Attach 1 - Product Description Substation Final 25 Sept 25.pdf

Cole River Substation Product Description

PART 1 GENERAL

1.1 SUMMARY

The Cole Rivers Hatchery electrical substation is in need of replacement.

The Substation Manufacturer is to use the Contract Drawings and Contract Specifications as a guideline for layout, fabrication, assembly, wiring and factory testing of the Cole Rivers service substation. The final layout, mechanical and electrical drawings of all the components are to be reviewed by the Government before manufacturing begins. The substation is to be completely assembled and tested at the Substation Manufacturer's factory and is to be shipped to the Cole Rivers Hatchery site by the Substation Manufacturer. The Government realizes the size of the equipment and realizes that it may have to be shipped in sections rather than as a complete unit due to shipping restrictions on the Oregon highway systems using standard trucking and the weight of each section: the medium voltage section, low voltage section and the transformer section. The manufacturer will be responsible to deliver, unload the substation and reassemble the substation once on site. The substation is to be delivered to the Lost Creek Boneyard Storage Building located at the end of Cole M Rivers Drive, Trail, Oregon (GPS Coordinates 42º40’05”N 122º40’47”W), see Attachment 2 for map and Attachment 4 for photos of delivery area.

Any engineering services required under this contract shall be limited to those customarily provided by the original equipment manufacturer (OEM) for integration and functional deployment of the completed substation.

The substation key components are:

a. Dry-type service transformer,

b. 15kV medium voltage switchgear and circuit breaker,

c. 480V low voltage switchgear and circuit breakers,

d. Automatic transfer switch and controller.

1.2 REFERENCES

The publications listed below form a part of this specification to the extent referenced. The publications are referred to within the text by the basic designation only.

AMERICAN NATIONAL STANDARDS INSTITUTE (ANSI)

ANSI C12.1 (2014) Code for Electricity Metering

ANSI C39.1 (1981; R 1992) Requirements for Electrical

Analog Indicating Instruments

ASME INTERNATIONAL (ASME)

ASME B1.1 (2003; R 2008) Unified Inch Screw Threads

(UN and UNR Thread Form)

ASME B1.20.1 (2013) Pipe Threads, General Purpose (Inch)

ASTM INTERNATIONAL (ASTM)

ASTM A123/A123M (2015) Standard Specification for Zinc (Hot-Dip Galvanized) Coatings on Iron and Steel Products

ASTM A153/A153M (2016) Standard Specification for Zinc

Coating (Hot-Dip) on Iron and Steel Hardware

ASTM B187/B187M (2016) Standard Specification for Copper, Bus Bar, Rod and Shapes and General Purpose Rod, Bar and Shapes

INSTITUTE OF ELECTRICAL AND ELECTRONICS ENGINEERS (IEEE)

IEEE 1248 (1998; R 2007) Guide for the Commissioning of Electrical Systems in Hydroelectric Power Plants

IEEE C2 (2023) National Electrical Safety Code

IEEE C37.09 (1999; AMD 1 2005; Corr 1 2007; R 2007;

Errata 2007; Amendment B 2011) Standard Test Procedure for AC High-Voltage Circuit Breakers Rated on a Symmetrical Current Basis

IEEE C37.13 (2015) Standard for Low-Voltage AC Power

Circuit Breakers Used in Enclosures

IEEE C37.16 (2009) Standard for Preferred Ratings, Related Requirements, and Application Recommendations for Low-Voltage AC (635 V and below) and DC (3200 V and below) Power Circuit Breakers

IEEE C37.17 Standard for Trip Systems for Low -

Voltage (1000 V and below) AC and General Purpose (1500 V and below) DC Power Circuit Breakers

IEEE C37.20.1 (2015) Standard for Metal-Enclosed

Low-Voltage (1000 Volts and Below, 3200 Vdc and Below) Power Circuit Breaker Switchgear

IEEE C37.90.1 (2012) Standard for Surge Withstand

Capability (SWC) Tests for Relays and Relay Systems Associated with Electric Power Apparatus

IEEE C57.13 (2016) Standard Requirements for

Instrument Transformers

IEEE C57.13.3 (2014) Guide for Grounding of Instrument

Transformer Secondary Circuits and Cases

INTERNATIONAL ELECTRICAL TESTING ASSOCIATION (NETA)

NETA ATS (2025) Standard for Acceptance Testing Specifications for Electrical Power Equipment and Systems

NATIONAL ELECTRICAL MANUFACTURERS ASSOCIATION (NEMA)

NEMA C37.50 (2012) American National Standard for

Switchgear--Low-Voltage AC Power Circuit Breakers Used in Enclosures - Test Procedures

NEMA SG 4 (2009; R 2013) Alternating-Current

High-Voltage Circuit Breakers

NATIONAL FIRE PROTECTION ASSOCIATION (NFPA)

NFPA 70 (2023) National Electrical Code

UNDERWRITERS LABORATORIES (UL)

UL 44 (2014; Reprint Feb 2015) Thermoset-Insulated Wires and Cables

UL 1581 (2001; Reprint Jun 2017) Electrical Wires, Cables, and Flexible Cords

U.S. ARMY CORPS OF ENGINEERS (USACE)

EM 385-1-1 (2024) Safety and Health Requirements

Manual

MEDIUM-VOLTAGE SUBSTATION COMPARTMENT

ASCE 7-10 (2010; Errata 2011; Supp 1 2013) Minimum

Design Loads for Buildings and Other Structures

ASTM INTERNATIONAL (ASTM)

ASTM A780/A780M (2020) Standard Practice for Repair of

Damaged and Uncoated Areas of Hot-Dip Galvanized Coatings

ASTM D1535 (2014; R 2018) Standard Practice for

Specifying Color by the Munsell System

ASTM D709 (2017) Standard Specification for

Laminated Thermosetting Materials

IEEE 100 (2000; Archived) The Authoritative

Dictionary of IEEE Standards Terms

IEEE C2 (2023) National Electrical Safety Code

IEEE C37.20.3 (2013) Standard for Metal-Enclosed

Interrupter Switchgear

IEEE C37.90 (2005; R 2011) Standard for Relays and

Relay Systems Associated With Electric Power Apparatus

IEEE C57.13 (2016) Standard Requirements for Instrument Transformers

IEEE C57.13.1 (2006; R 2012) Guide for Field Testing of Relaying Current Transformers

IEEE C57.13.3 (2014) IEEE Guide for Grounding of

Instrument Transformer Secondary Circuits and Cases

IEEE C57.98 (2011) Guide for Transformer Impulse Tests

INTERNATIONAL CODE COUNCIL (ICC)

ICC IBC (2021) International Building Code

INTERNATIONAL ELECTRICAL TESTING ASSOCIATION (NETA)

NETA ATS (2025) Standard for Acceptance Testing Specifications for Electrical Power Equipment and Systems

NATIONAL FIRE PROTECTION ASSOCIATION (NFPA)

NFPA 70 (2023) National Electrical Code

NFPA 70E (2024) Standard for Electrical Safety in the Workplace

DRY-TYPE SUBSTATION SERVICE TRANSFORMER

AMERICAN SOCIETY OF CIVIL ENGINEERS (ASCE)

ASCE 7-10 (2010; Errata 2011; Supp 1 2013) Minimum

Design Loads for Buildings and Other Structures

AMERICAN SOCIETY OF MECHANICAL ENGINEERS (ASME)

ASME B1.1 (2003; R 2018) Unified Inch Screw Threads

(UN and UNR Thread Form)

IEEE 693 (2018) IEEE Recommended Practice for

Seismic Design of Substations

IEEE C37.20.1A (2020) Metal-Enclosed Low-Voltage (1000

Vac and below, 3200 Vdc and below) Power Circuit-Breaker Switchgear Amendment 1:

Control and Secondary Circuits and Devices, and All Wiring

IEEE C57.12.01 (2020) General Requirements for Dry-Type

Distribution and Power Transformers Including Those with Solid-Cast and/or Resin-Encapsulated Windings

IEEE C57.12.51 (2019) IEEE Guide for Mechanical

Interchangeability of Ventilated Dry-Type

Transformers

IEEE C57.12.91 (2011) Standard Test Code for Dry-Type

Distribution and Power Transformers

IEEE C57.13 (2016) Standard Requirements for

Instrument Transformers

IEEE C57.13.3 (2014) IEEE Guide for Grounding of

Instrument Transformer Secondary Circuits and Cases

IEEE C57.32 (2015) IEEE Standard for Requirements, Terminology, and Test Procedures for Neutral Grounding Devices

IEEE C62.11 (2020) Standard for Metal-Oxide Surge

Arresters for Alternating Current Power Circuits (>1kV)

NATIONAL ELECTRICAL MANUFACTURERS ASSOCIATION (NEMA)

NEMA 250 (2020) Enclosures for Electrical Equipment

(1000 Volts Maximum)

NEMA TR 1 (2013) Transformers, Regulators, and

Reactors

1.3 DELIVERABLES

Government review is required for the below listed Deliverables

1.3.1 Substation Manufacturer is to submit within 90 days after award:

a. Draft substation layout,

b. Mechanical and electrical schematic/one-line drawing

1.3.2 Substation Manufacturer is to submit the following at the specified intervals:

a. Factory test procedure, test results, calibrations, and set points

14 days prior to factory testing starting,

b. Field test procedure at least 30 days prior to field testing starting,

c. Long term storage recommendation at least 30 days prior to field testing,

d. Offloading plan at least 14 days prior to delivery.

e. Detailed assembly drawings with delivery,

f. Outline drawings of substation component layout with delivery,

g. Schematic diagrams/wire connection diagrams with delivery,

h. Mechanical/electrical schematic/one-line drawings finals with delivery,

i. Manufacture cut sheets for all components used within the substation, marking out all non-applicable data with delivery,

j. Operations and maintenance (O&M) manuals for each component that requires routine maintenance or troubleshooting, including but not limited to protective relays, medium voltage breaker, low voltage breakers, high resistance ground (HRG), automatic transfer switch

(ATS), infrared (IR) windows, remote racking device, medium and low voltage switchgear with delivery,

k. Startup procedure for the assembled substation with delivery.

1.3.3 Quality Assurance

The Substation Manufacturer is to complete all required industry standard quality assurance and testing at their facilities to show the completed substation with all its components are fully functional prior shipping. All factory testing procedures, reports and test results are to be provided to the government prior to shipping the substation.

1.3.4 Assembly, Detail Drawings and Data

Prepare and submit assembly, detail drawings, and data to demonstrate that all parts of the equipment conform to the requirements and intent of the specifications. The drawings are to include, but not limited to, sectional views of switchgear units including bus and bracing, description of removable elements, circuit breakers and electronic trip units, equipment lists, high resistance ground equipment, ATS controller, and nameplate schedules. Drawings to show all coordination with other connected equipment including the transformer and metal enclosed bus indicating full electrical details of the connection.

1.3.5 Outline Drawings

Prepare and submit outline drawings for coordination of equipment and physical location. Include in the drawings, the overall dimensions and weights of the equipment; the size and location of conduit and cable entrances; details of provisions for bolting equipment to the floor, walls, and ceilings; the equipment crate sizes and proposed routing to the installation site within the facility.

1.3.6 Schematic Diagrams, Connection Diagrams and one-line Diagrams

Submit schematic diagrams, connection diagrams and one-line diagrams for the completed substation to the Government. Documentation submitted is to indicate that the switchgear mechanical assembly, internal wiring and bus connections, and control logic for the entire substation satisfies the requirements and intent of the specifications. All controls and external connections indicated on the Contract Drawings are to be accounted for in the substation assembly. Point to point connection wiring diagrams are to show all terminal blocks and connections made externally or internally to the substation. Provide a space at least three inches below and adjacent to the terminal blocks in which external circuits, conduits or connections may be shown. The wiring diagrams are to be made as seen by an observer of the actual wiring and show all the wiring and devices in the cubicle/sections.

Solely using ladder logic or control diagrams to indicate wiring connections is not acceptable. The drawings are to include space for the addition of devices where mounting space exists on the structure.

1.3.7 Operations and Maintenance (O&M) Manuals Requirements

Operations and maintenance manuals must clearly describe the provided equipment including the operation, troubleshooting, and long-term preventative maintenance of each component used in the Substation. The equipment being provided under this contract is expected to be commercially available (with customized options) enough that the O&M manuals have already been substantially developed.

1.3.7.1 General Requirements

a. Drawings: Include all shop assembly or special drawings for manuals and parts catalogs. Number each sheet and provide an index.

b. Electronic O&M manual: Provide electronic versions of the O&M manuals with each file specific to the component as well as all files consolidated in a single PDF file with each of the files hyperlinked to a table of contents.

1.3.7.2 Required information available in typical O&M manuals

a. Include product instructions, procedures, and illustrations for the supplied model and features.

b. List personnel and equipment hazards or product safety precautions.

c. Include procedures required to install, set up, and prepare the equipment specific to the O&M manual.

d. Provide narrative description of Normal Operating Procedures. Include

Control Diagrams with data to explain operation and control of systems and specific equipment.

e. Include a list of Environmental Conditions (temperature, humidity, and other relevant data) that are best suited for the operation of each product, component, or system. Describe conditions under which the item equipment must not be allowed to run.

f. Include all original standard catalog cuts, manufacturer’s data, parts sheets, or illustrations. Parts catalogs must include identification, nomenclature, part numbers, required parts, recommended spare parts stocked, and spare parts supplied. Data must match equipment furnished.

Standard catalog data will not be acceptable unless irrelevant parts are marked out and relevant parts are clearly identified.

g. Special hardware: Include special hardware requirements, such as to use high-strength fasteners.

h. Provide copies of all factory test results, calibrations and settings performed by the manufacturer.

1.3.7.3 Preventative Maintenance:

Include the following information for preventative and scheduled maintenance to minimize corrective maintenance and repair for the installed model and features of each system.

a. Lubrication: Include required lubrication or grease points, type of lubrication or grease and frequency of application.

b. Include manufacturers schedule for routine preventative maintenance, inspections, tests, and adjustments required to ensure proper and economical operation and to minimize corrective maintenance. For periodic maintenance, provide manufacturer’s specified frequency and procedures for each separate operation. Provide recommended preventative maintenance plan for equipment that is substantially de-energized and in long term storage for greater than one year.

c. Cleaning recommendations

1.3.7.4 Corrective maintenance (repair)

a. Include manufacturer’s recommended procedures and instructions for correcting typical problems and making repairs.

b. Wiring diagrams and control diagrams must be point-to-point drawings of wiring and control circuits. On diagrams, number electrical and electronic wiring and the terminals for each type, identically to actual manufactured configuration and numbering.

c. Include a list of any specialized tools required to repair or restore the product or equipment to proper condition or operating standards.

d. Include step-by-step procedures and lists of required tools and supplies for removal, replacement, disassembly, and assembly of components, assemblies, subassemblies, accessories, and attachments required.

e. Include lists of replacement parts and supplies required for maintenance and repair to ensure continued service or operation without unreasonable delays. Include information to identify parts such as part numbers and manufacturer.

1.3.7.5 Electronic Control System: Provide a narrative of how to perform and apply all functions, features, modes, and other operations, including any automatic or remote operation, manual operation, and alarms.

Include detailed technical manual for programming if relevant.

a. Provide full as-built sequence of operations.

b. Provide copies of all factory test and calibrations performed by the manufacturer.

c. Provide full print out of all schedules and set points after testing and acceptance of the system.

1.4 HANDLING, DELIVERY, STORAGE, ASSEMBLY, AND FIELD-TESTING

1.4.1 Handling

1.4.1.1 The Substation Manufacturer is to provide lifting and handling provisions such that the equipment sections can be moved with a forklift or a crane.

1.4.1.2 Prior to shipment, the complete substation sections are to be factory wrapped or otherwise protected from dampness, dust, and physical damage during shipment.

1.4.1.3 The substation sections are to be manufactured to fit on standard trucks to allow for delivery to the site via the applicable States Road/freeway systems.

1.4.2 Delivery

Delivery will be to the Lost Creek Boneyard Storage Building shown in Attachment 2.

1.4.2.1 Offloading Plan

a. The Substation Manufacturer is to provide the onsite POC with the offloading plan at least 14 days prior to delivery. To ensure the appropriate amount of space is reserved, the offloading plan must outline the needed space for offloading the sections to the temporary storage location in the Lost Creek Boneyard Storage Building.

b. The Substation Manufacturer is responsible for arranging all equipment required to offload the substation sections into the Lost Creek Boneyard Storage Building.

c. Most of the road between the Cole Rivers Fish Hatchery and the

Boneyard is paved. There is a small section that is gravel.

1.4.2.2 Lost Creek Boneyard General

a. The Boneyard is not normally staffed. The closest location that is staffed approx. 2 miles away at the Lost Creek Powerhouse located at 100 Cole M Rivers Drive.

b. Normal USACE staff hours are Monday-Thursday, 0630-1700. If delivery or assembly will occur outside of these hours, coordinate with the onsite POC 14 days in advance.

c. The onsite POC for this contract will be Sarah Broaddus. The onsite POC is only able to arrange site access and has no contractual authority. Contact at:

sarah.j.broaddus@usace.army.mil 541-554-3713

d. Notify onsite POC with expected delivery date when the substation sections ship. Keep onsite POC updated as updates are available. Confirm final delivery date and approximate time with onsite POC at least 2 days prior to the delivery.

e. A USACE employee will facilitate entry through the security fence and into the building each day of assembly and testing during the normal USACE work hours as described in section b of this sub-paragraph “Normal USACE staff hours”. If access is needed outside of the normal USACE staff hours, communicate those needs as soon as possible. Whenever all Manufacturer personnel leave the area, all doors and gates are to be closed and locked. Reentry will have to be arranged with the onsite POC. The Government does not anticipate issuing a key for unescorted access into the Boneyard.

1.4.2.3 Lost Creek Boneyard Storage Building Structure

a. Dimensions, see sketch in Attachment 5:

1. Boneyard/Security Fence Perimeter: approx. 234’x230’

2. Double Open gate width: 20’ total

3. Storage Building: approx. 160’x48’

4. Maneuvering area: approx. 65’ between the security fence and the storage building

b. The long side of the building (length) has 5 roll doors mailto:sarah.j.broaddus@usace.army.mil measuring 18 ft x 18 ft each. After reviewing the submitted offloading plan and associated manufacturer’s drawings, the onsite POC will determine which bay is best suited to offload and assemble the substation.

c. Of the 48’ width, there is approximately 40’ available for use inside (the rear wall has storage racks on it that can’t be relocated).

d. The building ceiling height is 20 feet.

e. The floor inside the building is concrete as shown in

Attachment 4.

f. The yard outside the building is compacted gravel as shown in Attachment 4.

1.4.2.4 Lost Creek Storage Building Utilities

a. There is limited lighting inside the building. The bay doors may be opened to provide natural light if desired.

b. Limited 120V outlets are available throughout the building.

c. One 480V welding receptacle is available for use inside the building, 2-3 bays from where reassembly will likely occur.

d. There is a small air compressor with variable pressure output up to 200 PSI.

e. Water is not available

f. Restrooms are not available

g. WIFI is not available

h. Cellular service is very limited

i. Telephone is not available

j. The building is not climate controlled (no heat or AC) in the main portion of the building. There is a room within the building that is heated, but not cooled, that could be used by the reassembly/testing personnel to warm up or store tools and equipment.

1.4.3 Storage

a. Manufacturer will provide recommended long-term storage plan at least 14 days prior to delivery to allow Government personnel to review and make necessary building/utility modifications.

b. The substation will be stored in a de-energized state with only the Manufacturer recommended loads having temporary power supplied to them.

c. As defined in paragraph 1.3.7.3 Preventative Maintenance, the Manufacturer will provide a recommended preventative maintenance plan for equipment in long-term, substantially de-energized storage.

1.4.4 Assembly

1.4.4.1 The Substation Manufacturer is responsible for providing all the load handling equipment and tools necessary for reassembly.

1.4.4.2 For utilities available for use during reassembly, see paragraph “Lost Creek Storage Building Utilities”

a. The Substation Manufacturer must provide extension cords, air hoses and fittings needed to reassemble the substation.

1.4.4.3 The Government may witness the re-assembly.

1.4.5 Post-assembly Field Testing:

The Substation Manufacturer is to prepare a post-assembly field-testing procedure that tests all functions of the substation. The government reserves the right to cancel post-assembly field testing if required equipment or utilities are not available in time.

a. The Manufacturer led post-assembly field-testing will be conducted by the Manufacturer with Government personnel observing to understand the procedures.

b. The Manufacturer led field-testing procedure must be provided to the onsite POC a minimum of 30 days in advance of the delivery to allow the Government time to arrange support for the Manufacturer led field testing and modify utilities necessary to complete the Manufacturer led field-testing.

c. The field tests must be completed with only 120VAC control power supplied to the substation. Medium voltage and 2 sources of 480VAC is not available for full voltage testing.

d. The Manufacturer led field-testing procedure must test all functions of the substation to verify the substation is fully functional after shipment and reassembly.

e. The Manufacturer led field-testing procedure must identify utilities and equipment (to include test equipment) needed to complete the field testing. For available utilities, see paragraph “Lost Creek Storage Building Utilities”

f. The factory acceptance test procedure can serve as the

Manufacturer led post-assembly field test procedure if the factory tests can be safely performed in the field while the substation is substantially de-energized. Should the factory test procedure be used as the field test procedure, the test result must match. The Substation Manufacturer will be responsible for troubleshooting and repairing any issues causing the result to differ.

g. The Substation Manufacturer is responsible for troubleshooting and repairing damages sustained during shipping at no extra cost to the Government.

h. The Government may choose to perform additional testing at its own cost and with its own testing equipment to establish baseline conditions with the Government owned test equipment. The Manufacturer may choose to witness this testing at no additional cost to the Government. A test plan specific to the supplied substation will be generated by the Government prior to testing.

Typical inspections and tests that may be performed are:

1. Full visual inspection including noting the serial numbers,

2. Contact resistance test through each of the breakers,

3. Insulation resistance test between phases,

4. Insulation resistance test across open contacts,

5. Vacuum integrity AC hipot test,

6. Insulation AC hipot test,

7. Rack out and in each breaker at the breaker,

8. Rack out and in each breaker with supplied remote racking device,

9. Manual operation (Close, Open) of each breaker using mechanical charging and push to trip/push to open buttons,

10. Test trip free operation,

11. Electrical operation of each breaker (Close, Trip, Close, Open) at the breaker,

12. Electrical of each breaker (Close, Trip, Close, Open) with supplied remote operation device,

13. Notate operation count.

1.5 QUALIFICATIONS

The automatic transfer switch (ATS), ATS controller, medium and low voltage switchgear and circuit breakers are all to be made by the same manufacturer.

1.6 FACTORY TESTING

1.6.1 Submit the Factory Test Procedure prior to factory testing. The factory test equipment and test methods used must conform to the applicable requirements of ANSI, IEEE, NEMA and NETA standards.

1.6.2 Arrange factory testing with the Government at least 14 days in advance to allow the Government to witness the factory testing.

1.6.3 Submit all Factory Inspection and Test Reports after the completion of the tests. Include all measured results and setpoints.

1.7 OUTDOOR RATING

The substation’s permanent location will be outdoors near 200 Cole M Rivers Drive, Trail, Or. Unless specified elsewhere in this document, all equipment and cables must be rated to operate between the record low of minus 10 and the record high of 114 degrees Fahrenheit.

Equipment must be rated to operate in all humidity conditions, 0-100%.

The switchgear must be rated for a snow load of 12.0 psi and rated to withstand the highest recorded wind speed of 127 MPH.

PART 2 PRODUCTS

2.1 SUBSTATION ASSEMBLY

The requirements in this section apply to the entire substation. For voltage specific requirement see subsequent sections.

2.1.1 Enclosure

2.1.1.1 General

The enclosures are to be of a ventilated, dead-front, freestanding construction.

a. Enclosures must be constructed to prevent inadvertent access to energized parts and the ingress of solid foreign objects.

b. Enclosure must be constructed per IEEE/ANSI C37.20.3 Outdoor Specifications which exceeds NEMA 3R.

c. The enclosure must be constructed such that all points are solidly bonded to the cubicle ground connection

d. The enclosure must not be able to be walked into.

e. All bolts, studs, machine screws, nuts, and tapped holes are to be in accordance with ASME B1.1

f. The required number of vertical sections must be bolted together to form a rigid assembly.

g. Barriers between compartments must be greater than No. 11 MSG

h. Each vertical section must have a sloped weatherproof room with labyrinth shaped joints.

i. Use of gasket or caulking to make roof joints weatherproof are not permitted

j. Eccentric or concentric knockouts are not allowed in the enclosure. All holes for conduits need to be drilled and punched in the field.

k. Enclosure finish must be in accordance with paragraph 2.15

PAINTING

l. The assembly is to be rated for 125 mile/hour sustained winds.

2.1.1.2 Exterior Doors, Covers, Panels

a. The sides are to be covered with removable bolt-on covers.

b. The enclosure must have smooth sheet steel panels, suitably supported.

c. Doors and panels used to support instruments, and other devices must be greater than No. 11 MSG

d. Cable compartment access is to be provided by hinged rear doors, complete with quarter turn latches and provisions for padlocking.

e. Exposed panels on the front and ends of the enclosure are to be bent angle or channel edges with all the corner seams welded and ground smooth or be the Manufacturer’s equivalent construction.

f. All external doors and covers must have gaskets.

g. The front outside surfaces are not to be drilled or welded for the purpose of attaching wires or mounting devices if such holes or fastenings are to be visible from the front.

2.1.1.3 Substation Handling

a. The assembly is to be provided with means to move with a forklift or a crane. Handling provisions must be configured such that the assembly sections can be positioned in both the temporary storage location and the future, yet to be determined, permanent location.

b. Provisions are to be made for:

(1) Jacking of shipping groups,

(2) Removal of skids or insertion of rollers

c. Base of the assembly is to be suitable for rolling directly on pipes without skids.

d. The base is to be equipped with slots in the base frame members to accommodate the use of pry bars for moving the equipment to its final position.

2.1.1.4 Ventilation and Openings

a. All exterior openings must be screened to prevent entrance of small animals and insects.

b. All exterior opening must be barriered to prevent snow, sand and other natural outdoor materials from entering.

c. Each vertical section must be vented at the top and bottom, both front and rear to allow airflow for cooling and assist in prevent moisture buildup within the section.

d. The enclosure must be dust resistant.

e. The ventilated openings must have filters to prevent dust from entering the substation.

f. The ventilated covers must be externally removable to allow safe maintenance of the filter without exposing live parts.

2.1.1.5 Vertical Sections

a. Each vertical steel unit forming part of the switchgear line-up are to be a self-contained housing having one or more individual breaker or instrument compartments, a centralized buss compartment and a rear cable compartment.

b. Each individual circuit breaker compartment or cell are to be segregated from adjacent compartments and sections by means of steel barriers to the maximum extent possible.

c. Current transformers for instrumentation, where shown on the plans, are to be located within the appropriate cells and be front accessible, removable, and provided with shorting terminal block in the front wireway.

d. Ventilation openings requirements are identified in paragraph “Ventilation and Openings”

2.1.1.6 Heaters

a. Each vertical section must include a minimum of (1) 250-watt, 120-volt space heater.

b. All the space heaters must be energized weather on normal or emergency backup power.

2.1.2 Nameplates

a. Nameplates must be provided for transformers, circuit breakers, switches, and switchboards and elsewhere as required by the contract drawing and this document.

b. Transformer, circuit breaker, switch and switchboard nameplates are to be mounted on the front panel or door of the appropriate section of the substation in accordance with the contract drawings.

c. The Substation Manufacturer is permitted to supply and attach to the switchgear assembly a nameplate or trademark.

d. Provide a nameplate for each item of equipment, which does not have a suitable designation included as an integral part of the device, with an engraved nameplate or with other approved suitable means of identification.

e. Make nameplates of laminated sheet plastic or of anodized aluminum approximately 1/8 inch thick, engraved to provide white letters on a black background.

f. Provide equipment of the withdrawal type with nameplates mounted on the removable equipment in locations visible when the equipment is in place.

g. Fasten the nameplates to the panels in proper positions with black finished roundhead screws.

h. Provide each control switch with an escutcheon clearly marked to show each operating position. The switch identifications are to be engraved on the escutcheon plates or on separate nameplates.

2.1.3 Ground Bus

a. The substation assembly is to have a full-length interior ground bus bar to which the housing, framework, cable supports, bus supports, and all non-current carrying metallic parts of all equipment and conduits are grounded.

b. Grounding is to conform to IEEE C37.20.1 except that the ground conductor is to have a continuous current-carrying capacity not less than 25 percent of the continuous rating of the circuit breakers.

c. The ground bus is to have a connection pad for connecting to the footing concrete encased electrode and to the mechanical-electrical building ground.

2.2 480V LOW VOLTAGE SWITCHGEAR AND CIRCUIT BREAKERS

2.2.1 General Requirements

The 480V low voltage switchgear and circuit breakers are to be included as an integral part of the substation assembly.

a. Except as otherwise specified or indicated, the layout, construction and tests of the switchgear are to conform to the applicable requirements of IEEE C37.13, and IEEE C37.20.1. The assembly is to be used to distribute power from one 2000kVA, 13800-480/277 volt 3-phase, 60-Hz, station service transformer to 480-volt loads around the Cole Rivers Hatchery.

b. The Substation Manufacturer is to incorporate an integral ATS controller to switch the switchgear's main, generator, and feeder circuit breakers using these circuit breaker's opening and closing internal circuitry. The ATS is to shed non-critical loads, as defined in the Contract Drawings, when the substation is operating on generator power. Once normal power resumes the ATS is to reconnect these loads to the system. This is to operate automatically without assistance from site personnel.

c. Furnish instruments, control accessories, and other equipment mounted on the front panels and inside the switchgear as shown on the Contract Drawings and as specified.

d. Provide remote racking and control for each breaker.

e. Submit a complete package of the 480 Volt switchgear information, to include, but not limited to, complete Manufacturer's data sheets, installation and troubleshooting manuals, field testing procedure, parts listings, high resistance ground equipment and equipment descriptions for all equipment purchased under this Contract.

Manufacturer's data and catalog cuts to demonstrate fully that all parts of the equipment conform to the requirements and intent of the specifications.

f. Voltage rating is to be 480VAC, 60Hz, as indicated on the

Contract Drawings. The entire assembly is to be suitable for 600 Vac maximum service.

g. The assembly is to be rated to withstand mechanical forces exerted during short-circuit conditions when connected directly to a power source having available fault current of 65kA symmetrical at rated voltage.

h. The bus system is to have a minimum IEEE/ANSI short-circuit withstand rating of 100kA symmetrical tested in accordance with IEEE/ANSI C37.20.1 and UL1558, and CSA C22.2 No. 31 where required.

i. All circuit breakers are to have a minimum symmetrical interrupting capacity of 65kAIC. To ensure a fully selective system, all circuit breakers are to have 30 cycle short time withstand ratings equal to their symmetrical interrupting ratings through 85 kA, regardless of whether equipped with instantaneous trip protection or not.

j. All ratings are to be tested to the requirements of IEEE/ANSI

C37.20.1, ANSI C37.50, ANSI C37.51, and UL 1558, witnessed and approved.

2.2.2 Switchgear Enclosure and Framework

See paragraph 2.1.1 Enclosure

2.2.3 General Drawout Circuit Breakers

a. Each drawout type circuit breaker is to be completely enclosed in a metal compartment. Provide access to the instrument circuit breakers, instrument wiring, relay wiring, instrument transformers and fuses through hinged steel doors in each breaker compartment.

All hinged doors are to have bent angle or channel edges with all corner seams welded and ground smooth or be the manufacturer's equivalent construction as approved. Doors are to have hidden hinges with suitable latches or fastenings. Access to bus compartments is to be through removable bolted panels or cover plates on the rear.

b. The stationary part of the primary disconnecting devices for each power circuit breaker is to be breaker mounted and consist of a set of contacts extending to the rear through a glass polyester insulating support barrier; corresponding moving finger contacts, suitably spaced, is to be furnished on the power circuit breaker studs which engage in only the connected position. The assembly is to provide multiple silver-to-silver full floating high pressure point contacts with uniform pressure on each finger maintained by springs. Each circuit is to include the necessary three-phase bus connections between the section bus and the breaker line side studs. Bus extensions are to be plated similarly to the main bus where outgoing terminals are attached.

c. The removable power circuit breaker element is to be equipped with disconnecting contacts and interlocks for draw-out application. It is to have four positions, "connected," "test," "disconnected" and "removed." The breaker draw-out element is to contain a worm gear levering "in" and "out" mechanism with removable lever crank.

Levering is to be accomplished via the use of conventional tools.

Mechanical interlocking is to be provided so that the breaker is in the tripped position before levering "in" or "out" of the cell.

Interlocking that trips the breaker is not to be accepted. The breaker cell is to include an optional provision for key locking open to prevent manual or electric closing. Padlocking is to provide for securing the breaker in the connected, test, or disconnected position by preventing levering. Breaker is to be ready to accept connection of remote racking device without modification of breaker, cell or door.

d. An insulating flash shield is to be mounted above each circuit breaker to prevent flashover from the arc chutes to ground.

e. Infra-red (IR) Viewing Windows:

1. IR Windows are to be provided on the rear of the switchgear enclosures.

2. The Substation Manufacturer is to provide the number of windows required to view each circuit breaker cable lug to allow IR sensing of each breaker in the closed position under load conditions without having to open the enclosure.

3. A minimum of one window for each vertical breaker section is to be installed.

4. Windows are to feature a removable steel or aluminum security cover over a 4-inch crystal sight glass.

5. The IR windows are to be the switchgear Manufacturer's standard product, or a third-party product that is UL certified and arc-flash tested to the kA rating of the breakers or higher

6. The IR windows are to be installed with the coordination and approval of the switchgear Manufacturer.

f. Provide a glass polyester full height and depth barrier between adjacent vertical structures in the bus compartment with appropriate slots for main bus.

g. Provide a rear compartment barrier between the cable compartment and the main bus to protect against inadvertent contact with main or vertical bus bars. Barrier is to be solid grounded steel.

2.2.4 Buses And Connections

a. Each main bus is to have a continuous current-carrying capacity of not less than 3,200 amperes without exceeding the temperature limits specified in IEEE C37.20.1. The bus is to be braced to coordinate with the mechanical and thermal capacities of the interrupting rating of the main circuit breakers. The bus cannot be braced less than the breakers close and latch rating and be not less than braced 65kA momentary current. Bus bars are to be of hard-drawn copper bars and shapes conforming to the requirements of ASTM B187/B187M. Shop splices and tap connections are to be brazed, pressure-welded or bolted. All splices for field assembly are to be bolted. Where bolted connections are used, contact surfaces are to be silver-plated and have adequately located bolts to provide proper contact pressure for low conductivity. The bus is to be mounted on insulating supports of wet process porcelain, glass polyester, or suitable molded material. All primary connections including the power connections to the line side of the circuit breakers are to be by bus bar.

b. The standard phasing within equipment housing for AC power circuits is to be A-B-C from left to right when facing the front of the equipment, A-B-C from top to bottom, and A-B-C from front to back.

Nonstandard phasing in any compartment is to be permitted only upon approval. If approved, identify each phase and a warning sign, "Nonstandard Phasing," is to be incorporated within such a compartment.

c. All bus bars are to be silver-plated copper. Main horizontal bus bars are to be mounted with all three phases arranged in the same vertical plane. Bus sizing to be based on IEEE/ANSI standard temperature rise criteria of 65°C over a 40°C ambient (outside the enclosure).

d. Provide a full capacity neutral bus.

e. All hardware used on conductors to be high-tensile strength and zinc plated. All bus joints to be provided with Belleville-type washers.

f. The primary means of insulation and isolation of main and vertical bus is to be by air gap. Minimal use of insulating material in addition to the air gap is to be provided.

g. Grounding studs to be installed on the main bus for applying safety grounds in the field. The studs are to be accessible through removable rear bolted covers.

2.2.5 Ground Bus

See paragraph 2.1.3 Ground Bus for ground bus requirement applicable to the entire substation.

a. The operating mechanism of the drawout units is to be permanently grounded, ground contacts are to be provided to automatically connect the movable element to the ground buses.

2.2.6 Main and Generator Power Circuit Breakers

a. The main (FXMQ1) and generator (FXGQ1) circuit breakers are to be electrically operated drawout type with the remote opening and closing mechanism. FXMQ1 is to be rated 600 VAC, 3,200 ampere frame size, 65,000 amperes symmetrical interrupting capacity. FXGQ1 is to have a frame size shown on the Contract Drawings with a short-circuit interrupting capacity of not less than 65,000 rms symmetrical amperes at 600 volts AC. Provide each circuit breaker with an integral digital electronic trip unit (ETU, see below). For individual trip settings on each breaker see the Contract Drawings.

b. In conjunction with the digital electronic trip unit, provide an arc flash reduction maintenance switch (ARMS) to engage the appropriate instantaneous element to reduce the arc flash level. Mount the provided switch and indicating lamp on the breaker cell (cubicle) door. The switch to have means to install a padlock.

2.2.7 Feeder Power Circuit Breakers

Feeder breakers FXQ1 through FXQ12 are to be electrically operated drawout type with the remote opening and closing mechanism. Circuit breakers are to have a frame size shown on the Contract Drawings with a short-circuit interrupting capacity of not less than 65,000 rms symmetrical amperes at 600 volts AC. For individual trip settings on each breaker see the Contract Drawings.

2.2.8 Main, Generator and Feeder Circuit Breaker Components

All 480VAC circuit breakers are to have digital electronic trip units (ETU) described below. All are to be drawout type with a protective factory-supplied weather cover. See paragraph “2.2.3 General Drawout Circuit Breakers” for general breaker specifications.

2.2.8.1 Digital Electronic Trip Unit (ETU)

a. Each low voltage power circuit breaker is to be equipped with a true RMS sensing, solid-state tripping system consisting of at least three current sensors microprocessor-based trip device and flux-transfer shunt trip. The trip unit is to use microprocessor-based technology to provide the basic adjustable time-current protection functions. Current sensors are to be of Rogowski coil type. The continuous current rating "In" is to be established via trip device firmware.

b. The nominal current rating "In" sets the maximum continuous ratings of the breaker and can be reduced by changing the firmware-based rating only. Replacing current sensors are not to be required.

c. The trip unit is to have an information system that utilizes battery backup LEDs to indicate mode of trip following an automatic trip operation. The indication of the mode of trip is to be retained after an automatic trip. A reset button is to be provided to turn off the LED indication after an automatic trip. A test pushbutton is to energize a LED to indicate the battery status.

d. The trip unit is to be provided with a display panel, including a representation of the time/current curve that will indicate the protection functions. The unit is to be continuously self-checking and provide a visual indication that the internal circuitry is being monitored and is fully operational.

e. The trip unit is to be provided with a making-current release circuit. The circuit is to be armed for approximately two cycles after breaker closing and is to operate for all peak fault levels above 25 times the ampere value of the rated current "In".

f. Trip unit is to have selectable powered and unpowered thermal memory for enhanced circuit protection.

g. Complete system selective coordination is to be provided by the addition of the following individually adjustable time/current curve shaping solid-state elements:

1. All circuit breakers are to have adjustments for long delay pickup and time

2. All circuit breakers are to have individual adjustments for short delay pickup and time, and include I2t settings

3. All circuit breakers are to have an adjustable instantaneous pickup

4. All feeder circuit breakers are to have individually adjustable ground fault current pickup and time and include I2t settings.

h. The trip unit is to be capable of providing zone interlocking for the short-time delay and ground fault delay trip functions for improved system coordination. The zone interlocking system is to restrain the tripping of an upstream breaker and allow the breaker closest to the fault to trip with no intentional time delay. In the event that the downstream breaker does not trip, the upstream breaker is to trip after the present time delay.

i. The trip unit is to have an LCD display capable of navigating settings and programming them via navigation buttons on the trip unit.

j. The trip unit is to be capable of communicating with a PC utilizing factory software via micro-B USB connection.

k. The Main, Feeder and Generator circuit breaker trip units are to utilize Arc flash Reduction Maintenance System (ARMS). ARMS is to be provided in the system to reduce the trip unit Instantaneous pickup value when activated. ARMS device is not to compromise breaker phase protection even when enabled. Once ARMS unit is disabled, the recalibration of trip unit phase protection is not to be required.

l. Activation and deactivation of ARMS setting is to be accomplished without opening the circuit breaker door and exposing operators to energized parts. ARMS is to provide a clearing time of 0.04 seconds, adjustable with a minimum of five settings ranging from 1.5x to 10x of the "In" value.

ARMS is to be enabled via a remote panel switch and indicated that it is enabled by a remote blue LED, both mounted adjacent the circuit breaker.

m. The trip unit is to include a power/relay module which is to supply control to the readout display. Following an automatic trip operation of the circuit breaker, the trip unit is to maintain the cause of trip history and the mode of trip LED indication as long as its internal power supply is available. An internal relay is to be programmable to provide contacts for remote ground alarm indication.

n. The trip unit is to include a voltage divider board, suitable for operation up to 600 V, 50/60 Hz which is not to require a disconnect plug for high-potential (hi-pot) or dielectric testing.

o. The display for the trip units is to be a LCD display. Metering display accuracy of the complete system, including current sensors, auxiliary CTs, and the trip unit, are to be ±0.5% of metered current values.

p. Main and Generator breakers only: Metering display accuracy of the complete system be ±0.5% of metered voltage value, and ±1.0% of full scale for power and energy values to IEEE/ANSI C12.1.

q. The unit is to be capable of monitoring the following data:

1. Instantaneous, minimum, and maximum values of phase, neutral and ground current

2. Main and Generator breakers only: Instantaneous, minimum, and maximum of line-to-line voltage and line-to-neutral voltage

3. Main and Generator breakers only: Power metering including demand power and power factor

4. Main and Generator breakers only: Energy metering including directional, nets and total

r. Main and Generator breakers only: The energy-monitoring parameter values (peak demand, present demand, and energy consumption) are to be indicated on the trip units LCD screen.

s. Main and Generator breakers only: The trip unit is to display the following power quality values: crest factor, power factor, percent total harmonic distortion, and harmonic values of all phases through the 35th harmonic.

t. An adjustable high load alarm is to be provided adjustable from 50 to 100% of the long delay pickup setting along with the ability to disable the alarm.

u. System coordination is to be provided by the following microprocessor-based programmable time-current curve shaping adjustments. The short-time pickup adjustment is to be dependent on the long delay setting. The adjustments are:

1. Programmable long-time setting

2. Programmable long-time delay with selectable for feeder breakers: I2t

3. Programmable long-time delay with selectable for Main and Generator breakers: I2t, It, I1/2t, or I4t curve shaping

4. Programmable short time setting

5. Programmable short-time delay with selectable flat or I2t curve shaping, and zone selective interlocking

6. Programmable instantaneous setting that can be disabled

7. Feeder breakers: Programmable ground fault setting trip or ground fault setting alarm that can be disabled

8. Feeder breakers: Programmable ground fault delay with selectable flat or I2t curve shaping and zone selective interlocking

v. Main and Generator breakers only: The trip unit is to have the following extra advanced features integral to the trip unit:

1. Under and Over voltage pickup and delays (ANSI 27 and 59)

2. Voltage unbalance pickup and delays (ANSI 47)

3. Reverse power pickup and delay (ANSI 32R)

4. Current unbalance pickup and delay (ANSI 46)

5. Phase loss pickup and delay (ANSI 78V)

w. Breaker Health Monitoring and Diagnostics:

The trip unit is to collect and store pertinent information to the trip unit and circuit breaker health and event…