Point_Adams_Electrical_Specifications__-_28_Jul_26.pdf

NWFSC ELECTRICAL, PV, and BATTERY ENERGY STORAGE SYSTEM Point Adams, OR 07/28/2026

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SECTION 26 31 00 – ELECTRICAL, PV, and BATTERY ENERGY STORAGE SYSTEM

Project: NOAA NWFSC Point Adams Electrical Backup Power System

Location: 520 Heceta Place, Hammond, OR 97121

Utility Jurisdiction: Pacific Power (PacifiCorp)

Order of Precedence: These technical specifications are fully complementary to the Point Adams Backup Power System Statement of Work (SOW). In the event of any conflict, discrepancy, or ambiguity between this specification and the SOW, the requirements of the SOW shall govern.

PART I - GENERAL

1.01 SUMMARY. This specification defines the technical, product, and execution requirements for the engineering, procurement, installation, testing, and commissioning of the Point Adams central electrical backup system. The complete scope encompasses three core areas:

A. Task 1 – Service Consolidation: Combining two existing 200A services into a single 400A, 120/240V, single-phase (1-phase, 3-wire) meter/main distribution system.

B. Task 2 – Microgrid & BESS: A design-build battery energy storage system (BESS), hybrid inverters, Microgrid Interconnection Device (MID), and automated remote load-shedding control providing 72 hours of autonomy for critical loads.

C. Optional Task 3 – Solar PV Integration: A 20 kWdc ground-mounted PV array connected via a DC-coupled topology directly to the battery bus.

1.02 APPLICABLE CODES & GOVERNING STANDARDS. All equipment design, manufacturing, installation, and testing shall strictly conform to the latest published editions of the following codes and standards:

A. Federal & State Building Codes: Oregon Electrical Specialty Code (OESC), Oregon Structural Option Code, and local AHJ regulations.

B. National Electrical & Safety Codes: NFPA 70 (National Electrical Code - NEC, including Articles 250, 690, 705, and 706), NFPA 855 (Stationary Energy Storage Systems), and OSHA 1926/1910.

C. Product Safety & Interconnection Standards:

1. UL 1741 (SA/SB): Inverters, Converters, Controllers, and Interconnection System

Equipment for Distributed Energy Resources.

2. UL 9540 & UL 9540A: Standard for Safety of Energy Storage Systems and Thermal

Runaway Fire Propagation.

3. IEEE 1547 & IEEE 929: Standard for Interconnection and Interoperability of

Distributed Energy Resources.

D. Utility Standards: Interconnection rules, metering standards, and grid isolation protocols established by Pacific Power (PacifiCorp).

1.03 SITE & ENVIRONMENTAL CONDITIONS

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A. Marine Coastal Environment: The project is located at the mouth of the Columbia River. All exterior enclosures, hardware, racking, conduits, and fittings shall be explicitly rated for marine coastal environments (corrosion resistance, UV resistance, stainless steel hardware/fasteners, and outdoor NEMA 3R/4X ratings).

B. Trade Constraints: All components shall be Buy American Act compliant. Made-in- China products or components will strictly not be accepted.

PART 2 – PRODUCTS

2.01 ELECTRICAL UTILITY SERVICES CONSOLIDATION GEAR (TASK 1)

A. System Rating: 400-amp, 120/240-volt, single-phase (1Ø, 3-wire) main service entry.\ B. Distribution Hierarchy: Equipment configuration must match Figures 8.1 and 8.2 of

Exhibit A:

1. Main Distribution: 400A central service entry panel feeding two 200A distribution panels.

2. Feeders:

a. One 60A feeder supplying the 2-Bay Building Panel.

b. One 200A feeder supplying the Main Building Panel.

c. One 200A feeder supplying the 4-Bay Building Panel.

3. Sub-feed: One 150A downstream sub-feed circuit from the 4-Bay Building Panel supplying the 1-Bay Building Panel.

C. Conduit Connections: Sized to connect to existing 4-inch Schedule 40 underground feeder conduits as mapped in Exhibit A (Figure 1).

D. Protection Ratings: All circuit breakers shall be fully rated with Ampere Interrupting Capacity (AIC) sized in accordance with contractor short-circuit calculations submitted during design review.

2.02 HYBRID INVERTERS & BATTERY ENERGY STORAGE SYSTEM (TASK 2)

A. Design-Build Microgrid System: The contractor shall engineer a turn-key BESS providing a continuous 72-hour runtime during utility outages for designated Critical Loads.

B. Microgrid Interconnection Device (MID):

1. Service-rated, UL 1741 / UL 9540 listed bidirectional isolation device.

2. Shall automatically disconnect the campus from Pacific Power's utility grid upon power loss and safely form an islanded microgrid.

C. Hybrid Inverter / Chargers:

1. Split-phase hybrid inverter system supplying continuous power to the Main Building and 4-Bay Building panels.

2. Sized with continuous islanded capacity and surge headroom to start motor loads (e.g., pumps, freezers).

3. Automated Neutral-to-Ground bonding management: Bond shall reside at the main utility service under normal grid conditions and automatically transfer to the inverter system during islanded operations.

D. Battery Energy Storage System (BESS):

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1. Battery chemistry certified under UL 9540 and UL 9540A.

2. Includes integrated Battery Management System (BMS), thermal monitoring, and code-compliant fire suppression.

E. Automated Load-Management Equipment:

1. Smart load-shedding control panels (e.g., Powerlink Panel Boards or controllable breakers/relays).

2. Operates on controller signal during islanding to automatically isolate Non- Critical Loads while maintaining continuous power to Critical Loads (freezers, IT/computer network, and emergency lighting).

2.03 GROUND-MOUNTED SOLAR PHOTOVOLTAIC EQUIPMENT (optional TASK 3) A. Array Capacity: Total system capacity of 20 kWdc.

B. System Architecture: DC-Coupled Topology. Solar array strings (600 Vdc-class) shall route to Maximum Power Point Tracking (MPPT) charge controllers that feed the common 48V battery bus directly. AC-coupled configurations are not permitted for

TASK 3.

C. PV Modules & Rapid Shutdown: High-efficiency, tier-1 PV modules with UL 1703 certification. Array must include module-level rapid shutdown devices (RSD) compliant with NEC 690.12.

D. Racking & Framing: Marine-grade aluminum or hot-dipped galvanized steel framing certified to UL 2703. Designed to withstand local wind velocity pressures per

ASCE 7.

E. Civil Foundations: 16-inch diameter poured concrete pier foundations installed below the local Oregon frost line.

F. Site Perimeter Enclosure: Perimeter fence (4-foot chain link) providing a minimum 5-foot clearance around the PV array footprint (approx. 25 ft. × 60 ft.).

2.04 EQUIPMENT IDENTIFICATION & NAMEPLATES

A. Plastic Nameplates: Laminated plastic nameplates inscribed with contrasting lettering shall be provided for panelboards, safety switches, equipment cabinets, transfer switches, and major electrical enclosures to identify the equipment designation and system function.

B. Panelboard Directories: Typewritten directories indicating the exact equipment served and location using final room/building numbers shall be provided inside all panelboard covers.

PART 3 – EXECUTION

3.01 COORDINATION & UTILITY APPROVAL

A. Utility Interconnection: The contractor shall act as the primary technical interface for interconnection applications and approvals with Pacific Power (PacifiCorp). Physical work shall not start until utility interconnection design approval is granted.

B. Downtime Minimization: Outages must be requested in writing at least 21 days in advance. Temporary rental generation must be provided by the contractor if necessary to ensure zero loss of critical research freezer loads during construction.

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3.02 SEQUENCE OF OPERATIONS

A. The installed system must automatically execute the following sequence:

1. Utility Failure: Pacific Power grid supply drops out.

2. Islanding: Microgrid Interconnection Device (MID) opens to isolate the campus from the utility grid.

3. Grid Formation: Hybrid inverters form the backup AC bus.

4. Load Shedding: Smart load controllers send signals to open non-critical branch breakers (HVAC, standard outlets, water heaters).

5. Critical Load Support: Freezers, IT systems, and emergency lighting remain continuously energized from the BESS.

6. Solar PV Integration: The DC-coupled solar PV system feeds MPPT controllers to supply site loads and recharge the battery bank during daylight hours while islanded.

3.03 EQUIPMENT PAD FOUNDATION & PHYSICAL MOUNTING

A. Concrete Slabs: Ground- or slab-mounted electrical equipment, including exterior BESS units and transformers, shall be mounted on a separate 4-inch-high concrete slab extending a minimum of 6 inches beyond the equipment footprint on all sides.

B. Structural Attachment: All electrical equipment, conduits, and enclosures shall be supported directly from building structural members or concrete pads independent of ceiling grids or non-structural walls.

3.04 CUTTING, PATCHING, AND SURFACE REPAIR

A. Execution Quality: Cutting, fitting, repairing, and patching required for electrical installations shall be performed by craftsmen skilled in their respective trades without weakening structural members or breaking finishes.

B. Roadways & Walkways: Where the contractor cuts or breaks asphalt/concrete roadways, walkways, or site paving, surfaces shall be repaired and restored to match existing conditions.

3.05 SURFACE PAINTING & PROTECTIVE FINISHES

A. Surface Preparation & Priming: All exposed conduit, pull boxes, junction boxes, hangers, anchors, and galvanized materials shall be properly treated, primed, and painted to match adjacent wall or building surfaces.

B. Exterior Gear Finishing: Exterior electrical panels, disconnect switches, meter enclosures, and exposed equipment covers shall be painted to match adjacent wall finishes.

3.06 POWER QUALITY & HARMONIC DISTORTION CONTROL

A. Harmonic Limits: System equipment shall comply with IEEE 519-1992 requirements to maintain total harmonic distortion (THD) within allowable limits (maximum 5% voltage THD and maximum 8% current THD) at equipment terminals.

B. Testing Documentation: Actual job site harmonic measurement testing shall be documented in the Operation and Maintenance manuals, with final compliance reports stamped by a registered Professional Engineer (PE).

3.07 QUALITY CONTROL, COMMISSIONING & DELIVERABLES

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C. Commissioning: Acceptance testing shall be performed by a manufacturer-certified technician. Testing shall verify microgrid isolation, automatic load-shedding response, inverter transfer times, battery runtimes, and DC-coupled solar charging.

D. Deliverable Timelines (Post-Commissioning):

1. Testing & Commissioning Report: Due within 7 calendar days.

2. Personnel Training: Operational training conducted within 5 working days; training logs submitted within 7 calendar days.

3. As-Built Drawings: PDF and AutoCAD (.dwg) files submitted within 7 calendar days after hard-copy approval.

4. O&M Manuals: Submitted within 7 calendar days.

5. Warranties: Completed warranty registrations (1-year labor/craftsmanship; 5-year

BESS/inverter; standard manufacturer warranties) submitted within 7 calendar days.

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