ground size, neutral size, conduit type, conduit size, length of run, and voltage drop.
o ForeFront Power provided Electrical Notes (Provided for information only and where applicable. The EDT to provide project specific Notes as necessary.) o Electrical details - Conduit routing/mounting, equipment mounting/installation, module grounding, equipment grounding, wire management, penetration details,etc.
o Equipment pad electrical details (if applicable) to include locations of all equipment and working clearances
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o Equipment pad structural details (if applicable) to include securement details, pad thickness/concrete strength/reinforcement, etc.
o Inverter shade structure
o Structural (Roof) - Include module securement, roof integration details, racking layout, racking design details, material grade/finish, hardware torque specifications, tolerances, corrosion protection, etc.
o Structural (Ground/Canopy) - Include module securement, foundation layout, foundation design details, racking design details, structural notes, material grade/finish, hardware torque specifications, tolerances, corrosion protection, etc.
o Construction details for all assemblies including torque and weld specifications.
o Module, Disconnecting Combiner Box (if applicable), and Inverter spec sheets
o Labels and Markings - i.e. POCC, disconnecting combiner boxes, DC/AC switches, Utility required labels per ForeFront Power naming convention see Equipment Labeling Convention Standard)
o ForeFront Power will either (i) provide a DAS specification and list of required instrumentation, (ii) approve a specification and list of instrumentation provided by the EDT, or (iii), furnish a DAS system for the installer to include in the design and install on site.
Title block must include ForeFront Power project number on all sheets, unless this would interfere with plan check. If unable to place ForeFront Power project number on title block, the project number must be displayed on the title sheet.
All drawings must use a conventional scale, with notations showing each sheet convention, as well as dimensioning (graphic) scales from which service personnel can measure on plans in the field.
All layout drawings must show a North arrow, as applicable to the specificsheet.
All drawings must be dated, with updated versions, using conventional "REV" control measures and documentation.
All Issued for Construction drawings, and subsequent revisions, final as -built drawings, and Record Drawings must be stamped and signed by the registered Professional Engineer of record, licensed in the state for the givenproject.
Additionally, when required by the AHJ, any other version of a drawing requiring stamp and signature, will be so provided.
Utilize adequate line weights as appropriate, to help differentiate on what is important to focus on, and what is simply background detail.
Provide ForeFront Power project managers all applicable PDF drawing packages for archiving, with all versions and updates through final completion. Complete construction drawings and version updates must be delivered to ForeFront Power, including permitting sets, construction drawings, as-builtdrawings, and Record Drawings.
As -built drawings must match equipment naming of DAS.
5 Design & Engineering Review
During the opportunity assessment phase, if applicable, and continuing as an opportunity progresses through the development cycle, ForeFront Power will provide support and design review stages to help guide the opportunity and allow for exchange of ideas andproposals.
ForeFront Power will also coordinate review of design iterations with the site host/offtaker as required.
Design Mobilization
Upon commercial and legal agreement finalization between all stakeholders, the External Design Team and ForeFront Power shall hold a kickoff meeting to discuss proposed project details including the following:
o Schedules
o Design Review process
o Scope of Work
o As -sold system specs
o Major equipment
o Customer requirements
o Material procurement
o Data Acquisition System (DAS)
o Any pertinent project details to be communicatedbetween parties.
The External Design Team should provide updated project schedules, high level design documents including module layouts and line diagrams, as well as any technology specifications for modules, inverters, and racking systems. Equipment selections for these (3) major components should be approved by ForeFront Power prior to proceeding with full designscope.
2 Design Review
Prior to completion of the permitting drawing package, the External DesignTeam shall initiate preliminary design review sessions in conjunction with the project schedule, with the appropriate stakeholders at ForeFront Power to review the plans and specs.
Yield estimates (kwh per KWDC) are created in PV SYST using preliminary design information such as: module/inverter selection, system size, tilt, azimuth, ground coverage ratio, DC:AC ratio, and shading from near or far obstructions. Should these design features (or any other characteristics that will impact the yield) change, External Design Team shall notify ForeFront Power to arrange for PV SYST estimates to be updated.
Prior to permit submittals, and after ForeFront Power's preliminary drawing package feedback is received, the External Design Team shall initiate design review sessions in conjunction with the project schedule, with the appropriate stakeholders at ForeFront Power to review the plans and specs.
The External Design Team shall provide all design drawings in AutoCAD and PDF
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format, as well as any engineering reports including ALTA surveys, civil, geo-technical, structural calculations, revised energy estimates or coordination studies asapplicable.
Coordination studies are required when there the site requires medium voltage gear or POCC, for system sizes of 1 MW AC and larger, "campus" type settings, multiple interconnections for a single host, "critical" load at site (data center, hospital, prison, water treatment facility, etc.), and any site that will make use of settings for protection devices, or modify/replace any programmable protection devices in the existing facility equipment.
Typical review timelines for a single project should be (5) business days, unless otherwise agreed upon, and will include feedback from all ForeFront Power stakeholders. Comments will be provided in a Word document with response instructions. Please note that thorough responses with sheet numbers references will result in optimal response times and minimize re -review cycles. Once ForeFront Power verifies that the External Design Team's response addresses the initial concern, ForeFront Power will insert "RESOLVED" in the response column. The External Design Team should expect a minimum of one design re -review cycle and Construction NTP will not be issued until ForeFront Power approves drawing package.
Upon "Permit Approval", the External Design Team shall provide construction drawings and reports in AutoCAD and PDF format to ForeFront Power for record keeping. AHJ backcheck comments will be provided to Forefront Power, and all revisions to drawings will be clouded and annotated with the appropriate revision number. The drawing legend will be kept current at all times.
5.3 Construction/Term-Out
Upon mechanical completion of a project (local inspections and approval obtained), the External Design Team shall furnish final as -built drawings and or Record Drawings to Forefront Power.
As -built plans and Record Drawings shall capture any variances from the construction or permit drawings, and shall accurately reflect site conditionsfor:
o Equipment placement including module arrays, DC and AC components, conduit routing, equipment pad details, metering and monitoring equipment including weather station, and interconnection.
o Include module layouts, locations and heights (labeled on drawing) for any shade creating sources including parapet walls, trees, existing rooftop equipment - this information will be used by the Independent Engineer to validate any shade assumptions.
o Confirm sizing of equipment, specifications, equipment labeling and identification (disconnecting combiners, disconnects, source circuits, inverters, etc.).
o Label drawings"as-builts" with date, include electronic professional engineering stamps and signatures for all disciplines.
External Design Team or the EPC Contractor will create and provide Closeout Manuals upon completion of the project. These manuals will include all warranty information, final project drawings, and other closeout information as so requested by Forefront Power.
Design Standards
The goal of standardizing design requirements for all ForeFront Power financed projects is to ensure projects take into account considerations for ForeFront Power's service requirements, safety aspects that are designed into projects, and specifying high quality components that meet the demands of a 20+ year lifetime, as well as requirements known by various Independent Engineers. It is acknowledged that utilities, jurisdictions, and customers will have various requirements that may test our standards, and concessions will be made on a case by case basis as appropriate.
6_1 Module Layout
6.1.a — Existing Site Features
Provide architectural plan view of dimensions of and setbacks from existingbuilding and relevant features including all rooftop obstructions and relative height.
Provide dimensions of and setbacks from any additional shade sources that may exist in adjacent areas to the building - i.e. trees, buildings, power poles,etc.
Provide heights of parapet walls, including any variances around the perimeter of the building - i.e. store front signage, etc.
Provide azimuth angle of the site facility. Use 1800 to represent due south, increasing angle clockwise.
Provide building height and variances in rooftop areas - i.e. sloping roof, drainage areas, etc.
6.1.b - Define Useable PV space
Consider all required setbacks and access aisles as defined by the local AHJ i.e.
California Fire Requirements, known customer requirements, safety, equipment clearances, and shade sources. To the extent that ForeFront Power is providing this information in a 30% design document, the EDT or EPC Contractor will need to verify array placement on balance with provided survey and mapping and geotechnical information provided.
Utilize the following standard rooftop setbacks utilized by ForeFront Power:
o Comply with NEC 110.26 for any rooftop electrical equipment (does not apply to PV modules).
o Provide minimum 4' setback (or greater if required by building owner) onall sides of HVAC or similar type equipment.
o Provide minimum 4' setback to skylights, smoke -hatches. o Provide minimum 4' setback to roof hatches, including at least (1) 4' access aisle directly to building edge.
o Provide minimum 6' setback from building edge for any buildings with parapet walls 42" orhigher.
o Provide minimum 10' setback from building edge for any buildings with parapet walls 41" or less. Alternatively, EPC contractor may utilize 6' setback from building edge for any buildings with parapet walls 41" or less if permanent, structurally engineered safety tie offs are installed as the cost of
EPC contractor.
o Provide minimum 6'setback from drainage systems, swales, or roof pitches greater than 50 slope.
o Access to every module on rooftops is required - fully `tiled' layouts are not acceptable. At a minimum, a 10" gap is required every two rows for serviceability.
Utilize the following standard ground mount setbacks utilized byForeFront Power:
o Provide a minimum of (1) vehicular gates with specifics to be determined on a case by case basis.
o Provide 15' minimum setback to fencing around PVarray, unless otherwise directed by the AHJ.
o Provide 15' minimum drive aisle to equipmentpad, unless otherwise directed by the AHJ.
o More drive aisles might be required for serviceability to be determined on a case by case basis.
o East-West gaps between racking `tables' in fixed -tilt ground mount projects are required. This gap shall be the larger of 6" and twice the East-West elevation change between the tables. At very flat sites, the gap will be 6". At a site with 12" elevation change between adjacent tables, the gap will be24".
For ground -mounted PV arrays, the site shall be secured by perimeter fencing and gates to secure and isolate the system from the public or on -site operations as applicable. Typical fencing shall include standard tall, #9- gauge wire mesh fencing and wire fasteners with 1' barbed wire at the top.
Fence post foundations shall be engineered to site conditions, and grounded per NEC guidelines.
6.1.c — Module Array Design
Modules shall be grouped and organized in a manner which minimizes the use of jumpers" to complete source circuits.
Group modules to best optimize DC source circuit wiring todisconnecting combiner boxes, and minimize conductor length to theinverter.
Rows of modules shall be grouped in full or half source circuits, for ease of wire routing and grouping.
Modules shall be grouped in a manner that best optimizes the requirements for the specific racking structure, taking into account all design requirements, roof penetration scheme, ballasting requirements, wind loading, and minimizing customization, as well as optimal module to steel ratios when laying out canopy projects with a DSA Pre -Approved Pre -Check Detail.
Provide all relative dimensions from a common reference point, with sufficient detail provided to show conformance to setback and shade requirements, as well as those required to instruct installation crews on field arraylayouts.
All modules feeding a single MPPT must be of the same tilt and azimuth angles.
When site conditions require multiple tilt and/or azimuth angles, utilize multiple MPPT inverters to maximize poweroutput.
Array should be designed with access and washing considerations in mind. Use of
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top clamps that are not flush with top of module frames are prohibited.
6.2 Electrical Requirements
6.2.a — General Specifications
All design elements shall above all others, meet applicable NEC and local AHJ requirements.
All specified equipment shall be designed, and installed per manufacturer requirements, in order to maintain warranties. Provide torque settings for all mechanical/electrical connections.
All specified components are listed by the appropriate NRTL, for their intended use.
Verify module source circuit voltage is within "Inverter MPPT" operatingrange. o Provide calculations for module string sizing, comply to NEC 690.7, or any section more recently adopted by the NEC, using ASHRAE climate data expected temperatures per NEC, for crysta[line only).
Optionally, VOC may be calculated per2017 NEC guidelines under engineering supervision where allowed by local jurisdiction. o Confirm module string sizing VMP is above minimum "MPPT" voltage range for highest expected temperatures.
Overcurrent protection must be provided per NEC 240 as applicable. o Specific attention shall be made to 240.413, 240.4C for choosingappropriately sized devices, or other NEC sections should they be more relevant. o Standards Ampere ratings shall be made from NEC 240.6, or other NEC sections if more relevant.
Specify listed rain -tight fittings where EMT is utilized.
All systems shall have a single point of disconnect on the DC side located within or adjacent to the array locations, accessible and visible for a system operator, regardless of system POCC or Utility disconnect location, for single or multiple inverter systems.
String inverters shall have 1 DC disconnect per inverter.
All aboveground conductors shall be installed in conduit. Conduit shall be spaced and supported appropriately and routed in an organized manner. Direct burial is OK if all codes are met for utility scale projects, subject to confirmation from ForeFront Power, provided that any exposed wires are sleeved in conduit. o String wiring maybe installed within array per NEC 690.31(A). Array must remain not readily accessible. Wiring must be secured to racking and must remain clear of sharp edges.
Canopy systems must utilize RMC conduit above grade up to 8'. Transition to EMT or other metallic conduit is acceptable 8' or higher above grade. Conduit must be encased within concrete canopy foundation.
o If canopy foundations are not 2' or higher or conduit cannot be encased above 2', bollards are required to protect conduit from vehicle strikes unless canopy is not subject to vehicle traffic including maintenance and landscaping vehicles.
Buried conduit shall abide by NEC requirements for depth and cover appropriate to conditions and voltage.
o Where communication lines are required along underground conduit, a
separate conduit minimum 1" shall be utilized.
Where conduit or wire is exposed to direct sunlight, they shall be listed/rated for the appropriate usetype.
Low voltage AC conduit shall be sized to include a neutral conductor in the circuit regardless of planned installation of neutral conductor.
Hardware used to secure modules, ground lugs, and other electrical componentsin outdoor environments to be stainless steel or hot dipped galvanized.
All NEMA 3 and 4 boxes shall be equipped with a listed drain plug (NEMA 3 may use a weep hole) installed to allow water to drain. Any modification made to as - manufactured equipment shall be done in such a way as to maintain all listedratings.
Dry type medium voltage ISU power transformers are to be avoided unless specific conditions warrant the use of dry -type, and will require approval from ForeFront power. Dry -type transformers are only acceptable under 1000kVA for auxiliary power such as DAS, trackers, etc.
6.2.b — Inverter Sizing
Inverter technology must be an approved manufacturer and capable of supporting the intended DAS monitoring solution.
Target inverter DC power input should be best financial outcome that is within allowable equipment specifications.
When preliminary designs are provided by FFP, equipment changes shall match specifications as close as possible to initial design.
Inverter inputs should always reference manufacturer guidelines for the following parameters including:
o Maximum DC watts input.
o Maximum DC amperageinput.
o Approved DC wire size and number inputs.
Inverter MPPT loading must be balanced to the greatest extent possible. Preference is to use parallel MPPT mode when available and minimal impact to design (shading, different string size, different tilt/azimuth, or large difference in distances. o Stringing design must be documented in detail on design drawings. o If stringing cannot be balanced between MPPT inputs, FFP engineering must be informed and approve design.
On occasion, Inverter sizing may exceed recommended parameters for DC system inputs; this must be approved in writing from the manufacturer and not impact available local incentives.
All central inverters, when approved, shall include zone monitoring ordered with the inverters.
All inverters shall be updated to latestfirmware available priorto commissioning.
6.2.c — Equipment Selection
FFP reserves the right to approve or deny any equipment selections.
Prior to installation, ForeFront Power shall review submittals for all proposed equipment. Material submittals must specify make/model/options of equipment to be used; submittals consisting of brochures or cutsheets without markups are not acceptable. Context must also be provided indicating where and how
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equipment is intended to be installed.
All equipment shall be verified for approved use for site specific climate or location features such as elevation, temperature, and intended wiring configuration.
PID, or Potential Induced Degradation, is a phenomenon which occurs in crystalline modules coupled with ungrounded inverters resulting in a gradual loss of power over time. Modules and inverters must be combined in a way that does not allow for the risk of PID. Options include using PID free modules or PID mitigation boxes with ungrounded inverters.
All panelboards and equipment enclosures shall be pad -lockable, when possible and allowable by code.
6.2.d — Equipment Locations
All electrical equipment shall meet minimum working space clearance as required per NEC 110.26.
Provide working space permitting at least 90° opening of all hinged doors.
Comply with NEC 110.26(C)
All equipment shall be installed in a secured location, either by lock orlocation.
Provide at least (1) entrance not less than T wide in fenced locations.
Panel boards and switchboards shall be installed to avoid direct sunlight to the greatest extent possible. if panels/switchboards must be exposed to direct sunlight, then the design and equipment selection must consider the additional heat load and must be designed to avoid derating or nuisance tripping that affects performance. Some recommendations for avoiding excessive heat:
o Spacing panel breakers with spaces between.
o Ventilated enclosures, where possible.
o Upgraded breaker and wire ratings.
o Shade structure to block sunlight.
o If nuisance tripping occurs, external design and construction team must remediate to prevent future nuisance tripping.
Inverters shall avoid direct sunlight and especially southern aspects. o Inverters must be installed in a manner to avoid derating or shutdowns due to excessive heat. This can be accomplished with any combination of the following: installed to avoid sunlight/heat, selecting inverters that can tolerate high heat loads, oversizing inverters to overcome derates (must be acceptable by interconnection approval), constructing shade structure. o If derating or shutdowns occur during operation leading to performance degradation, external design and construction team must remediate inverters.
o East aspects are preferred if the choices are between west, south, and east.
Utility AC Disconnect must be located as close as possible to the POCC, and meet requirements of local AHJ and Utility.
All combiner boxes shall have disconnecting means near the box or integrated as part of the combiner box.
DAS shall be located near inverter and/or PVmeter location. o Direct sunlight and thermal loads must be considered for DAS enclosures. If the
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DAS fails to operate properly due to excessive heat, the DAS equipment must be remediated.
Equipment pads housing Inverters.and other electrical equipment shall be made accessible by location or other means provided by design. Vehicle access with sufficient space for turns should be provided, where located in free field, gravel roads or other means of reliable, all-weather vehicle access shall beprovided.
Systems with multiple inverters and/or transformers in separate locations across the site location should provide a means for a single disconnecting means, located at an accessible point adjacent or within the PV arraysite when connecting to a single POI. o On sites with multiple POIs, each POI shall have a single consolidated disconnecting means.
6.2.e - Grounding, (all system types as required)
Provide PV System grounding in accordance to NEC 250.21, 250.4, 250.24(C) and related code sections as applicable.
Equipment grounding conductors and system ground conductors shall have as short a distance to ground as possible, with minimal turns.
Module source circuits shall be grounded in accordance with NEC690.42.
Enclosures shall be properly prepared with removal of paint/finish when grounding equipment with termination grounding lugs.
The connection to a module shall be arranged in a manner that removal of one module from the source circuit does not interrupt a grounded conductor toadjacent modules.
Grounding system components shall be listed for their use, including but not limited to:
Grounding lugs, ground rods, clamps/crimps. Grounding devices exposed to the climate shall be rated for direct burial.
Modules shall be grounded in accordance with manufacturer requirements, the corresponding UL listing, and the NEC.
o Conductors used for module frame grounding and other exposed metal equipment grounding must be bare
All non -current carrying exposed metal parts of j-boxes, equipment, andappliances shall be grounded per NEC 690.43.
Equipment grounding conductors shall be sized in accordance with NEC 690.45and 250.122 (proportionality adjustment).
Specify a manufactured grounding electrode to be installed within the inverter cabinet, that is corrosion resistant, 5/8" diameter, and minimum 8' driven into soil for central inverter systems.
Comply with NEC 250.166 for sizing of DC grounding electrode conductors and install per250.64.
AC grounding electrode (NEC 690.47(A)), shall be provided in accordancewith NEC 250.50, 250.60, size per 250.66 and installed per250.64.
All PV support structures must be effectively grounded - this should be analyzed carefully, especially for canopy systems. All connections must be conductive surface such as galvanized) to conductive surface material to be considered a path to
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ground. A bolted connection between a galvanized purlin and a painted or primed beam does not establish a ground path. Structural members that support any live parts must either have a path to ground via conductive surface to conductive surface connections or be grounded with a grounding lug and wire.
6.2.f - Disconnecting Means
Provide Utility AC disconnecting means per local Utility requirements and NEC requirements for location and distance.
o Must be on the approved Utility list, or meet the utility minimum technical requirements and must ultimately be approved by the utility. o Means shall be provided to disconnect all current carrying conductors of the PV System from all other conductors in thefacility.
o Disconnecting means shall utilize appropriately sized and specified over - current protection, as well as ratings that meet minimum interrupt ratings per site conditions.
o Disconnecting means shall be pad lockable in both open and closed positions.
All DC conductors shall have disconnecting means per local AHJ requirements and N EC.
When multiple disconnecting means are provided for a single system; disconnects shall be grouped and labeled.
The disconnecting means shall be rated in accordance to690.17.
Disconnecting means shall be provided to allow personnel to safely service fuses per NEC requirements.
6.2.- - Interconnection
Provide detailed design showing method and location of interconnection to the facility.
Interconnection shall be made on the line side of all ground faultprotection equipment.
Service entrance conductors shall be sized for 125% of continuous loads per NEC 230.42 and NEC220.3.
Conductors of size 1/0 or larger are permitted to be run in parallel (NEC 310.4), given conductors are the same length, same material, same size and insulation type, and terminated in the same manner. Note NEC 250.122(F) for parallel conductor sizing and routing requirements.
Comply with NEC 705 for supply side interconnections.
The grounded conductor shall not be less than the minimum size as required by NEC 250.24, design grounding systems in accordance with NEC 250.24, section A)(1) - (A)(5).
Comply with locally accepted version of the NEC. Load -Si de Connection o Conform to AHJ/Utility Requirements -including appropriate version of NEC perAHJ. o
Confirm compliance with NEC705.12 Confirm
compliance to sum of over -current devices, per(B)(2). Connection shall be made at a dedicated circuit breaker or fusible
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disconnecting means, compliant with the switchgear manufacturer's and interconnecting utility's allowable hardware.
Identify any main breaker de -rates and means of de -rating, including any location requirements when required for new breaker installation.
Provide calculations showing capacity to de -rate main breaker when required.
Provide specifications for breaker compatible with existing switchgear, including design for in -rush current.
If utilizing the 120% of the rating of the busbar or conductor allowance, specify that the interconnection breaker will be located at the opposite end from the input feeder or main circuit location. In some cases where there is no opposite end, such as the case with branched or center fed bussing, this 120% allowance may not be utilized. Always consult with ForeFront Power if the bussing is complicated in anyway.
Breaker{shall have GFI protection in accordance with NEC 690.64(B)(3) Exception: Connection shall be permitted to be made to the load side of ground -fault protection, provided that there isground- fault protection for equipment from all ground -fault currentsources. o Sub -Panel connections will be reviewed on a case by case basis -all upstream coordination shall be performed.
Line -Side Connection
o Utilize existing holes in bus -bar- NO physical modification of existing switchgear bus -bar is allowed unless approved by the switchgear manufacturer and can demonstrate that the UL listing is notimpacted. o All above grade conductors below 8' above grade between line -side connection point and first OCPD shall be contained in IMC or RMC. o Confirm appropriate conductor and over -current protection for PV system load and Facility equipment coordination.
o Use appropriate bolt/washer/nut assemblies for bus -bar terminations - Provide torque per device listings.
o Use UL listed crimp by Burndy or ILSCO rated for the system as designed and installed and in accordance with manufacturer's approved crimping device only.
o Any bolted "pad to flat" electrical connection should include a bolt, two flat washers, and the nut- If any flat components are aluminum, utilize a properly designed conical Belleville washer.
o Consult section NEC 230 for treatment of service entrance conductors. Special attention to NEC 230.71 for limitations on number of existing"main breakers", and NEC 230.46 which allows service -entrance conductors to be spliced or tapped in accordance with NEC 110.14 and NEC300. o Note NEC 220.5(B) which permits calculations to drop fractions if lessthan
0.5 ampere.
o Design disconnecting means in compliance with NEC 230.72(A) and 230.70(A).
o Size over current protection per NEC 230.90(A), 230.91, and
NEC 240.4(B,C) for allowable device ratings.
6. 1.h — Metering/Monitoring
ForeFront Power will either (i) provide the EDT or EPC Contractor with a specification of a DAS provider along with required instrumentation, (ii) will approve a specification submittal and list of instrumentation provided by the EPC Contractor. EPC Contractor will ensure that all relevant line diagrams and drawings are included in the engineered drawings.
External Design Team or EPC Contractor shall provide all other metering requirements per local utility and 120VAC outlet for service equipment.
Communication wire should be run directly from PV meter to DAS and shall not run through otherequipment.
Provide appropriate wire size to account for voltage drop for large distances or use of housekeeping transformer at equipmentarea.
Meter potential wires should typically be #12 awg with 2A fusing per meter install, use Milbank TS10-0109 for typical applications.
o C.T. wires typically use #12 awg for short distances, if over 18', need to run 10 awg. Ferrules shall be used on CT wires to ensure proper connection.
Ion 8600 meter does not require 120V, these units are self -powered at 480V from leads.
RS485 cable should be shielded and outdoor rated. DAS to Inverter connections should be fiber optic/PE for large distances. Ferrules shall be used on RS485 wires to ensure proper connection.
Pyranometer and weather station should not shade the array or be shaded by the array or any other obstruction during ALL daylight hours.
UPS should power DAS, Primary Meter, Primary Weather station, modem, switch, protective relay so ForeFront Power can estimate lost production if the grid fails and remotely reclose breakers for all projects over 1MWac. For all projects under 1MWac, a 120Vac outlet shall be provided by contractor to power DAS equipment.
No networking hardware should be connected to DAS production network Ethernet/Fiber TCP/IP without advance approval by ForeFront Power. If additional networking hardware is required i.e. IP camera / surveillance system / DVR. It should be on an isolated LAN from DAS networked components.
The project generation meter should be as close as is reasonably possible to the utility revenue meter'. In particular, the project gen meter should not be reading at LV or on the low side of the step-up XFMR if the utility is metering at MV or on the high side of the XFM R.
MV relays and protective devices with control options shall employ remote control schemes so FFP is able to reset relays. SEL relays are preferred, when available.
6.2.i — Labels & Markings
FOREFRONT
POWER
Provide system labeling and marking details as required by code or utilities for all DC equipment and Interconnection equipment (POCC, AC/DC Disconnects, Inverter, Disconnecting Combiner Boxes, etc.).
Labels and markings shall be etched placards, stickers notacceptable. o Comply to NEC 690.7, 690.17, 690.53, 705.10, 690.54.
o All utility interactive system points of interconnection with other sources shall be marked at an accessible location at the disconnectingmeans. o A permanent plaque or directory shall be provided identifying the location of the service disconnection means and PV System disconnection means. o Label all wiring per NEC required color coding configurations forDC/AC conductors.
All DC and AC equipment must have Arc Flash labels to meet NFPA70E standards, CSA Z462 Electrical Safety Standards, local and national OSHA Standards and per local, state, federal standards and regulations, whichever is the moststringent.
ForeFront Power name and logo is required on allplacards. EPC Contractor and ForeFront Power can discuss options during final design review.
Carport clearance warning signage is required for all arrays located in parking lots or structures. Signage is required at conspicuous locations at the lot or garage entrance and on low side of carport structure.
All canopies in regions with snow load greater than 0 PSF must have warning labels showing danger of falling snow/ice.
ForeFront Power contact info labels to be located every 50' around perimeter fencing of ground mount arrays.
6.2 j - Wiring
Wiring and Wiring Methods" provided in E.100 Electrical Notes are provided for guidance only.
Terminations shall use approved wiring types and connectors. o All terminations shall follow manufacturer spec torques. o All termination fasteners or mechanical lugs shall utilize torque marks after torquing to spec.
Straight above grade conduit runs, 100' or more, shall employ expansion fittings.
Use listed Bridgeport Rain Tight connectors or equivalent; seal all other electrical connections with climate resistant cau[king.
Show module source circuit groupings per disconnecting combiner box, label disconnecting combiner boxes numerically, in a logical order- show location of disconnecting combinerboxes.
Module connectors must use same manufacturer and model as the factory installed inter -module connectors.
o No connector shall be mated to a connector of a different brand unless approved by both manufacturers in writing with accompanying listing documentation approving the mating pair.
o Factory installed module connectors cannot be removed/replaced unless correcting defective connectors and approved by module manufacturer to maintain warranty.
FOREFRONT
POWER
o If module connectors are not compatible with equipment with built-in connectors (micro -inverters, rapid shutdown, module level power electronics, combiner boxes, string inverters, etc.), jumpers must be utilized to mate connections.
Follow all manufacturer instructions for installation of wire connectors. o Use of manufacturer specific tool is required unless manufacturer explicitly allows use of other tools.
Wire connectors shall be installed to reasonably avoid possibility of pooled water.
Wire connectors shall not be installed in direct sunlight. Show on plans conduit routing for DC and AC conduits - Size and locate pull boxes in accordance with NEC 314.28, 358.26.
Direct burial of conductors is allowed provided all direct burial conductors are listed for such use and 1/0 AWG or larger.
Provide all construction details required for equipment grounding, including but not limited to: Modules, Racking, Conduit, Equipment enclosures, Inverters, Equipment Pad (Fence, Shade structures), and Facility interconnection.
Provide construction details for conduit supporting methods, for rooftop, roof to ground transitions, and all AC conduitrouting.
Conduit on rooftop must be secured to sleepers/strut and not make direct contact with the roof surface (except for conduit roof penetration, if applicable.
Use of PVC conduit on rooftop is prohibited.
All wiring exposed to direct sunlight must be covered in split -loom type protection, or equivalent. This applies to wiring spanning a gap longer than typical module -to - module gaps (approx. I"). This applies regardless of wire sunlight rating.
Show on plans inverter location and installation details including:
o Equipment orientation and required clearances, Inverter grounding design, DC Conduit entry and routing.
Direct burial of conductors is allowable provided all direct burial conductors are listed for such use and 1/0 AWG or larger.
Conduit routing shall not employ top -entry routing to new and existing switchboards, panels, inverters, or any other enclosure to the greatest extent possible for avoidance of moisture ingress.
o If top -entry must be employed, the following stipulations apply:
Written consent from FFP in form of RFI response.
Use of sealed conduit fittings and Meyers Hub (OAE) and all appropriate sealants.
Top conduit entry point must be positioned to avoid dripping on breakers, bus bars, terminations, and any other equipment within enclosure.
Use of drip loops within enclosure to avoid potential moisture ingress onto contained equipment.
Weep holes (or equivalent) so moisture will not build up within an enclosure.
Show on plans location forAC Disconnects, metering, monitoring and any other
FOREFRONT
POWER
accessory AC equipment. Demonstrate mounting methods and conduitrouting.
Provide 1-line diagram or 3-line diagram including the following o All conductors sizes and types (including ground/neutral), including sizing calculations.
Include reference temperatures forde-rating.
Reference NEC 2005 - 310.10 FPN No.2.
Reference NEC 2008-310.15(B)(2)(c).
N Include NEC 690.4(A)(1) & (13)(1), NEC240.
Include NEC 690.7 for multiple conductors.
Use 750C for wire sizing when any terminal is rated for 75°C. 900C may only be used when all terminals and fittings are rated 90°C.
Use 690.8(A)(1) & (B)(1) for all DC sizing for over current protection, equipment, and wire sizing.
Provide wiring schedule for all DC and AC systems.
o All source circuits shall have individual source circuit protection. o Fuses and wires subject to transformer in -rush current shall be sized accordingly.
o Provide voltage drop calculations for DC and AC wiring including estimated distances for each raceway. DC voltage drop should not push voltage below inverter MPPT window. AC voltage drop should not push voltage below inverter's ability to match gridvoltage.
All splices must be made in approved J-boxes, with an approved splicing method - i.e. connecting 2 different wire sizes together, that provides an irreversible means. Use Burndy crimp type compression connector suitable for wire type and size, comply to NEC 300.15. Lug type connections for conductor splices is not an approved method.
All conduit shall be supported within 3' from enclosures and every 10' thereafter - there should not be more than total of 3600 of bends between pullpoints.
Specify RNC (PVC - NEC 352), schedule 40 for underground locations - comply with NEC 300.5 for proper coverage.
All conduit above grade must be metallic (EMT, IMC, RMC) with the exception of stub ups to equipment maximum 4' height.
Conduit shall be sized in accordance with NEC Annex C, with appropriate attention to conduit and conductor type matching.
Conduit bodies (LB, LL, LR, etc.) are allowable with the following stipulations:
o Conduit bodies must not contain sharp edges that can damage conductors.
o Conduit body volume and bend radii must be considered when sizing conduit bodies.
o Conductors must be properly secured to avoid excessive strain on conductors within the conduit body.
For Bi-Polar systems and pull sections, it may be possible to manufacture 1200 volt differential between conductors, so Positive and Negative DC conductors in Bi-Polar systems shall never share conduit, pull boxes, or any enclosure unless explicitly listed to maintain a 600V rating while doing so."
Protect string wire when jumping more than 1" between adjacentmodules.
FOREFRONT
POWER
ForeFront Power encourages the use of aluminum conductors due to the cost benefit.
However, it is the responsibility of the design partner to engineer and design the system entirely and ensure proper design and installation of any material Use Schedule 80 conduit above ground for all underground to aboveground conduit transitions.
Canopy system conduit stub -ups shall be routed inside concrete foundation. If conduits or equipment is subject to vehicle damage, bollards or other approved methods of protection are required.
o Canopy system vertical conduits must be RMC up to 8' above grade.
Ferrules or other listed connections shall be utilized for mechanically and electrically joining metallic conduit sections. if such listed devices are not utilized, the conduit section may not be used as grounding conductor.
Where cable tray is employed outdoors, the conductors must be listed for use in cable tray. The cable tray must utilize a ventilated cover or conductors contained in sunlight protection (split loom, OAE).
6.2.k — Mediurn Voltage
Transformers
o Comply with NEC 450.3 for overcurrentprotection.
o Comply with NEC 690.15 for disconnecting means.
o Bolted to pad and sealed if any gaps in the pad, verify transformer islevel. o Power cable and equipment grounding conductor installed in a mannerthat will allow for easy removal and standing off ofelbows.
o Tape shield adapter kits used with power cable that has tapeshielding. o NEMA drilled long barrel compression lugs used for low voltage wiring, low voltage wire routed to provide access to oil drain valve and sampleport. o Specify use of lock or conical nuts.
o Non-magnetic hardware used for all current carryingconnections. o MV and LV conduits are separated and under their own compartment. o Appropriate sized gravel in the bottom of the Xfrmr pad window. o Provide danger signs on doors, statement of voltage, power cables labeled. o Provide surge arrestors to mitigate potential of any traveling wavecurrents. o Specify Penta-bolts on equipment enclosuredoors.
o Specify stainless steel hardware forconnections.
o MV transformers shall have low oil level and high temperature alarm contacts.
Systems with MV interconnections shall meter production at the MV interconnection voltage.
Provide danger signs on doors of equipment, statement of voltage, with power cables and transformers labeled.
Dead break/ Load break elbows shall be specified copper type or approved equivalent.
Provide current limiting fuses on the HV side of the transformer in series with Bay- 0- Net fuses or per transformer MFR designs/recommendations.
Provide appropriate working space allowing for use of safety equipment to stand-off of elbows, ensuring enclosure doors will open to the fullest extent without obstruction.
FOREFRONT
POWER
MV conductors, when routed between Delta connections, should be rated for 173% insulation.
Confirm design allows for proper pulling tension for MV conductor for given distance and degrees of turn. Provide transformer foundation design perapplicable codes and standards.
Provide transformer grounding details per applicable codes and standards.
Provide conduit routes to pull transformer control and monitoring wiringas required.
The transformer shall be capable to provide monitoring points per systemoperator requirements (see above for monitoring contact requirements).
Provide transformer electrical connection details including all cables, connectors, elbows, surge arrestors and all applicable fittings specifications.
Transformer impedance values shall be design to meet the system needs,consult system designer for appropriate transformerimpedance.
Determine transformer is capable to handle the system load flow and potential overload conditions through a professional calculations and/or softwaremodel.
Provide transformer protection from overcurrent and other fault conditionsbased on circuit needs.
All equipment shall be tested to IEEE and ANSI/NETA standards prior to acceptance and startup.See ForeFront Power MV Testing document.
6.2.1— Electrical Requirements for Landfills
Use cable tray systems for DC wiring and runs from arrays toinverters.
AC runs from inverters to substation/point of interconnection are normally direct burial or buried conduit, may be required to run through above -ground conduitdue to restrictions with cap penetration or settlement concerns.
AC equipment and associated supporting equipment pads should be verified as within landfill cap weight requirements, if located on thecap. ' Electrical grounding is a standard design consideration for all PV systems. In landfill applications, PV systems should be grounded into the soil either in buffer areas or into the landfill cap material if it is determined that the material and thickness of the cap is sufficient to dissipate the electrical charge. If the PV system is grounded to the landfill cap, grounding, rods should not be installed vertically such that theypenetrate the landfill cover and protrude into the waste material, as this poses a fire and explosion hazard due to the presence of landfill gas. Any protrusion through the landfill cap should be reviewed and approved by a licensed professional engineer and the local jurisdiction.
6.2.rn — Electrical Calculations
Show how grounding design is related to soil electrical resistivity measured in soil during geotechnical investigation.
Show that temp rise due to ohmic losses for any underground conductors will not exceed temperature rating of wire, and is be tied to measured thermal resistivity of soil in geotechnicalresults.
6.g Structural
Provide module racking specifications from manufacturer, materials list, and installation guidelines.
o All racking to have appropriate level of climate protection. o Racking shall be designed for minimum 30 year lifetime. o All dissimilar metals should have measures for isolation, all fasteners shall be corrosion resistant appropriate for siteconditions. o
All connections should have listed torque ratings per device listing or engineered values. o
Structure shall allow for unrestricted airflow tomodules. o Structure shall be rated for site specific wind speed and exposure. o Structure shall be designed to meet local snow or seismic conditions. o Module mounting method and racking structure shall comply with module manufacturer' s product requirements for mounting hardware and locations. o Canopy systems located within 5.0 miles of the coast shall utilize hot dipped galvanized finish for structural steel, unless directed otherwise. Provide roof integration details including measures for ballasted systems, or roof attachment locations and methods. Include any details for roofing requirements. It is the External Design Team's responsibility to verify roofing requirements, and adherence to manufacturer guidelines for maintaining warranties, for integration of racking structures. Provide
ground foundation details and specifications including measures for ballasting, concrete caissons, spread footings, or piles as applicable. Include any measures required to mitigate corrosion sources as identified in the soils report, including ground water. Concrete type and anti -corrosion coatings must be selected using soil corrosivity measurements from geotechnicalinvestigation. Provide construction detail(s) for array piles, including pile type, pile size, embedment depth, stick-up height, spacing, etc. Include pile layout plan including any special spacing for corner zones, edge zones, and interior zones ofarrays. Incorporate recommendations provided by Geotechnical report for design andsite work, ensuring the Structural FOR has included site specific design in conjunction with soils report. All
concrete work shall provide required strength (PSI), water content, and anyother applicable concrete mix specifications. All special inspections required for slump and concrete breaks will be adhered to and test results will be provided to ForeFront power. o
Plans to indicate appropriate curing time as it applies to application and site specifics. o
Contractor to verify strength of concrete through laboratorytesting. Show on plans structural roof members and typical sizes/spacing forpositively attached structures or ballasted structures. Provide
inverter equipment pad construction details including: o Equipment pad details -i.e. concrete pad construction.
FOREFRONT
POWER
o Inverter mounting details.
o Shade structure is required for all exposed inverters unless written production guarantee is provided by the manufacturer.
o Fence and gate assemblies forsecurity/safety.
o Skids.
Provide fencing details and service access paths for ground mounted projectsas applicable.
All fabrication and manufacturing shall be performed by certified individuals in approved assembly and fabrication shops.
Provide on plans, approved locations and conditions for equipment storage on roof- top, verified by a licensed structural engineer of record.
6.3.a - Stl'U&Ural Cai.CULatioti Packages
Provide structural calculations package to include:
o Clear reference is provided to applicable codes, standards, and any local ordinances governing the design (for example, 2012 IBC, ASCE 7-10, ADM1- 2010) AISI S110- 07/S1-09, AISC 360-10, ACI 318-11, etc.). o Summary of all basic design loads (dead, wind, snow, seismic), with references to the specific sections of applicable codes and standards from which design loads are derived.
o For wind load, identification of design wind speed, Risk Category, Exposure Category, magnitude and source of wind pressure coefficients, etc.
o If wind pressure coefficients are derived from wind tunnel testing, the wind tunnel test report must demonstrate conformance with ASCE 7 wind tunnel method (i.e. testing performed in a boundary layer wind tunnel). o Summary of combinations of load, including identification of governing load combinations and final design wind loads (uplift, downforce, drag, moments).
o Calculations take into account.the specific project site and specific geometry of the system (i.e. tilt, row spacing, height, etc.). o Structural calculations for roof mounted systems should verify that existing structure can withstand weight of PV system and include calculation for roof attachment.
o Structural calculations for roof -mounted systems must demonstrate compliance with 2018/2021 IBC section 503.4.
o Structural calculations from ground or canopy projects shall include calculations for the racking system and for piles/foundations of racking system (must be tied to geotechnical results and pile testing results when used).
o Structural calculations shall include module attachment (required for canopy systems though this may not be part of the standard calculation package).
Section 7: Equipment Specifications
EQUIPMENT REGULATORY SPECIFICATIONS
U L 1703
IEC 61215 for Crystalline Meets site specific climate conditions i.e.
Modules IEC 61646 for Thin Film temperature, humidity, PSF NFPA 70-Class C Fire Utilizes recognized grounding
NEC including Series Fuse rating methods/components(lay-in-lug) CEC Listed (CA only)
UL 1741
Outdoor rated - NEMA3R
Inverters IEEE 1547,519
Meets site specific climate conditions
CEC Listed (CA only)
DAS Monitoringconfigured
Inverter level combiner
NEMA 3R minimum, Steel
Ambient Temp - (-20°C -50°C)
Combiner Boxes UL 1741 Standard Accessory 1000VDC rated components (1500 VDC rated where applicable).
Copper bussing, compression fittings or
mechanical lugs forterminations
DC Disconnects
All applicable NEC, UL, ANSI, and NEMA 3R minimum, Steel NEMA requirements UL Listed
All applicable NEC, UL, ANSI, and
208 - 600VAC as required
AC Disconnects
NEMA requirements
NEMA3R
Fusible, Visible, Lockable
Bolted construction
Outdoor NEMA 3R,finish coat ANSI #61
Equipment bears the ULlabel
Copper bus bars
All applicable NEC, UL, ANSI, Silver plated connections Switchgear
NEMA, and Utility requirements Meets interrupting current ratings Underground cableentry
Ring type connection,13 jaw sockets
Ground Fault trip unit integrated switch,
open jaw verification window
120V receptacle provided
MeteringAll applicable NEC, UL, ANSI,
Utilize Ion 8600 - Form 9SMeter, or other as
NEMA, and Utility requirements approved by ForeFront Power Revenue Grade C.T.'s - Bar -type, unless
otherwise approved by ForeFront power
Provide 120VAC/2KVACPT
Monitoring Applicable NEC, UL,ANSI,NEMA DAS Only
Conduit
EMT UL 797, NFPA 70, ANSIC80.3 Galvanized orequivalent
IMC UL 1242, NFPA 70, ANSIC80.6 Galvanized orequivalent RMC UL 6, NFPA 70, ANSI C80.1 Galvanized orequivalent
Corrosion resistant
PVC UL 651, NFPA 70, NEMATC-2 90°CRated
Schedule 40 or 80 asappropriate
Section 8: Glossary of Terms
The following terms and definitions are covered in this document:
TERM DEFINITION
AlternatingCurrentAC
AHJ Authority Having-lurisdiction
ALTA American Land Title Association
BOM Bill of Materials
BOS Balance of System
CAD Computer -Aided Design
CUR Covenants, Conditions, and Restrictions
CEC California Energy Commission
CEQA California Environmental QualityAct
COGS Cost of Goods Sold
CPT Control PowerTransformer
CSA Canadian StandardsAssociation
CT CurrentTransformer
DAS Data Acquisition System
D&E Design and Engineering
DC Direct Current
DWG Drawing (Standard AutoCAD File Extension)
ECO Engineering ChangeOrder
EMT Electrical MetallicTubing
FOR Engineer of Record
EPC Engineering, Procurement, Construction
ETL Electrical Testing Labs
FAA Federal Aviation Administration
GCR Ground Coverage Ratio
HVAC Heating, Ventilating, and AirConditioning
IAEI International Association of Electrical Inspectors IEEE Institute of Electrical and Electronics Engineers
ISC Short Circuit Current
TERM
L&M
DEFINITION
Labels and Markings
MPPT Max Power PointTracking
MSE Main Service Entrance
NEC National ElectricalCode
NEPA National Environmental PolicyAct
NREL National Renewable Energy Laboratory
NRTL Nationally Recognized TestingLaboratories
OCPD Over Current Protection Device
O&M Operation and Maintenance
OSHA Occupational Safety and Health Administration
PDF Portable Document Format (Adobe° Acrobat®)
POCC Point of Common Coupling
PSI Pounds per Square Inch
PV Photovoltaic
ROW Right of Way
SLD Single Line Diagram
SOW Scope of Work
SPSA Solar Power Services Agreement
THHN Thermoplastic High Heat-resistantNylon-coated
THWN Thermoplastic High Water-resistantNylon-coated
TMY Typical MeteorologicalYear
UL Underwriters Laboratory
UPS Uninterruptible PowerSupply
USE Underground Service Entrance
USFWS U.S. Fish and WildlifeService
VmP Voltage Maximum Power
Voc Voltage Open Circuit
Our adjustable and durable frame features'less hardware, integrated electrical"bonding, and included wire management resulting in reduced labor hours. Installation times are shortened by up to 36%through simplified connections, agile parts, and seasoned field teams. Foundation consultation from an unbiased partner, based on your unique project site. No matter the terrain or weather, we'll provide the'right solution. Our versatile design enables numerous configurations allowing us to meet your unique needs. and bring solar to more -fields.
Portrait up to 3 high x 12 wide
Benefits
Less hardware for faster installation and reduced
labor hours
Simplified hardware featuring 2-piece bolt stacks and
only two types of hardware
Adapts to steep slopes
Foundations for any terrain
Included wire management
Specifications
Landscape up to d. high x o Mde
Bifacial compatible
Lighter, stiffer components for less freight costs
Versatile with numerous configurations
Durable, tolerating up to 170 MPH winds and 100 PSF
ground snow loads
Landscape orientation is bifacial compatible to maximize potential backside power yield
Module orientation Portrait or Landscape
Module mounting Bottom mount / Integrated electrical bonding Tilt angle 5°- 35°
Wire management Incorporated in structure - NEC compliant Configuration Portrait: up to 3 high x 12 wide / Landscape: up to 4 high x 6 wide Slopes East or West facing, up to 30% / North or South facing, up to 36% Load capacities Project specific: up to 170 MPH wind speed and 100 PSF ground snow load Foundations Ground screws / Driven piles
Warranty — - — — — -- — 20 year limited warranty
Certifications UL2703, edition 1; CPP wind tunnel tested iimv.terrasnar-,-%-om4-i-.. • u. .0
Q,PEAK DUO XL-G11S JIM
SERIES acells
585-60OWp 1156Cells
21.5% Maximum Module Efficiency
MODEL O,PEAK CAJO Aw(311S. 'SFG
ITBifacial energy yield gain of up to 21%
Bifacial Q.ANTUM solar cells make efficient use of light shining on the module rear -side for radically improved LCOE.
Low electricity generation costs
Q.ANTUIM DUO technology with optimized module layout to boost module power and improve LCOE.
A reliable investment
Double glass module design enables extended lifetime with 12-year product warranty and improved 30-year performance warranty'.
Enduring high performance
Long-term yield security with Anti LID and Anti PID
ocells TechnologyZ, Hot -Spot Protect.
Frame for versatile mounting options
High-tech aluminum alloy frame protects from damage,
enables use of a wide range of mounting structures and is certified regarding IEC for high snow (5400Pa) and wind loads (2400Pa).
Innovative all-weather technology
Optimal yields, whatever the weather with
excellent low -light and temperature behavior.
See data sheet on rear for further information.
APT test conditions according to IEC/TS 62804-1:2015 method B I-150011, 168 h) including post treatment according to IEC 612154-1 Ed 2.0 (CD) The ideal solution for: °"^ '• wnvonea w
Ground -mounted
ELid :ozx
solar power plants —
PEAK DUO XL-G11S SERIES
Mechanical Specification
Format 96.9in x 44.6in x 1.38in (including frame)
2462 mm x 1134 mm x 35 mm)
Weight 76.9lbs(34.9kg)
Front Cover 0.08 in (2.0 mm) thermally pre -stressed glass w m' •_- qr* a, 9s osam-, ` 3 °•
with anti -reflection technology
Back Cover 0.08 in (2.0 mm) semi -tempered glass m,
Frame Anodised aluminium
Cell 6 x 26 mon,ocrystalline Q.ANTUM solar half cells
El
3 esomn
Junction box 2.09-3 98 x 1.26-2 36 x 0 59-071 in (53-101 mm x 32-60 mm x 15-18m1`11). C,3 x 1: ':" Protection class IP67, with bypass diodes
Cable 4mm2Solar cable; (+)>-29,5in(750mm),(-)>-13.8in(350mm) Connector Staubli MC4. Staubli MC4-Evo2, - IP68 Electrical
Characteristics MINIMUM
PERFORMANCE AT STANDARD TEST CONDITIONS. STC' (POWER TOLERANCE -5 W / -0 W) BSTC' BSTC' BSTC' BSTC' Power
at MPP' P1°.,, (W] 585 639.9 590 645.4 595 650.8 600 656.3 Short Circuit Current' Isc [A] 13.72 15.01 13.74 15.04 13.77 15.07 13.80 15.10 C E
Open Circuit Voltage' V,, [V] 53.57 53.76 53.60 53.79 53.63 53.B2 53.66 53.85 Current at MPP I,,,., (A] 13.07 14.30 13.12 14.36 13.17 14.41 13.22 14.46 Voltage at MPP V„c, IV] 44.75 44.74 44.96 44.95 45.18 45.17 45.39 45.38 Efficiency' 1`7 (%] 221.0 z211 2!213 221.5 Bifaciality
of P_ and 1, 70%±5°a • Bifaciality given for rear side irradiation on top of STC (front side) • According to IEC 60904-1-2 Measurement tolerances PI,,,, =3 %; I,r, V, ±5 °5 at STC: 1000 W/m2, 'at BSTC: 1000 W1m2 * cD x 135W/m2. (= 70%±5g5, 25±2'C. AM 1.5 according to IEC 60904-3 MINIMUM PERFORMANCE AT NORMAL OPERATING CONDITIONS, NMOT2 Power at MPP P,[NJ] 440.5 444,2 449.0 451.8 E
Short Circuit Current I,c [A] 11.05 11.07 11.09 11.11 E Open Circuit Voltage V_ [V] S0.67 50.69 50.72 50.75 c- - - - ---- --- -- - --- -- -- ----- - - -- ---- -- . - - - 5 i
Current at MPP Ii [A] 10.30 10.34 10.38 10.42 Voltage
at MPP - - - - -- V,ec, [
V] - - - 42.79 --- -- 42.97 - - -- - - 43.15 - - -- - - - 43.34 -. Measurement tolerances P,,,,. ±3 %,1,; V x =5 % at STC. 1000W/m2, 25±2 °C, AM 1.5 according to IEC 60904-3 • 2800 W/mz, NMOT, spectrum AM 1.5 acells PERFORMANCE WARRANTY PERFORMANCE AT LOW IRRADIANCE pg
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least 98% of nominal power P' o
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Full warranties in accordance
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terms of guarantee for the 5 PV c-panles mtb the Typical -nodule performance uncer fow ufmiance cor:ti.ti . in highest production capadty in 2021 (Februar/ 2021) companson to STC condi!ions (25'C, T000WIrn't TEMPERATURE COEFFICIENTS Temperature
Coefficient of Isc o [%IK] +004 Temperature Coefficient of Voc (3 1%/K] -0.27 Temperature Coefficient of P /K -034 Nominal Module Operating Temperature NMOT 108± 5 4 w,
e '/ [`a )
P 9 P [ (42±
3'C) Properties
for System Design Maximum
System Voltage Vsys V1 1500 PV module classification Class II Maximum Series Fuse Rating A DC] 30 Fire Rating based on ANSI/UL 61730 TYPE 29' Max.
Design Load, Push/Pull' Ibs/112) 75 (3600Pali r33 (1600Pa) Permitted Module Temperature 40'F up to+185'F Max. Test Load, Push/Pull' lbs/ft2) 113 (5400Pa)/50 (240OPa) on Continuous Duty 40'C up to +85'C) 3 See Installation Manual New Type is similar to Type 3 but with metallic frame Qualifications and Certificates UL 61730.
CE-compliant, 1 IEC 61215:
2016, IEC 6
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solar cells) io unno:
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Qcelis Sales Representative for details regarding the module's eligibility to be Buy American Act (BAA) compliant. I-•w--'-• Qcells pursues minimizing paper output in consideration of the global environment. tdote Installation instructions nc ha
OCELLSAmericamustbe
followed Contact our technical service for funkier informavon on aoproved instailabgn of this product I I H-I400SprumectCenterDrive. Suae 1400, Irvine. CA 92618. USA i TEL •1 949 748 59 96 1 EMAIL hquwnquiryagcells com I WEB gcells coin ce
SUNSYS HES V
Modular outdoor Energy Storage System
from 50 WA / 186 kWh to 550 WA / 1116 kWh systems
1 0 ®
I t J l 3
1 1
SUNSYS HES L is an outdoor system that merges proven individual technologies to create a more efficient all -in -one solution. Partnering with CATL, Socomec has selected the EnerOne liquid cooled LFP battery system as the optimum battery for SUNSYS Hybrid Energy Storage.
SUNSYS HES L meets the most stringent safety standards.
The range is available in a variety of sizes and can work both as grid follower and grid -former.
Safety certified
The system combines 2 top quality
components to deliver a winning formula.
CATL EnerOne Liquid -Cooled Battery:
the SUNSYS B-Cab L uses stable Lithium
Iron Phosphate (LFP) battery chemistry. The
battery has passed the large-scale fire test
UL9540A.
Socomec Power Conversion System (PCs):
the SUNSYS C-Cab L uses a safe conversion
technology to limit the common mode noise effect.
SUNSYS HES L is compliant with UL9540-2020:
the latest and most stringent safety standard
for Energy Storage Systems, in both Canada
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Extreme flexibility
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Fast and error -free installation
Battery cabinets are shipped completely
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Reduced maintenance with HVAC replaced
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Environment: RoHS; REACH
Communication protocol:
Modbus TCP; SunSpec 2.0
Grid code: UL 1741 SA/SIB;
UL 1741 ORD; IEEE 1547-
2018; IEEE 1547.1-2020; CA
Rule 21
MET
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Please consult us for additional ones.
Mufti-MWh systems
For larger installations,
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SUNSYS HES V
Modular outdoor Energy Storage System
from 50 kVA / 186 kWh to 550 kVA / 1116 kWh systems
modular units _for maximum flexibility
R3ET79'1 =
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Up to 1005 kg / 2216 Ibs 2280 kg / 5027 Ibs
Bidirectional power converter Lithium ion battery
50 to 300 kVA / cabinet LFP technologyiAutomationfunctions186kWh / rack AC/DC distribution and protection Liquid cooling thermal management Battery management system i > Integrated fire safety, detection and extinction system Integrated EMS
IoT Ready.
I
M_anystem configurations are available_ to meet customer_requirements Energy (kWh)
1 B-Cab 2 B-Cab 3 B-Cab 4 B-Cab 5 B-Cab I 6 B-Cab
Power(kVA) I 186 372
9 558 744 1 930 1116
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System information
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110% during 3o min -125°% during 10 min -150°% during 30 s l Cemistry I _ _ LFP- Lit_hiumIronPhosphate
Energy Nameplate 186 kWh per cabinet
AC/AG Max Bound Trip Efficiency 90°%
Maximum C-rate 0.6 C _
j ftdmum DC current 82 A charging / 87 A dischargingper 50 kVA power module Power rating 50 kW 1— 100 kW I 150 kW 1_ 200 kW 250 kW I 300 kW f AC rated current 60 A 120 A —1 1 00 A _ 241 A I 3 11 A 3 11 A _ SAC max: temporary current (overload) 90 A l _ 18OA +1 2 11 A 3 11 A __F 51 A _ 541 A AC, AC cow I Up to4 x 95 mm2/3/0AWG - 3x 150 mmz13O01VICM,- 2 x 185 mm2/35OMCM Rated voltage (U!)) I 480 Vac (3ph+N) ±2O%
I Rated frequency 60 Hz ±5°%
Fire tecc n I Fire Safff—y§y—stem Including smoke detectors, heat detectors and aerosol Environment
Degree of protection IP_55 / NEMA 3R{Outdoor) _
Operation temperature I -20 to +45 C° / -4 to +113°F without derating j`Storagetemperature _ I _-20to+60C°/-4to+140°F
i Awustic level at 1 m _ <64.8 dB
Maximum attitude 1000 m 13280 ft without derating (consult us for requirements above this) .,_._ Two sy"stem installation optioisYacc®rding';to "fhespace_ available On-line installation
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CITY OF FAIRFIELD
RESOLUTION NO. 2024-213
RESOLUTION OF THE CITY COUNCIL OF THE CITY OF FAIRFIELD AUTHORIZING THE CITY
MANAGER TO EXECUTE A POWER PURCHASE AGREEMENT WITH ONYX DEVELOPMENT GROUP LLC. FOR THE PROVISION AND OPERATION OF A SOLAR FIELD AT THE WATERMAN
WATER TREATMENT PLANT
WHEREAS, the City conducted a study to determine the feasibility of investing in solar infrastructure at the Waterman Water Treatment Plant (Waterman WTP); and WHEREAS, the feasibility study yielded positive results in regards to potential energy saving at the Waterman WTP; and
WHEREAS, staff is seeking to move forward with a design -build, Power Purchase Agreement PPA) model for the solar infrastructure based on the results of the study; and WHEREAS, the City released a Request for Proposal (RFP) for the solar PPA design -build project at the Waterman WTP; and
WHEREAS, Onyx Development Group LLC. (Onyx) provided the most advantageous system, schedule and pricing to the City; and
WHEREAS, the City is required to meet regulatory deadlines to maintain its Net Energy Metering NEM) 2.0 program status for maximum savings; and
WHEREAS, the City provided two weeks' notice of this public hearing and held a public hearing on this matter pursuant to Government Code section 4217.12.
NOW, THEREFORE, THE COUNCIL OF THE CITY OF FAIRFIELD HEREBY RESOLVES:
Section 1. That the anticipated cost to the City for thermal or electrical energy or conservation services provided by the energy conservation facility under the contract with Onyx will be less than the anticipated marginal cost to the City for thermal, electrical, or other energy that would have been consumed by the public agency in the absence of those purchases.
Section 2. That the difference, if any, between the fair rental value for the real property subject to the facility ground lease and the agreed rent is anticipated to be offset by below -market energy purchases or other benefits provided under the energy service contract.
RES. NO. 2024-213
Section 3. The city manager or designee is hereby authorized and directed to execute the attached PPA with Onyx.
Section 4. The council further authorizes the city manager or designee to take all steps necessary to implement this resolution.
PASSED AND ADOPTED this 20th day of August 2024, by the following vote:
AYES: MEMBERS: $ ER rRII / CARR /PANDURO / TONNESEN/ VACCARO / WILLIAMS NOES: MEMBERS:
ABSENT: MEMBERS:
ABSTAIN: MEMBERS:
b- e r+ay,.
MAYOR CVi ca)
ATTEST:
64+--
CITY CLERK
Muv
Agenda Item No: K.10
AGENDA REPORT
DATE: September 16, 2025
TO: Mayor and Council
FROM: David Gassaway, City Manager
SUBJECT: Resolution 2025-184 PW Midway Meadows Subdivision Improvements Acceptance
Accepting Midway Meadows Subdivision Improvements as Complete
Funding Source: N/A
Contact: Roger Dunham, (707) 428-7478
RECOMMENDED ACTION
Adopt resolution.
STATEMENT OF ISSUE
Adoption of the resolution will formally accept the subdivision improvements for the Midway Meadows Subdivision (Subdivision) as complete.
DISCUSSION
Discovery Builders, Inc. (Developer) has completed all the required improvements for the subdivision in accordance with the subdivision improvement agreement a dopted by the City Council on December 19, 2023, by Resolution No. 2023-300. The Subdivision consists of 14 single- family residential units at the exiting terminus of Midway Road, located approximately 0.25 miles west of the Beck Avenue and Woolner Avenue intersection.
As part of the improvements, the Developer constructed new curb, gutter, and sidewalk along Midway Road and connected new water and sewer mains to the existing public utility infrastructure in Midway Road. Additionally, the Developer installed a new double detector check assembly and sewer manhole at the Midway Road frontage to demarcate the limit of private versus public responsibility and replaced the existing public streetlight fixture with a light emitting diode (LED) fixture.
Staff has inspected the subdivision improvements and found them to be complete in accordance with City standards and the requirements of the subdivision improvement agreement. The final punch list was completed on July 17, 2025 . The proposed resolution accepts the subdivision improvements as being complete, except for the obligation of the Developer to repair or reconstruct defective work for a period of one year after final acceptance.
FINANCIAL IMPACT
Acceptance of the public improvements by the council will obligate the City to maintain the public improvements, which include sidewalks, streetlights, water, and sewer utilities. On-going maintenance for the public improvements will be funded by the City’s General Fund and Water Enterprise Fund. The Developer created a Maintenance Association to govern common interests shared among the residential lots. All new landscaping installed as part of this development shall be privately owned and maintained by either the Maintenance Association or the homeowners.
PUBLIC CONTACT/ADVISORY BODY RECOMMENDATION
N/A
ALTERNATIVE ACTION
If the council has any questions, acceptance may be delayed so that staff may provide the necessary additional information.
COORDINATED WITH
N/A
STAFF CONTACT
Roger Dunham, Public Works Construction Manager
(707) 428-7478
[email protected]
ATTACHMENTS
Attachment 2: Proposed Resolution
CITY OF FAIRFIELD
RESOLUTION NO. 2025-184
ACCEPTING MIDWAY MEADOWS SUBDIVISION IMPROVEMENTS AS COMPLETE
WHEREAS, the City Council executed an improvement agreement with Discovery Builders, Inc (Developer) for the Midway Meadows Subdivision on December 19, 2023, by Resolution No. 2023-300; and
WHEREAS, the Developer has completed all the required improvements in accordance with the improvement agreement approved by the council.
NOW, THEREFORE, THE COUNCIL OF THE CITY OF FAIRFIELD HEREBY RESOLVES:
Section 1. The City hereby accepts the improvements as complete pursuant to the improvement agreement between the City and the Developer approved by the council on December 19, 2023.
PASSED AND ADOPTED this 16th day of September 2025, by the following vote:
AYES: MEMBERS: MOY/BERTANI/CARR/PANDURO/SANDHU/TONNESEN/WILLIAMS NOES: MEMBERS: _________________________________________________ ABSENT: MEMBERS: _________________________________________________ ABSTAIN: MEMBERS: _________________________________________________
_________________________________________________
MAYOR
ATTEST:
___________________________
CITY CLERK
Agenda Item No: K.11
AGENDA REPORT
DATE: September 16, 2025
TO: Mayor and Council
FROM: David Gassaway, City Manager
SUBJECT: Resolution 2025-185 PW – Jepson Parkway Phase 2B-2C National Environmental Policy Act Revalidation
Authorizing the City Manager to Execute a Professional Services Agreement with LSA Associates, Inc., to Provide Environmental Services to Support National Environmental Policy Act Revalidation for the Jepson Parkway Phase 2B-2C
Funding Source: $300,000; Capital Streets Fund
Contact: Alvin Lei, (707) 428-7476
RECOMMENDED ACTION
Adopt resolution.
STATEMENT OF ISSUE
In 2022, the City secured a $4 million federal grant to construct widening improvements to Vanden Road – Segment 19 (Jepson Parkway Phase 2C). The Federal Highway Administration (FHWA) administers this grant and requires the City to revalidate the environmental assessment for Segment 19 and ensure consistency with the National Environmental Policy Act (NEPA). The City desires to retain the professional services of environmental consultation company LSA Associates, Inc. (LSA) to prepare and submit the necessary documents to the FHWA to revalidate and finalize the NEPA documents for the Vanden Road – Segments 17a, 17b, and 18 (Jepson Parkway Phase 2B) and Jepson Parkway Phase 2C.
DISCUSSION
On June 26, 2011, the City Council adopted Train Station Specific Plan, including proposed improvements to Vanden Road, and its accompanying environmental impact study (EIS). Since FHWA’s initial approval, Vanden Road’s alignment was shifted further away from existing Vanden Road and elevated to support removal of the at-grade railroad crossing. As such, the FHWA required the City to revalidate the EIS in order for the City to use grant funding towards constructing Jepson Parkway Phase 2C.
Public Works is revalidating the EIS for Jepson Parkway 2B as part of this effort. Although the FHWA does not require revalidation for Jepson Parkway 2B since the City is funding this segment through local and developer funds, City staff support revalidating this segment to maintain consistency with the overall EIS for Jepson Parkway.
FINANCIAL IMPACT
The professional service agreement with LSA for environmental services will authorize a contract for an amount not-to-exceed $300,000. Funding for Jepson Parkway 2C was previously allocated in the fiscal year 2025-2026, and the agreement will be funded by the Capital Streets Fund (Fund 252; CPW070108).
PUBLIC CONTACT/ADVISORY BODY RECOMMENDATION
N/A
ALTERNATIVE ACTION
If there are any additional questions, the council may postpone authorization; however, this will result in undue delay towards construction of Vanden Road – Segment 19.
COORDINATED WITH
Finance Department
STAFF CONTACT
Alvin Lei, Senior Civil Engineer
(707) 428-7476
[email protected]
ATTACHMENTS
Attachment 2: Proposed Resolution
Attachment 3: Proposed Agreement
CITY OF FAIRFIELD
RESOLUTION NO. 2025-185
AUTHORIZING THE CITY MANAGER TO EXECUTE A PROFESSIONAL SERVICES AGREEMENT WITH LSA ASSOCIATES INC., TO PROVIDE ENVIRONMENTAL SERVICES TO SUPPORT NATIONAL ENVIRONMENTAL POLICY ACT REVALIDATION FOR THE JEPSON PARKWAY PHASE 2B-2C
WHEREAS, the City intends to use grant funding administered by the Federal Highway Administration to construct Vanden Road – Segment 19 (Jepson Parkway Phase 2C); and
WHEREAS, the Federal Highway Administration requires the City to revalidate Vanden Road’s Environmental Impact Statement per the National Environmental Policy Act in order to utilize the grant funding; and
WHEREAS, the City requires technical services of an environmental consultation firm to conduct studies and prepare required documents necessary to complete the revalidation; and
WHEREAS, LSA Associates, Inc. is an environmental consultation firm that completed the environmental impact assessment for Vanden Road and surrounding developments and has the necessary subject matter expertise necessary to complete the revalidation and has been selected to provide professional environmental services for the revalidation .
NOW, THEREFORE, THE COUNCIL OF THE CITY OF FAIRFIELD HEREBY RESOLVES:
Section 1. The city manager is hereby authorized and directed to execute on behalf of the City of Fairfield that certain agreement with LSA Associates for an amount not-to-exceed $300,000 to provide professional environmental services to revalidate Jepson Parkway Phase 2B-2C’s National Environmental Policy Act requirements.
Section 2. The city manager is hereby authorized to do all things necessary to implement the above-mentioned agreement.
RES. NO. 2025-185
PASSED AND ADOPTED this 16th day of September 2025, by the following vote:
AYES: MEMBERS: MOY/BERTANI/CARR/PANDURO/SANDHU/TONNESEN/WILLIAMS NOES: MEMBERS: _________________________________________________ ABSENT: MEMBERS: _________________________________________________ ABSTAIN: MEMBERS: _________________________________________________
_________________________________________________
MAYOR
ATTEST:
___________________________
CITY CLERK
1 Revised 1/26/2024
PROFESSIONAL SERVICES AGREEMENT
THIS AGREEMENT is made at Fairfield, California, as of ________________, 2025, by and between the City of Fairfield, a municipal corporation (the “CITY") and LSA Associates, Inc ("CONSULTANT"), who agree as follows:
1)SERVICES. Subject to the terms and conditions set forth in this Agreement, CONSULTANT shall provide to the CITY the services described in Exhibit “A,” which consists of the proposal and delivery schedule submitted by CONSULTANT. CONSULTANT shall provide said services at the time, place, and in the manner specified in Exhibit “A.”
2)PAYMENT. CITY shall pay CONSULTANT for services rendered pursuant to this Agreement at the times and in the manner set forth in Exhibit “B.” The payments specified in Exhibit “B” shall be the only payments to be made to CONSULTANT for services rendered pursuant to this Agreement.
CONSULTANT shall submit all billings for said services to the CITY in the manner specified in Exhibit “B.” 3)FACILITIES AND EQUIPMENT. CONSULTANT shall, at its sole cost and expense, furnish all facilities and equipment which may be required for furnishing services pursuant to this Agreement. 4)GENERAL PROVISIONS. The general provisions set forth in Exhibit “C” are part of this Agreement. In the event of any inconsistency between said general provisions and any other terms or conditions of this Agreement, the provisions set forth in Exhibit “C” shall control. 5)INSURANCE REQUIREMENTS. The insurance requirements set forth in Exhibit “D” are part of this Agreement. In the event of any inconsistency between said general provisions and any other terms or conditions of this Agreement, the requirements set forth in Exhibit “D” shall control. 6)BUSINESS LICENSE. The CONSULTANT shall obtain and keep current a business license for work within the City of Fairfield pursuant to Chapter 10B of the Fairfield City Code, with respect to the gross receipts received pursuant to this Agreement. No payments shall be made to any SERVICE PROVIDER until such business license has been obtained, and all fees paid therefore, by the CONSULTANT. Business license applications and information may be obtained from the Community Development Department, Fairfield City Hall, 1000 Webster Street, Fairfield, CA 94533-4883, (707-428- 7509) and online at www.fairfield.ca.gov/biz .
7)EXHIBITS. All exhibits referred to herein are attached hereto and are by this reference incorporated herein.
8)TERM. This agreement shall be in effect through December 31 ,2026. 9) GOVERNING LAW AND VENUE. Should either Party to this Agreement bring legal action against the other, the validity, interpretation, and performance of this Contract shall be controlled by and construed under the laws of California, excluding California’s choice of law rules. Venue for any such action relating to this Agreement shall be in the Solano County Superior Court. 10)Where applicable, vehicles with a GVWR greater than 8,500 lbs. and light-duty package delivery vehicles operated in California may be subject to the California Air Resources Board Advanced Clean Fleets regulations. Such vehicles may therefore be subject to requirements to reduce emissions of
Revised 1/26/2024
air pollutants. For more information, please visit the CARB Advanced Clean Fleets webpage at https://ww2.arb.ca.gov/our-work/programs/advanced-clean-fleets 11)ENTIRE AGREEMENT. This Agreement, including any other documents incorporated herein by specific reference, represents the entire and integrated agreement between CITY and CONSULTANT.
This Agreement supersedes all prior oral or written negotiations, representations or agreements. This Agreement may not be modified or amended, nor any provision or breach waived, except in a writing signed by both parties which expressly refers to this Agreement. 12)COUNTERPARTS. This Agreement may be executed in counterpart originals, duplicate originals, or both, each of which is deemed to be an original for all purposes. 13)NOTICES. This Agreement is managed and administered on the CITY’s behalf by the individual named below. All invoices must be submitted and approved by this individual and all notices shall be given to the CITY using the following contact information:
CITY Contact: Alvin Lei
E-mail: [email protected]
Invoices:[email protected]
Address:1000 Webster Street, Fairfield, CA 94533
Telephone:(707)428-7476
Notices must be given to CONSULTANT at the following:
CONSULTANT Contact: Edward Heming
E-mail: [email protected]
Address: 3210 El Camino Real, Ste 100, Irvine, CA 92602 Telephone: (916)844-2847
EXECUTED as of the day first above stated-.
City of Fairfield, a municipal corporation
By:__________________________________
David Gassaway, City manager
CONSULTANT, LSA Associates, Inc.
By:___________________________________
Anthony Petros, CEO
2
3 Revised 1/26/2024
EXHIBIT “A”
SCOPE OF SERVICE
SCOPE OF WORK
This scope of work has been prepared based on information provided by the City, Caltrans, and the One Lake (Phase 2B) project proponent. The updated technical studies are needed due to design modifications and the length of time since the original studies were prepared. This scope of work is valid for a period of six months beginning June 2025. Our scope is based on a 12-month schedule. Re-scoping and/or a budget adjustment may be required after that period has lapsed, or if that overall schedule is exceeded.
Task 1. Project Initiation
Task 1.1 Initial Assessment
Following authorization to proceed, LSA will conduct an in depth assessment of project changes and potential impacts comparing current design plans to the original EIS. LSA will make a preliminary determination of what additional documentation may be required and then coordinate with the City and Caltrans regarding these findings. It is expected that Caltrans will confirm the technical studies described in this scope of work will remain sufficient.
This task assumes two joint meetings with City and Caltrans staff to confirm the scope/approach for the NEPA revalidation.
Task 1.2 Project Description
LSA will work closely with the project design team to prepare a Draft Project Description that supports subsequent technical studies. The Project Description will provide the level of detail necessary for the technical studies and revalidation to support a thorough environmental impact analysis. For example, the Project Description will include details pertaining to the existing environmental setting, a description of the proposed project components, construction access and staging, and other essential project and construction details. A location map and graphics illustrating the project will be prepared based on materials provided by the project design team.
LSA will provide the Draft Project Description the project design team for review, and a revised version will be prepared in response to comments. The Draft Project Description would then be submitted to the City and Caltrans staff for review. Preparation of the technical studies will commence after the Project Description is reviewed and approved by the City and Caltrans. LSA will address one consolidated set of comments on the Draft Project Description.
LSA will support any necessary updates to the TIP. This will include a review of the current TIP listing and preparing a revised TIP listing (if required). It is assumed that the City will coordinate directly with the Solano County Council of Governments using this revised listing.
4 Revised 1/26/2024
Deliverable: Draft and Final Project Description
Task 2. Technical Studies
The technical studies outlined in this section will support the NEPA revalidation. The studies will be based on a project description and design provided by the project design team and cover a single build alternative. Draft and final versions of each study will be provided to the City and Caltrans in electronic format for concurrent review. No printed copies will be provided. It is anticipated that all previously completed technical studies and their supporting analysis will be made available to LSA. LSA will begin this task following receipt of these project materials, approval of the project description, and confirmation that project design will change substantially enough to require revisions to the technical reports.
LSA has scoped its level of effort for mapping/analysis on receipt of the project design in AutoCAD (i.e., .dwg) format and projected into a real-world coordinate system (e.g., State Plane) for efficient integration into GIS software. If revisions to the technical reports are required based on changes to the project description or design, or if LSA needs to manipulate the design files in order to integrate them into a GIS, additional budget may be required.
Task 2.1 Air Quality Studies
LSA will prepare an Air Quality Report (AQR) that documents the study results consistent with Caltrans Standard Environmental Reference (SER) AQR Annotated Outline (June 10, 2024, or newer). Construction related air pollutant emissions will be quantified using California Emission Estimator Model (CalEEMod) or another appropriate model as directed by Caltrans commensurate with available Project specific information. Caltrans Standard Specifications for Construction, as well as mitigation measures, if necessary, will be recommended to reduce short-term, construction-related impacts. Operational air pollutant emissions will also be quantified using CalEEMod or another appropriate model as directed by Caltrans. The greenhouse gas (GHG) analysis would be based on the SER Climate Change Annotated Outline for a capacity increasing project (June 17, 2024, or newer). This task will start after preparation of the traffic memorandum prepared by Fehr and Peers.
LSA will prepare an Air Quality Conformity Analysis (AQCA) consistent with the SER AQCA Annotated Outline (June 24, 2024 or newer). LSA will prepare the associated AQCA Cover Letter and Air Quality Conformity Findings Checklist. LSA will prepare the PM Conformity Hot Spot Analysis Project Summary Form for Interagency Consultation to allow the Southern California Association of Governments (SCAG) Transportation Conformity Working Group (TCWG) to determine whether a project requires a project- level PM hot-spot analysis pursuant to Federal Conformity Regulations. This scope assumes the preparation of a quantitative PM10 and PM2.5 Hot-Spot assessment would not be required. A qualitative Mobile Source Air Toxic (MSAT) analysis will be prepared according to FHWA Updated Interim Guidance on Mobile Source Air Toxic Analysis in NEPA Documents.
LSA will schedule a meeting with the Interagency Task Force and assist in the preparation of meeting materials. It is assumed that Fehr and Peers staff will be at the presentation to assist with any traffic- related questions. To support the required 30-day public review period, LSA will prepare a draft public notice. Fees for the public notice will be the responsibility of the City. LSA has budgeted up to 12 hours for responding to one consolidated set of comments on the AQR and AQCA.
5 Revised 1/26/2024
Deliverables: AQR (Draft and Final)
AQCA (Draft and Final)
Air Quality Conformity Cover Letter (Draft and Final)
Air Quality Conformity Findings Checklist (Draft and Final) Air Quality Conformity Public Notice (Draft and Final)
Task 2.2 Noise Studies
LSA will prepare a Noise Study Report (NSR) consistent with the April 2020 Caltrans Traffic Noise Analysis Protocol, September 2013 Technical Noise Supplement (TeNS), and the annotated outline provided by the Caltrans SER. Short-term (20 to 30-minute) noise level measurements will be conducted at up to three locations with concurrent traffic counts to document the existing noise environment and to calibrate the traffic noise model. Long-term 24-hour noise level measurements will be conducted at up to two locations to identify the peak traffic noise hour. FHWA Traffic Noise Model (TNM) version 2.5 will be used to evaluate the traffic noise levels associated with the Existing, Future No Build, and a future Build Alternative. Traffic noise impacts will be determined based on the design-year with project traffic noise levels and the corresponding noise abatement criteria (NAC) for each land use. Noise abatement measures (noise barriers) designed to reduce long-term traffic noise impacts by 5 dBA or more, as required to be feasible, will be evaluated. A reasonable allowance per receptor and total reasonable allowance will be calculated for each feasible nose barrier height. In addition, construction noise impacts will be evaluated in terms of the maximum instantaneous noise levels (Lmax), hourly equivalent continuous sound levels (Leq), and frequency of occurrence at adjacent sensitive locations. Analysis requirements will be based on the sensitivity of the area and Caltrans standard specifications in Section 14-8.02.
Optional Task: If feasible noise barriers are identified in the NSR, LSA will prepare a Noise Abatement Decision Report (NADR) consistent with the April 2020 Caltrans Traffic Noise Analysis Protocol, and the annotated outline provided by the Caltrans SER. The report will summarize key information presented in the NSR, which would include acoustical feasibility, number of benefited residences, and the total reasonable allowance. Also, the report will be approved and signed by the project engineer. In addition, the preliminary noise abatement decision, and secondary effects of abatement (impacts on cultural resources, scenic views, hazardous materials, and biology) will be provided. The engineer’s cost estimate to construct noise barriers and non-acoustical factors related to feasibility will be provided to LSA for the completion of the NADR. The noise barrier construction cost estimate will be compared to the total reasonable allowance to determine the reasonableness of the noise abatement measure. Non-acoustical factors related to feasibility for the reasonable noise abatement measure will include but not limit to line- of-sight, safety, maintenance, security, geotechnical considerations, and utility relocations. In addition, secondary effects of abatement on cultural resources, scenic views, hazardous materials, biology, and any other applicable resources will be addressed.
The optional task will be engaged if needed. LSA has budgeted 6 hours for responding to one consolidated set of comments on the NSR and NADR.
Deliverables: NSR (Draft and Final)
NADR (OPTIONAL) (Draft and Final)
6 Revised 1/26/2024
Task 2.3 Biological Studies
LSA will conduct supplemental field surveys and review other relevant data from the One Lake project monitoring to update information regarding species subject to the Federal Endangered Species Act (FESA) in order to verify the applicability of Jepson Parkway Biological Opinion (BO) for Phases 2B and 2C. LSA will prepare a Biological Resources Technical Memorandum addressing updated information and address if new information would require any revisions to the findings and conditions in the BO. If revisions are required to the BO, an augment to this contract would be required.
Under a separate contract with One Lake, LSA will prepare and coordinate permit applications to the CDFW for an ITP for State listed species and a Lake and Streambed Alteration Agreement (if needed) and to the San Francisco Bay Regional Water Quality Control Board for WDR for a small, isolated wetland that will be affected by the project. LSA has budgeted 4 hours for responding to one consolidated set of comments on the Biological Resources Technical Memorandum.
Deliverables: Biological Resources Technical Memorandum (Draft and Final) Task 2.4 Aesthetics/Visual Studies
LSA through its subconsultant, Earthview Science, hereafter referred to as team, will complete a Questionnaire to Determine Visual Impact Assessment (VIA) Level to identify study needs to support the revalidation. Based on available information, the team anticipates that a VIA Memorandum will be prepared. This deliverable will assess the degree of impact on aesthetic resources. It would not include the analysis of specific viewpoints or visual simulations but would include character photos of the existing conditions to supplement the discussion on visual character and quality. If the level of VIA exceeds the scope of a technical memorandum, an augment to this scope will be required.
The team has budgeted 4 hours for responding to one consolidated set of comments on the Questionnaire and VIA Memorandum.
Deliverables: Questionnaire to Determine VIA Level
VIA Memorandum (Draft and Final)
Task 2.5 Hazardous Materials/Waste Coordination
LSA will prepare a Hazardous Waste Technical Memorandum comparing current Geotracker information to the data presented in the 2015 revalidation. It is assumed that no additional sites from the previous EIS will be identified, or that new sites will not have any potential conflicts with the project. The purpose of this memorandum is to document no substantial changes in the hazardous materials environmental setting have occurred since the original EIS. If new Geotracker sites are identified that may conflict with the Project, an augment to the scope and budget will be needed to support additional technical analysis and potentially an Initial Site Assessment (ISA). The team has budgeted 4 hours for responding to one consolidated set of comments on the Hazardous Waste Technical Memorandum.
Deliverables: Hazardous Waste Technical Memorandum (Draft and Final)
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Task 2.6 Farmland Impact Coordination
The project will require the conversion of active agricultural land to a non-agricultural use (specifically a transportation use). To support the NEPA revalidation, LSA will prepare a Form NRCSCPA- 106 (corridor- type projects) and if the points of the Total Site Assessment in Part VI equate to 60 points or greater, the Form NRCS-CPA-106 will be sent to the applicable Natural Resources Conservation Service (NRCS) field office. If the point total in Part VI is less than 60 points, then Form NRCS-CPA-106 does not need to be submitted to NRCS and instead LSA will retain the form as supporting documentation for NEPA revalidation. If NRCS coordination is required, LSA will prepare a farmland impact analysis and present mitigation measures (as applicable) in a Farmland Impact Assessment Memorandum. The results of Form NRCS-CPA-106 will be discussed in the memorandum and the signed Form will be included as an appendix.
LSA has budgeted 4 hours for responding to one consolidated set of comments on the NRCS form and Farmland Impact Assessment Memorandum.
Deliverables: NRCS AD 1006 Form (Draft and Final)
Farmland Impact Assessment Memorandum (OPTIONAL) (Draft and Final) Task 2.7 Hydraulic Studies
LSA through its subconsultant Avila and Associates Consulting Engineers Inc., hereafter referred to as team, will prepare the necessary hydraulic studies to support the NEPA revalidation. The team will review all available background information for the project including as-built plans of adjacent infrastructure and existing hydrology analyses of the watershed. To initiate this work, it is assumed the City will provide as- built plans for the existing infrastructure needed to support a HEC-RAS hydraulic model. The team will perform a field review of the project reach to support the hydraulic studies.
The team will coordinate with Solano County and obtain all readily available hydrology and hydraulic analyses of the project area. Hydrology and hydraulic analyses will be conducted by the team to determine the Overtopping Flood and Flood of Record at the bridge. If prior hydrology and hydraulic analyses are unavailable, the team will estimate the peak discharge and create hydrographs for the 100-year discharges using a HEC-RAS point precipitation model to determine the discharges in Union Creek.
Hydrology results will be provided in the Location Hydraulic Study (LHS). It is assumed that the hydrology analysis will only be conducted for the Union Creek watershed and does not include hydrology for local surface drainage facilities. It is further assumed that FEMA discharges will not be changed with the project.
The team will review the channel and structure information needed to model the existing bridge and channel. A 2D HEC-RAS model will be created using existing conditions based on existing topographic information (LiDAR), creek surveys, and detailed survey or as-built plans of the existing bridges along Union Creek in the vicinity of the project using HEC-RAS 6.5 (or newer). The team will update the existing conditions 2D model for the proposed project based on project plans and grading (if provided). Hydraulic results will be provided in the LHS.
To support this work, topographic information will be provided by the City and will include details of the creek bottom through the project reach. Finish grade surfaces of the roadway approaches for all alignments will be provided by the City in either .dwg or .xml file format. Centerline alignment and profile of proposed alternatives will be provided within .dwg format. Exhibits of the proposed bridge configuration options will be provided by the City including profiles, deck thickness, abutment locations,
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and pier types and locations. The hydraulic analysis will be for Union Creek only and does not include local surface drainage facilities. This scope does not include design and analysis of detention facilities (if necessary).
The team will complete an LHS complying with Caltrans local assistance forms ( https://dot.ca.gov/programs/local-assistance/environmental/local-environmental-issues) . This report will document the hydrology and hydraulic results for the existing condition and one proposed roadway/bridge alternative in accordance with 23 CFR 650.113. The team will complete Flood plain Encroachment Report forms in accordance with 23 CFR 650.113. Only the final proposed project alternative will be evaluated. No insurable structures will be adversely impacted by the proposed bridge and grading. The team will complete and sign the forms for Items 3, 4, 5, 7 and 9 of the LHS Form.
It is assumed that the proposed project will not cause a significant encroachment into the floodplain or a change in the water surface elevation. Survey information for adjacent buildings will be provided by the City to determine the potential impact of the proposed bridge on the adjacent insurable structures, if applicable. No Conditional Letter of Map Revision (CLOMR) or Letter of Map Revision (LOMR) or formal No-Rise certification is included in this scope of work. Floodplain Encroachment forms will be provided as an appendix in the Final Location Hydraulic Study Report.
The team has budgeted 6 hours for responding to one consolidated set of comments on the LHS.
Deliverables: LHS (Draft and Final)
Task 3. NEPA Revalidation
LSA will prepare a NEPA revalidation form using the template on the Caltrans SER (September 2024). This will include a discussion on changes in project design, changes in the environmental setting, changes in the environmental circumstances, changes in environmental impacts, and/or changes in avoidance/minimization/mitigation measures. As part of the revalidation, a revised Environmental Commitments Record (ECR) will be completed (if needed). Continuation sheets will be added if necessary to complete the form.
LSA assumes that the revalidation will not require additional public review and that a new environmental document will not be required. LSA will provide electronic copies (word and pdf) of the completed NEPA revalidation form to the City and Caltrans. No printed versions will be distributed.
This work assumes the final NEPA revalidation form will not need to be 508 compliant.
LSA has budgeted 8 hours to respond to one consolidated set of comments that the City and Caltrans may have on the NEPA Revalidation Form.
Deliverables: NEPA Revalidation Form (Draft and Final)
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Task 4. Project Management/Meetings
LSA’s Project Manager will undertake a variety of general project management tasks throughout the contract managing the deliverables outlined in the scope of work. This includes coordination of the day- to-day activities associated with the project and monitoring its scope, budget, and schedule. Other project management tasks include regular client contact, subcontractor management, and assistance to team members. LSA will provide written documentation of all substantive project developments in the form of client emails and/or phone conversation records and will follow up our submittals to outside parties and conduct coordination as necessary to ensure efficient and timely review.
LSA’s Principals will ultimately be responsible for quality assurance for all work undertaken and will review all text, tables, and graphics before these materials are presented as administrative review documents.
The Principal-in-Charge will also be available for consultation on environmental review procedural matters, and strategy.
LSA will attend 12 Project Development Team (PDT) meetings via conference call.
We look forward to supporting this project. Please contact us with any questions or comments on this proposal ([email protected] or [email protected]).
Sincerely,
LSA Associates, Inc.
Edward Heming Thomas J. Warner
Principal Associate
Attachments: Detailed Budget Spreadsheet with Optional Tasks Detailed Schedule