switchboard - lv gen transfer and load management.doc

PSG Section 16429E

emergency transfer and load management Switchboard - Low Voltage

Section 16429E

section 16429E

emergency transfer and load management SwitchBoard

low VOLTAGE

PART 1 general

1.01 Scope

A. The Contractor shall furnish and install, where indicated on the drawings, a complete standby power generation and load management power distribution and control system. B. The Emergency Power System consists of the following as applicable:

1. Generator sets

2. Generator Control Switchboard (with associated monitoring and distribution equipment)

3. Automatic Transfer Switches

4. Uninterruptible Power Supply Systems

5. Load Banks

6. Battery Systems

C. The Emergency Power System Supplier (EPSS) shall be an authorized service provider for all components of the Emergency Power System (EPS). In order to assure maximum equipment uptime and best service response to the owner, the Emergency Power System Supplier shall be a factory-authorized dealer with complete Emergency Power System parts and service available on a 24 hour emergency basis within a (_________ mile radius of the project site. An additional tier of service shall be available on a 24 hour emergency basis through regionally located factory technicians.D. The Generator Control Switchboard specified in this section shall be a dead front type, low voltage switchboard construction. The Generator Control Switchboard shall be by the same manufacturer as the generator sets and furnished with the generator sets by the (EPSS) as a total system. The switchboard and circuit breakers utilized in the Generator Control Switchboard shall be products of the same manufacturer as the circuit breakers provided in the assemblies for the normal and emergency distribution as specified under other sections of the specifications.

E. ( [An independent third party] [The Emergency Power System Supplier] shall provide a Short Circuit and Coordination Study, performed by a qualified professional engineer, as specified in the contract documents and described in Part 3 below.

1.02 Related Sections

A. Section 16496 Automatic Transfer Switches

B. Section 16911 Power Monitoring and Control System

C. Section (_____ Uninterruptible Power Supply System

D. Section (_____ Generators

E. Section (_____ Load Bank

F. Section (_____ Battery Systems

G. Section 16015A Short Circuit / Coordination Studies

H. Section 16015B Arc Flash Study

1.03 References

A. The low voltage distribution switchboards and all components shall be designed, manufactured and tested in accordance with the latest applicable following standards:

1. NEMA PB-2

2. UL Standard 891.

B. The Emergency Power System shall meet or exceed the applicable requirements for the following standards as required:

1. UL

2. CSA

3. IEC

4. NFPA 70

5. NFPA 99

6. NFPA 110

1.04 Submittals for Review/approval

A. The following information shall be submitted to the Engineer:

1. Master drawing index

2. Front view elevation

3. Floor plan

4. Top view

5. Single line drawing

6. Controls One-Line diagram

7. Nameplate schedule

8. Component list

9. Conduit entry/exit locations

10. Assembly ratings including:

a. Short-circuit rating

b. Voltage

c. Continuous current

11. Major component ratings including:

a. Voltage

b. Continuous current

c. Interrupting ratings

12. Circuit Breaker Schedule

a. Cable terminal sizes

13. Product data sheets.

14. Sequence of operation description

B. Where applicable, the following additional information shall be submitted to the Engineer:

1. Busway connection

2. Connection details between close-coupled assemblies

3. Composite floor plan of close-coupled assemblies

4. Key interlock scheme drawing and sequence of operations.

1.05 Submittals for construction

A. The following information shall be submitted for record purposes:

1. Final as-built drawings and information for items listed in Paragraph 1.04

2. Wiring diagrams

3. Certified production test reports

4. Installation information

5. Seismic certification and equipment anchorage details as specified

B. The final (as-built) drawings shall include the same drawings as the original construction drawings and shall incorporate all changes made during the manufacturing process.

1.06 Qualifications

A. The manufacturer of the assembly shall be the manufacturer of the major components within the assembly.

B. For the equipment specified herein, the manufacturer shall be ISO 9001 or 9002 certified.

C. The manufacturer of this equipment shall have produced similar electrical equipment for a minimum period of five (5) years. When requested by the Engineer, an acceptable list of installations with similar equipment shall be provided demonstrating compliance with this requirement.

D. (Provide Seismic qualified equipment as follows:

1. The equipment and major components shall be suitable for and certified by actual seismic testing to meet all applicable seismic requirements of the 2006 International Building Code (IBC). Equipment certification acceptance criteria shall be based upon the ability for the equipment to be returned to service immediately after a seismic event within the above requirements without the need for repairs.

2. The following minimum mounting and installation guidelines shall be met, unless specifically modified by the above referenced standards.

a. The Contractor shall provide equipment anchorage details, coordinated with the equipment mounting provision, prepared and stamped by a licensed civil engineer in the state. Mounting recommendations shall be provided by the manufacturer based upon the above criteria to verify the seismic design of the equipment.

b. The equipment manufacturer shall certify that the equipment can withstand, that is, function following the seismic event, including both vertical and lateral required response spectra as specified in above codes.

c. The equipment manufacturer shall document the requirements necessary for proper seismic mounting of the equipment. Seismic qualification shall be considered achieved when the capability of the equipment, meets or exceeds the specified response spectra.

1.07 Regulatory Requirements

A. The low-voltage switchboard shall be UL labeled.

1.08 Delivery, Storage and Handling

A. Equipment shall be handled and stored in accordance with manufacturers instructions. One (1) copy of these instructions shall be included with the equipment at time of shipment.

B. Each switchboard assembly shall be split into shipping groups for handling as determined during the shop drawing phase jointly with the installing contractor. Shipping groups shall be designed to be shipped by truck, rail or ship. Shipping groups shall be bolted to skids, and covered with tarps for protection from weather. Accessories shall be packaged separately.

1.09 Operation and Maintenance Manuals

A. Equipment operation and maintenance manuals shall be provided with each assembly shipped and shall include instruction leaflets, instruction bulletins and renewal parts lists where applicable, for the complete assembly and each major component.

PART 2 Products

2.01 manufacturers

A. Caterpillar

B. (__________

C. (__________

The listing of specific manufacturers above does not imply acceptance of their products that do not meet the specified ratings, features and functions. Manufacturers listed above are not relieved from meeting these specifications in their entirety.2.02 Ratings

A. The assembly shall be rated to withstand mechanical forces exerted during short-circuit conditions when connected directly to a power source having available fault current of ([(65,000) (100,000) (150,000) amperes symmetrical at rated voltage] [as shown on the drawings]. B. Voltage rating to be as indicated on the drawings.

2.03 Construction

A. Switchboard shall consist of the required number of vertical sections bolted together to form a rigid assembly. The sides and rear shall be covered with removable bolt-on covers. All edges of front covers or hinged front panels shall be formed. Provide adequate ventilation within the enclosure.

B. All sections of the switchboard shall be front and rear aligned with depth as shown on drawings. All generator main protective devices shall be individually mounted. All distribution protective devices shall be group mounted. Devices shall be front removable and load connections front and rear accessible. Rear access shall be provided.

C. The assembly shall be provided with adequate lifting means.

D. The switchboard shall be equal to Caterpillar utilizing the components herein specified and as shown on the drawings.

E. (The switchboard shall be suitable for use as service entrance equipment and be labeled in accordance with UL requirements.

2.04 Bus

A. All bus bars shall be ([silver-plated copper] [tin-plated aluminum]. Main horizontal bus bars shall be mounted with all three phases arranged in the same vertical plane. Bus sizing shall be based on NEMA standard temperature rise criteria of 65 degrees C over a 40 degrees C ambient (outside the enclosure).

B. Provide a full capacity neutral bus where a neutral bus is indicated on the drawings.

C. A copper ground bus (minimum 1/4 x 2 inch) shall be furnished firmly secured to each vertical section structure and shall extend the entire length of the switchboard.

D. All hardware used on conductors shall be high-tensile strength and zinc-plated. All bus joints shall be provided with conical spring-type washers.

2.05 Wiring/Terminations

A. Small wiring, necessary fuse blocks and terminal blocks within the switchboard shall be furnished as required. Control components mounted within the assembly, such as fuse blocks, relays, pushbuttons, switches, etc., shall be suitably marked for identification corresponding to appropriate designations on manufacturers wiring diagrams.

B. NEMA 2-hole ([mechanical-] [crimp-] type lugs shall be provided for all line and load terminations suitable for copper or aluminum cable rated for 75 degrees C of the size indicated on the drawings.

C. Lugs shall be provided in the incoming line section for connection of the main grounding conductor. Additional lugs for connection of other grounding conductors shall be provided as indicated on the drawings.

D. All control wire shall be type SIS, bundled and secured with nylon ties. Insulated locking spade terminals shall be provided for all control connections, except where saddle type terminals are provided integral to a device. All current transformer secondary leads shall first be connected to conveniently accessible short-circuit terminal blocks before connecting to any other device. All groups of control wires leaving the switchboard shall be provided with terminal blocks with suitable numbering strips. Provide wire markers at each end of all control wiring.

E. Where individual conductors cross switchboard shipping splits they shall be fitted with plug-together connectors for reliable field assembly.

2.06 Insulated case circuit breakers Generator Main Breakers and Controlled (Load Shed) Distribution Breakers

A. Protective devices shall be drawout UL1066 low-voltage insulated case circuit breakers. Frame ratings shall be 800, 1200, 1600, 2000, 2500, 3000, 4000, 5000, or 6000 amperes. All breakers shall be UL1066 listed for application in their intended enclosures for 100% of their continuous ampere rating.

B. Circuit breakers shall be electrically operated and equipped with auxiliary contacts, bell alarm contacts, and microprocessor based trip units. C. Electrically operated breakers shall be complete with 24Vdc shunt trips, and 120VAC motor operators, the charging time of the motor shall not exceed 6 seconds.

D. All circuit breakers shall have a minimum symmetrical interrupting capacity of ([50,000] [65,000] [85,000] [100,000] [150,000] amperes.

E. All insulated case circuit breakers shall be provided with trip units as specified in section 2.07.

F. To facilitate lifting, the insulated case circuit breaker shall have integral handles on the side of the breaker. The insulated case circuit breaker shall have a closing time of not more than 3 cycles. The primary contacts shall have an easily accessible wear indicator to indicate contact erosion.

G. The insulated case circuit breaker shall have three windows in the front cover to clearly indicate any electrical accessories that are mounted in the breaker. The accessory shall have a label that will indicate its function and voltage. The accessories shall be plug and lock type and UL listed for easy field installation. They shall be modular in design and shall be common to all frame sizes and ratings.

H. The breaker control interface shall have color-coded visual indicators to indicate contact open or closed positions as well as mechanism charged and discharged positions. Manual control pushbuttons on the breaker face shall be provided for opening and closing the breaker. The insulated case circuit breaker shall have a Positive On feature. The breaker flag will read Closed if the contacts are welded and the breaker is tripped or opened.

I. The current sensors shall have a back cover window that will permit viewing the sensor rating on the back of the breaker. A rating plug will offer indication of the rating on the front of the trip unit.

J. A position indicator shall be located on the faceplate of the breaker. This indicator shall provide color indication of the breaker position in the cell. These positions shall be Connect (Red), Test (Yellow), and Disconnect (Green). The levering door shall be interlocked so that when the breaker is in the closed position, the breaker levering-in door shall not open.

K. Each insulated case circuit breaker shall offer sixty (60) front mounted dedicated secondary wiring points. Each wiring point shall have finger safe contacts, which will accommodate #10 AWG maximum field connections with ring tongue or spade terminals or bare wire.

L. The breaker cell shall be equipped with drawout rails and primary and secondary disconnecting contacts. The stationary part of the primary disconnecting devices for each insulated case circuit breaker shall consist of a set of contacts extending to the rear through a glass polyester insulating support barrier; corresponding moving finger contacts suitably spaced shall be furnished on the insulated case circuit breaker studs which engage in only the connected position. The assembly shall provide multiple silver-to-silver full floating high-pressure point contacts with uniform pressure on each finger maintained by springs.

1. The secondary disconnecting devices shall consist of plug-in connectors mounted on the removable unit and engaging floating plug-in connectors at the front of the compartment. The secondary disconnecting devices shall be gold-plated and pin and socket contact engagement shall be maintained in the connected and test positions.

2. The removable insulated case circuit breaker element shall be equipped with disconnecting contacts, wheels and interlocks for drawout application. It shall have four (4) positions: CONNECTED, TEST, DISCONNECTED, and REMOVED all of which permit closing the compartment door. The breaker drawout element shall contain a worm gear levering in and out mechanism with removable lever crank. Mechanical interlocking shall be provided so that the breaker is in the tripped position before allowing access to the levering mechanism for levering in or out of the cell. Interlock systems that trip the breaker when accessing the levering mechanism will NOT be acceptable. The breaker shall include an optional provision for key locking open to prevent manual or electric closing. Padlocking shall provide for securing the breaker in the connected, test, or disconnected position by preventing levering.2.07 Microprocessor trip units - Insulated case circuit breakers*Note to Spec. Writer:

Digitrip RMS trip units are available in four (4) models:

Digitrip RMS 520 Basic protection select paragraph 2.07 A through I.

Digitrip RMS 520M Basic protection with local current metering, select paragraph 2.07 A through K.

Digitrip RMS 520MC Basic protection with local current metering and remote communications, select paragraph 2.07 A through L, and Z.

Digitrip RMS 1150+ Advanced protection, metering, LED display and remote communications, select paragraph 2.07 A through E, H through J, and L through Z.

A. Each low voltage insulated case circuit breaker shall be equipped with a solid-state tripping system consisting of three current sensors, microprocessor-based trip device and flux-transfer shunt trip. Current sensors shall provide operation and signal function. The trip unit shall use microprocessor-based technology to provide the basic adjustable time-current protection functions. True RMS sensing circuit protection shall be achieved by analyzing the secondary current signals received from the circuit breaker current sensors and initiating trip signals to the circuit breaker trip actuators when predetermined trip levels and time delay settings are reached. Interchangeable current sensors with their associated rating plug shall establish the continuous trip rating of each circuit breaker. B. The trip unit shall have an information system that provides LEDs to indicate mode of trip following an automatic trip operation. The indication of the mode of trip shall be retained after an automatic trip. A reset button shall be provided to turn off the LED indication after an automatic trip.

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

D. The trip unit shall be provided with a making-current release circuit. The circuit shall be armed for approximately two cycles after breaker closing and shall operate for all peak fault levels above 25 times the ampere value of the rating plug.

E. Trip unit shall have selectable thermal memory for enhanced circuit protection.

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

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

2. (Main circuit breakers shall have individual adjustments for short delay pickup and time, and include I2t settings.

3. (Main circuit breakers shall have an adjustable instantaneous pickup.

4. ([All circuit breakers] [Circuit breakers, where indicated on the drawings,] shall have individually adjustable ground fault current pickup and time, and include I2t settings or ground alarm only.

G. The trip unit shall have provisions for a single test kit to test each of the trip functions.

H. The trip unit shall provide zone interlocking for the short-time delay and ground fault delay trip functions for improved system coordination. The zone interlocking system shall 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 shall trip after the present time delay. (Factory shall wire for zone interlocking for the insulated case circuit breakers within the switchboard.I. The trip unit shall 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 shall be retained after an automatic trip operation. The indication of the mode of trip shall be retained after an automatic trip. A test pushbutton shall energize a LED to indicate the battery status.

J. ([All circuit breakers] [Circuit breakers, where indicated on the drawings,] shall have individually adjustable ground fault alarm only.

K. The trip unit shall have a 4-character LCD display showing phase, neutral, and ground current. The accuracy of these readings shall be +/- 2% of full scale.

L. The trip unit shall be equipped to permit communication via a network twisted pair for remote monitoring and control.

M. The trip unit shall include a power/relay module which shall supply control to the readout display. Following an automatic trip operation of the circuit breaker, the trip unit shall 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 shall be programmable to provide contacts for remote ground alarm indication.

N. The trip unit shall include a voltage transformer module, suitable for operation up to 600V, 50/60 Hz. The primary of the power relay module shall be connected internally to the line side of the circuit breaker through a dielectric test disconnect plug.

O. The display for the trip units shall be a 24-character LED display.

P. Metering display accuracy of the complete system, including current sensors, auxiliary CTs, and the trip unit, shall be +/- 1% of full scale for current values. Metering display accuracy of the complete system shall be +/- 2% of full scale for power and energy values.

Q. The unit shall be capable of monitoring the following data:

1. Instantaneous value of phase, neutral and ground current

2. Instantaneous value of line-to-line voltage

3. Minimum and maximum current values

4. Watts, VARs, VA, watt-hours, var-hours, and VA hours.

R. The energy-monitoring parameter values (peak demand, present demand, and energy consumption) shall be indicated in the trip units alphanumeric display panel.S. The trip unit shall display the following power quality values: crest factor, power factor, percent total harmonic distortion, and harmonic values of all phases through the 31st harmonic.

T. An adjustable high load alarm shall be provided, adjustable from 50 to 100% of the long delay pickup setting.

U. The trip unit shall contain an integral test pushbutton. A keypad shall be provided to enable the user to select the values of test currents within a range of available settings. The protection functions shall not be affected during test operations. The breaker may be tested in the TRIP or NO TRIP test mode.

V. Programming may be done via a keypad at the faceplate of the unit or via the communication network.

W. System coordination shall be provided by the following microprocessor-based programmable time-current curve shaping adjustments. The short-time pickup adjustment shall be dependant on the long delay setting.

1. Programmable long-time setting

2. Programmable long-time delay with selectable I2T or I4T curve shaping

3. Programmable short-time setting

4. Programmable short-time delay with selectable flat or I2T curve shaping, and zone selective interlocking

5. Programmable instantaneous setting

6. Programmable ground fault setting trip or ground fault setting alarm

7. Programmable ground fault delay with selectable flat or I2T curve shaping and zone selective interlocking.

X. The trip unit shall offer a three-event trip log that will store the trip data, and shall time and date stamp the event.

Y. (The trip unit shall have the following advanced features integral to the trip unit:

1. Adjustable under voltage release

2. Adjustable over voltage release

3. Reverse load and fault current

4. Reverse sequence voltage alarm

5. Under frequency

6. Over frequency

7. Voltage phase unbalance and phase loss during current detection

Z. ([1150 and 520MC only] The trip unit shall utilize ARMs Technology (Arc Flash Reduction Maintenance System). The ARMs Technology shall be provided in a system that shall reduce the trip unit Instantaneous pickup value when activated. The ARMs device shall not compromise breaker phase protection even when enabled. Once the ARMs unit is disabled, the recalibration of trip unit phase protection shall not be required. Activation and deactivation of the ARMs Technology trip setting shall be accomplished without opening the circuit breaker door and exposing operators to energized parts. The ARMs Technology shall provide a clearing time of 0.04 seconds, adjustable with a minimum of five settings ranging from 2.5X to 10X of the sensor value.

1. The ARMs Technology shall be enabled via a switch on the trip unit. It shall also provide confirmation of protection via a Blue LED.

2. (The ARMs Technology shall be provided with remote enable/disable control and confirmation of protection via an IR communication link.

3. (The ARMs Technology shall be provided with a switchboard panel mounted enable padlockable selector switch and indication via Blue LED pilot light.

4. (The ARMs Technology shall be wired locally with interposing relays and wired to terminal blocks to enable a remote selector switch and confirmation light to be mounted a the downstream protected distribution equipment.

*Note to Spec. Writer: For remote enable/indication add in the downstream distribution equipment specification a requirement for a padlockable selector switch and Blue LED confirmation light.

2.08 Molded-Case Circuit Breakers Non-Controlled distribution Breakers

A. Protective devices shall be fixed-mounted, molded case circuit breakers with inverse time and instantaneous tripping characteristics.

B. Circuit breakers shall be operated by a toggle-type handle and shall have a quick-make, quick-break over-center switching mechanism that is mechanically trip-free. Automatic tripping of the breaker shall be clearly indicated by the handle position. Contacts shall be nonwelding silver alloy and arc extinction shall be accomplished by means of DE-ION arc chutes. A push-to-trip button on the front of the circuit breaker shall provide a local manual means to exercise the trip mechanism.

C. Circuit breakers shall have a minimum symmetrical interrupting capacity ([of (65,000) (100,000) (150,000) amperes symmetrical at rated voltage] [as shown on the drawings]. D. Circuit breakers ([250-] [400-] [600-] [800-] ampere frame and below shall be thermal-magnetic type trip units and inverse time-current characteristics.

E. Circuit breakers ([400-] [600-] [800-] ampere through 2500-ampere frame shall be microprocessor-based RMS sensing type trip units.

F. (Ground fault protection shall be provided where indicated.

G. (Where indicated circuit breakers shall be current limiting. H. (Where indicated provide UL listed circuit breakers for applications at 100% of their continuous ampere rating in their intended enclosure. 2.09 Microprocessor TRIP UNITS Molded-Case Distribution Circuit Breakers

A. Each molded case circuit breaker microprocessor-based tripping system shall consist of three (3) current sensors, a trip unit and a flux-transfer shunt trip. The trip unit shall use microprocessor-based technology to provide the adjustable time-current protection functions. True RMS sensing circuit protection shall be achieved by analyzing the secondary current signals received from the circuit breaker current sensors, and initiating trip signals to the circuit breaker trip actuators when predetermined trip levels and time-delay settings are reached.

B. An adjustable trip setting dial mounted on the front of the trip unit, or interchangeable ratings plugs shall establish the continuous trip ratings of each circuit breaker. Rating plugs shall be fixed or adjustable as indicated. Rating plugs shall be interlocked so they are not interchangeable between frames, and interlocked such that a breaker cannot be closed and latched with the rating plug removed.

C. System coordination shall be provided by the following microprocessor-based time-current curve shaping adjustments:

1. Adjustable long-time setting (set by adjusting the trip setting dial or rating plug)

2. Adjustable short-time setting and delay with selective curve shaping

3. Adjustable instantaneous setting

4. (Adjustable ground fault setting and delay.

D. The microprocessor-based trip unit shall have both powered and unpowered thermal memory to provide protection against cumulative overheating should a number of overload conditions occur in quick succession

E. When the adjustable instantaneous setting is omitted, the trip unit shall be provided with an instantaneous override.

F. Where internal ground fault protection is specified, adjustable settings shall not exceed 1200 amperes. Provide neutral ground fault sensor for four-wire loads.

G. Breakers shall have built-in test points for testing the long-time delay, instantaneous, and ground fault functions of the breaker by means of a test set. ([Provide one test set capable of testing all breakers 250-ampere frame and above].

2.010 accessories

A. Provide shunt trips, bell alarms and auxiliary switches as shown on the contract drawings.

B. Provide a ([traveling type circuit breaker lifter, rail-mounted on top of switchgear] [floor running portable circuit breaker transfer truck with manual lifting mechanism].

2.011 miscellaneous devices

A. Key interlocks shall be provided as indicated on the drawings.

B. Control power transformers with primary and secondary protection shall be provided, as indicated on the drawings, or as required for proper operation of the equipment. ([Control power transformers shall have adequate capacity to supply power to the transformer cooling fans.]

C. (Each section of the switchboard shall be provided with a space heater ([thermostatically controlled]. Power for the space heaters shall be obtained ([from a control power transformer within the switchboard] [from a source as indicated on the drawings]. Supply voltage shall be ([120] [240] volts AC. 2.012 Enclosures

A. NEMA 1 Enclosure

B. (Outdoor Walk-in Enclosure

1. Switchgear shall be enclosed in an outdoor walk-in NEMA 3R enclosure conforming to all applicable requirements of UL and designed to withstand wind velocities of ([110] [125] mph. The enclosure shall have a roof sloping toward the rear. Outer sections shall be the same widths as indoor structures except the end sections of a walk-in enclosure shall be wider than the inner sections to permit opening the inner door. Each end of the outdoor structure shall have an end trim. Front aisle depth for walk-in structures shall be 42 inches, minimum.

2. The enclosure shall be provided with rear hinged padlockable doors with wind stops for each section. Aisle doors shall be supplied with provisions for padlocking. A steel floor shall be provided in walk-in aisle space. ([Steel floor plates shall be provided in the rear cable compartment.] An anti-skid floor strip shall be provided in the aisle. Ventilating openings shall be provided complete with replaceable fiberglass air filters which are removable from the exterior of the enclosure. Provide necessary space heaters thermostatically controlled for breaker, bus and cable compartments of adequate wattage to prevent the accumulation of moisture within the compartments.

3. Provide panic door hardware on aisle doors at each end of the line-up. External padlocking of the aisle doors shall not prevent operation of the panic hardware from the interior of the enclosure. The construction of the enclosure shall be modular so future sections can be added without affecting NEMA 3R integrity. Provide interior aisle fluorescent lights, 3-way switches and GFI protected receptacles.

4. The enclosure shall be provided with undercoating applied to all members in contact with the foundation surface to retard corrosion.

5. Power for the space heaters, lights and receptacles shall be obtained from a ([control power transformer within the switchgear] [source as indicated on the drawings]. Supply voltage shall be 120 volts AC.

6. An overhead circuit breaker lifter shall be provided in the aisle of the enclosure.

7. Each shipping section shall be shipped completely assembled.

C. (Outdoor Non-Walk-in Enclosure

1. Switchgear shall be enclosed in an outdoor non-walk-in NEMA 3R enclosure conforming to all applicable requirements of UL and designed to withstand wind velocities of ([110] [125] mph. The enclosure shall have a roof sloping toward the rear. Outer sections shall be the same widths as indoor structures except the end sections of a non-walk-in enclosure shall be wider than the inner sections to permit opening the inner door. Each end of the outdoor structure shall have an end trim.

2. The enclosure shall be provided with front and rear hinged padlockable doors with wind stops for each section. Aisle doors shall be supplied with provisions for padlocking. ([Steel floor shall be provided in the rear cable compartment.] Ventilating openings shall be provided complete with replaceable fiberglass air filters which are removable from the exterior of the enclosure. Provide necessary space heaters thermostatically controlled for breaker, bus and cable compartments of adequate wattage to prevent the accumulation of moisture within the compartments.

3. The construction of the enclosure shall be modular so future sections can be added without affecting NEMA 3R integrity. Provide interior fluorescent lights, switches and GFI protected receptacles.

4. The enclosure shall be provided with undercoating applied to all members in contact with the foundation surface to retard corrosion.

5. Power for the space heaters, lights and receptacles shall be obtained from a ([control power transformer within the switchgear] [source as indicated on the drawings]. Supply voltage shall be 120 volts AC.

6. A portable overhead circuit breaker lifter shall be provided to assist in removal of the circuit breakers from the enclosure.

7. Each shipping section shall be shipped completely assembled.

2.013 Nameplates

A. Engraved nameplates, mounted on the face of the assembly, shall be furnished for all main and feeder circuits as indicated on the drawings. Nameplates shall be laminated plastic, black characters on white background. Characters shall be 3/16-inch high, minimum. Nameplates shall give item designation and circuit number as well as frame ampere size and appropriate trip rating.

B. Furnish master nameplate giving switchboard designation, voltage ampere rating, short-circuit rating, manufacturers name, general order number, and item number.

C. Control components mounted within the assembly, such as fuse blocks, relays, pushbuttons, switches, etc., shall be suitably marked for identification corresponding to appropriate designations on manufacturers wiring diagrams.

2.014 Finish

A. All exterior and interior steel surfaces of the switchboard shall be properly cleaned and provided with a rust-inhibiting phosphatized coating. Color and finish of the switchboard shall be ANSI 61 light gray.

2.015 (surge protective devicesA. Provide surge protective devices as specified in Section 16671.

*Note to Spec. Writer:The Emergency Power System Automation & Controls described below is available in Standard and High Redundancy Packages. Choose features according to the selected package.

2.016 Emergency Power System (EPS) automation & Controls

A. The automation and control system shall facilitate overall EPS operation including automatic standby operation, monitoring and control of the generator sets including start/stop, alarm/fault monitoring, synchronizing, generator kW load sharing, generator kVAR load sharing, generator loading/unloading, load shed/add, power factor control when in Utility paralleling operation, and protective relaying.

B. The EPS Automation and Controls shall utilize true redundant, distributed processing technology to maximize system reliability and fault tolerance. The distributed processing system shall include a separate automation processor for each power source, and a separate processor dedicated to each touchscreen Human/Machine Interface (HMI) operation.

C. The EPS Automation and Controls shall be by the same manufacturer as the switchgear and generator sets. It shall be furnished with the generator sets by the Emergency Power System Supplier as a total coordinated and integrated system.*Note to Spec. Writer:Choose one of the HMI Options below

2.017 HMI HUMAN/MACHINE INTERFACE [standard package]

A. EPS Automation interface shall be via a touchscreen with the following characteristics:

1. Color, 15 (diagonal) TFT LCD display capable of displaying both text and graphics.

a. The display shall support a minimum resolution of 1024x768 pixels, 256 displayable colors.

2. Integral alarm and event recording

-- (OR --

2.018 HMI HUMAN/MACHINE INTERFACE [high redundancy package]

A. EPS system interface shall be via a touchscreen with the following characteristics:

1. Color, 19 inch (diagonal) TFT LCD industrial display capable of displaying both text and graphics.

2. The touch screen shall be clear glass, with light transmission of 95% or better, furnished with a Surface Acoustic Wave touch interface.

3. The display shall support a minimum resolution of 1280 x 1024 pixels, 16 million displayable colors, 24~60kHZ horizontal scan rate, 56-75kHZ refresh rate.

4. The EPS touch screen processor shall contain no moving parts.

2.019 HMI Screen Listing

A. The EPS Automation shall provide the following screens. The screens shall provide all of the information, metering, control, annunciations settings and indications listed below:

1. Main menu screen with a complete listing of major screens.

2. System overview screen with an animated graphic display of the electrical one line.

3. System control screen

4. System metering screen

5. System settings screen.

6. Generator control screen for each generator set

7. Generator metering screen for each generator set

8. Generator set settings screen.

9. Generator set demand priority control and status screen.

10. Generator set load shed control and status screen.

11. Engine monitoring screens for each generator set that shall contain a graphical representation of engine gauges and data

12. Utility control screen

13. Utility metering screen

14. Utility setting screen

15. Annunciator screens as follows:

a. System annunciation screen that shall contain status, lamp test and alarm points.

b. Generator set annunciator screen for each generator set that shall contain status, lamp test, pre-alarms and shutdown faults.

c. Utility annunciation screen that shall contain status, lamp test and alarm points

16. Password entry screen that shall contain a numeric keypad for password entry.

17. Alarm Summary Screen that shall contain a time/date stamped System Alarm Summary. Alarm log shall be exportable to external media.

*Note to Spec. Writer:The additional HMI Screens listed below are provided with the High Redundancy Package only

18. Report menu screen as follows:

a. System settings report

b. Generator set settings report

c. Plant test report including all current operational parameters

d. ([NFPA compliant JCAHO report]

e. Alarm summary report

19. System real time trend screen.

20. Generator set real time trending screens.

21. (Historical trending package.

22. (A printer shall be provided for local printing of system reports.

*Note to Spec. Writer: (for systems with Generator Bus Tie Breakers)

23. (Tie control screen

24. Tie metering screen

25. Tie setting screen

2.020 (UNIT DISPLAY

A. A unit display shall be furnished for each generator set shall be mounted on the door of the switchboard section containing the associated generator set controls. The unit display shall have as a minimum a 5.7 graphic LCD transflective display, and shall be capable of monitoring and controlling its associated generator set.

2.021 (Remote Power Monitoring System

A. A PC based remote power ([monitoring][monitoring and control] system shall be provided to monitor breaker status, alarms, metering and other operating parameters. All ([control functions, displays metering][displays, metering] and other information described in these specifications shall be available to the operator of the Remote System.

B. The remote system shall be designed such that its operation shall not in any way impede the selected automatic operation of the system control. Any failure of the remote system shall have no impact to the automatic operation of the system control.

C. The remote system shall provide the identical screens and resolution at the remote screen as seen at the Switchboard HMI as noted above.

D. The remote system shall communicate with the system control via high speed network.

E. A PC workstation shall be provided by ([owner][EPSS] for the remote power system with the following minimum features:

Intel Pentium CPU operating at 3.0 GHz, 4GB RAM, 160GB hard drive, 3.5 floppy disk drive, CDRW/DVD drive, 22 flat screen monitor, keyboard and optical mouse,10/100MHz Ethernet network interface card, Windows XP operating system, laser printer for reports (optional), line printer for alarm/event reports (optional).

2.022 (data Table Interface (DTI)A. The system shall allow interface from the users building management system.

B. The DTI shall be designed such that the building management system or external user interface shall in no way compromise the integrity or interfere with the critical operations of the EPS control system.

Interface to the users building management system shall be via [RS-485] [Ethernet] communications, utilizing [Modbus RTU] [Modbus/TCP] Protocol.

2.023 (REMOTE NOTIFICATION

A. The system shall be capable of providing several types of remote notification. Notification shall be triggered by user specified events and/or alarms. Means of notification shall include:

1. Voice notification via cell phone or land lines.

2. Pager notification

3. Email notification

2.024 Emergency Power System (EPS) FEATURES

A. The EPS automation and controls shall consist of the hardware and software required for the control of the engine-generator plant and associated utility, tie, and distribution circuit breakers. The system shall include all automation controllers, HMI (Human / Machine Interface) touchscreens, power transducers, supervisory networks and all ancillary control equipment necessary to automatically execute the specified functional sequence of operations.

B. The EPS Automation shall be provided with an HMI consisting of a touchscreen display.

1. The HMI shall provide all metering, status, monitoring, and control information to the operator.

2. The HMI shall serve only as an operator interface. The EPS must continue to function normally with a complete HMI failure.

C. The EPS automation and controls shall be designed to eliminate single points of failure.

1. For redundancy, multiple automation processors shall be utilized.

2. At a minimum, the EPS controls shall utilize a separate automation processor for each generator power source.

3. Control systems utilizing a single automation processor are not acceptable.

D. The EPS automation and controls shall be capable of surviving a fault of one or more of its automation controllers. The failure of any generator controller shall only cause loss of automatic operation of a single generator. *Note to Spec. Writer:The following feature is provided with the High Redundancy Package only

The failure of any single master controller or utility controller shall in no way hinder the full automatic operation of the entire EPS automation and control system.

E. Operator/System Safety Provisions

1. Circuit Breaker Control Switch (CBCS) - A separate circuit breaker control switch (CBCS) shall be provided for each source and tie circuit breaker controlled by EPS automation. CBCS functionality shall be manual and separate from EPS automation. Each CBCS will include a Pull to Lock function in the trip position. A CBCS locked in the trip position shall override all EPS automation functionality.

2. (A separate hardware synchronization check relay (ANSI Device 25) shall be furnished in addition to the sync check functions provided by the EPS system for each paralleling circuit breaker.

F. Master Control Functions

1. Master control redundancy levels shall be equal to the number of generator sets in the system.

2. Any required transfer of master control functions shall be transparent and bumpless.

3. Master control functions shall include:

a. Automatic start of the generator plant

b. First-up, dead-bus functions

c. Automatic generator demand priority

1. The system controls shall include a generator demand priority control function to automatically match the on-line generator capacity to the loads, and avoid unnecessary operation of generator sets.

d. Automatic Load Shed / Add

1. The load shed control shall have one essential load shed priority level for each generator in the system plus one non-essential load shed priority level (which is always shed in the emergency mode of operation).

2. The load shed control shall control each of the distribution circuit breakers as shown on the drawings. Distribution circuit breakers to be controlled shall be electrically operated. Each electrically operated distribution circuit breaker shall be field selectable to be assigned to any of the available load shed priority levels.

G. Generator Set Control Functions

1. For safety and availability, all generator set control functions shall be executed autonomously from each generator set controller.

2. No master control coordination or intervention shall be required to affect the generator set control functions.

3. Generator set control functions shall include:

a. Operation of generator set circuit breaker

b. Generator set run command

c. Generator set protective and annunciator functions

d. Active synchronization

e. Synchronization check function (ANSI Device 25)

f. Load and VAR sharing calculations

g. Generator set load control

h. Generator set VAR control

i. Generator set metering functions

H. Utility Control Functions

1. For safety and availability, all Utility control functions shall be executed autonomously from each utility controller.

2. No master control coordination or intervention shall be required to affect the utility control functions.

3. A utility grade protective relay, as specified below, will monitor and protect the system against utility faults in parallel to the utility protective functions.

4. Utility control functions shall include:

a. Operation of utility circuit breaker

b. Utility protective and annunciator functions

c. Synchronization of generator sets to Utility

d. Utility metering functions

e. Utility tie circuit breaker monitoring and control

*Note to Spec. Writer:

The following Utility Control Redundancy applies only to the High Redundancy Package.

5. Utility Control Redundancya. Utility control functions shall be executed from fully redundant utility controllers.

b. Redundant power supplies, controllers, inputs, and outputs shall be provided.

c. Transfer of utility control functions from the primary utility controller to the back-up utility controller shall be transparent and bumpless.


The following System Master I/O Redundancy applies only the High Redundancy Package.

I. System Master I/O

1. System master I/O shall be fully redundant, including horn, horn silence, instant auto selector, load shed on/off, and load shed relays

2. Transfers from primary to back-up system master I/O shall be transparent and bumpless.

J. Load Shed / Load Add Distribution Circuit Breaker I/O

1. Load shed / load add I/O shall be monitored and controlled via the supervisory network.

2. Load shed / load add distribution circuit breaker I/O shall include:

a. Circuit breaker auxiliary contact monitoring

b. Circuit breaker bell alarm contact monitoring

c. Close circuit breaker output

d. Open circuit breaker output


The following Load Shed / Load Add Distribution Circuit Breaker I/O Redundancy applies only to the High Redundancy Package.

3. Load shed / load add distribution circuit breaker I/O redundancy

a. Load shed / load add I/O shall be fully redundant.

b. Transfers from primary to back-up load shed / load add I/O shall be transparent and bumpless.

K. Supervisory Network

1. The supervisory network shall consist of a non-proprietary topology and utilize open source protocols.

2. Supervisory network topology shall be EMI and RFI noise tolerant.

3. Supervisory network data rate shall be a minimum of 10Mbps.

4. All critical plant control data communication shall be deterministic with an update rate not to exceed 100ms.

5. The supervisory network shall be a fully dedicated network, providing high speed communication for the following:

a. Communications of control data between distributed controllers

b. Distribution of master control data

c. Communications to and from the system HMI(s)

d. Communications to and from the customer building management / Data Table Interface (DTI).

e. Communication to and from 3rd party balance of plant PLCs (as specified)


The following Supervisory Network Redundancy applies only to the High Redundancy Package.

6. Supervisory Network Redundancy

a. The Supervisory network shall be fully redundant. Supervisory network cable switching schemes are not acceptable.

b. Transfers from the primary to the back-up supervisory network shall be transparent and bumpless.

L. EPS automation control power system shall be protected against single point of failure by the utilization of a 24Vdc, best source DC system strategy. The control power system shall include the following features:

1. The best source DC bus shall accept 24vdc power, through an isolation diode and circuit breaker, from each generator set battery.

2. An additional station battery and battery charger shall be provided to maintain system control power in the event that all generator set batteries and their associated chargers should fail.

3. All EPS automation and controls shall be powered directly from this best source DC bus. DC-DC converters shall not be utilized.

M. The EPS automation and controls shall be provided with an Instant Auto Selector Switch that will shift the EPS to the fully automatic mode.

N. Each generator, utility, and tie circuit breaker controller shall be furnished with integral power sensing capabilities. Controller inputs shall include 3 phase voltage on both source and bus sides of the associated circuit breaker and 3 phase current inputs.

O. The EPS automation shall log all events and alarms with device, condition, and time/date stamp.


The trending below applies only to the High Redundancy Package.P. Real Time Trending

1. The EPS automation shall support real time trending.

2. Real time trending shall display the following:

a. Utility:

Average voltage, average current, kW, kVAR.

b. For each system generator set:

Voltage, amps per phase, kW, kVAR, frequency, engine RPM, engine battery voltage, engine oil pressure, engine water temperature.

Q. (Long Term Historical Trending

1. Long term historical trending shall log EPS data in non-volatile memory. This data shall be displayed in a strip chart format. Historical data file format shall be dbf to facilitate manipulation of these files in other software programs.

R. Full manual backup control shall be provided for generator set voltage and frequency.2.025 EPS automation & Controls Environmental specifications

A. The EPS automation controllers shall meet or exceed the following environmental requirements:

1. Control Power: 8 to 50 Vdc continuous (24 Vdc nominal)

2. Maximum: 80Vdc for 2 hours

3. Operating Temperature: -30 to 70 C4. Humidity: 5 95% non-condensing

5. Vibration: 4g; 2,5mm Amplitude; 5Hz to 150Hz6. Shock: 1: 40G peak, 11ms, saw tooth pulse, 3 shocks/axisB. All other EPS automation and control system components shall meet or exceed the following environmental requirements:

1. Control Power: 16 to 40 Vdc continuous (24 Vdc nominal)

2. Operating Temperature: 0 to 55 C3. Humidity: 5 to 95% non-condensing2.026 eps Metering

A. All metering functions shall be 0.5% accuracy or better. 1. The following metering shall be provided for the system bus, each individual utility, tie, and generator:a. Volts with 4-position selector switch to select three phases of voltageb. Amps with 4-position selector switchc. Kilowatts

d. Kilovars

e. Frequency

f. Power Factor

g. SynchroscopeB. All engine parameter data available on the generator set shall be accessible on the HMI.

C. (The following metering shall be provided for each distribution breaker:

1. Volts with 4-position selector switch to select three phases of voltage.2. Amps with 4-position selector switch.3. Kilowatts

4. Kilovars

5. Frequency

6. Power Factor

D. (Additional Metering

1. Where indicated on the drawings, provide a separate customer metering compartment with front hinged door.

2. Furnish and install current transformers located within the EPS switchboard for each meter. Current transformers shall be wired to shorting-type terminal blocks.

3. Furnish and install ([potential transformers including primary and secondary fuses with disconnecting means] [fused potential taps as the potential source] for metering as shown on the drawings.

Note to Spec. Writer:See Section 16901 Microprocessor Based Metering for functional descriptions.

2.027 protective Relays

A. The switchboard manufacturer shall furnish and install the quantity, type and rating of protection relays as indicated on the drawings and described hereafter in this specification.

B. Protective Relaying shall be microprocessor, high reliability, as specified below.C. GENERATOR PROTECTIVE RELAYING

1. Overcurrent (50/51) as provided by the microprocessor trip units described above. 2. Under/Over Voltage (27/59) Relay, 3-phase, percent adjustable, percent reset, with time delay.3. Over/Under Frequency (81 O/U) Relay, single phase, percent adjustable, percent reset, with time delay.4. Reverse Power (32) Relay, 3-phase, percent adjustable with time delay.5. Loss of Field (Reverse VAR, 40) Relay, 3-phase, percent adjustable with time delay.6. Automatic Synchronizer and Sync Check(15/25)

7. (Redundant Sync Check Relay (25).

D. UTILITY PROTECTIVE RELAYING

1. Overcurrent (50/51) as provided by the microprocessor trip units described above.

2. Automatic Synchronizer and Sync Check (15/25)

3. (Redundant Sync Check Relay (25).

4. Utility Lock-out (86) Relay (Utility Grade), manual reset.5. Utility Re-close Lock-out Switch with lockable cover.

6. A ([Multilin SR-750] [Schweitzer SEL 351] [Basler BE1-951] [Basler IPS-100], utility grade, multi-function protective relay shall be furnished, providing the following minimum functionality:

a. Under/Over Voltage (27/59) Relay, 3-phase, percent adjustable, percent reset, with time delay.b. Over/Under Frequency (81 O/U) Relay, single phase, percent adjustable, percent reset, with time delay.c. Phase Sequence/Phase Failure (47) Relay, 3-phase, percent adjustable, with time delayd. Reverse Power (32) Relay, 3-phase, percent adjustable with time delay.e. Reverse Direction Overcurrent (32/51) Relay, 3-phase, percent adjustable, with time delay.E. TIE PROTECTIVE RELAYING (Where applicable)

1. Overcurrent (50/51) as provided by the microprocessor trip units described above

2. Sync Check Relay (25).

3. ( Lock-out (86) Relay (Utility Grade), manual reset.4. ( Two - Redundant Sync Check Relays (25)

2.028 EPS ANNUNCIATION SYSTEM

A. The EPS shall be provided with local annunciation to monitor and display critical generator set, utility, and system status, fault, and shutdown information. B. Annunciation shall comply with NFPA 110 requirements. C. The annunciation system shall be equipped with a fast pulse horn (rated 80-95 dbA at two feet), a horn silence push-button and an acknowledge push-button. Any generator pre-alarm, generator shutdown alarm, or EPS alarm shall cause the alarm horn to sound until the horn silence button is depressed. Any subsequent alarms shall re-sound the horn. The display shall operate such that any alarm point shall flash until acknowledged.D. The annunciation system shall be provided with five (5) distinct types of annunciation points:

1. Status Points These annunciation points shall show the status of critical system or generator set components. Status annunciation points shall not sound the annunciation system horn. They shall not require acknowledgement.

2. Generator Set Pre-Alarm Points These annunciation points shall show fault conditions that could jeopardize the ability of the EPS to function properly without immediate attention. Generator set pre-alarm annunciation points shall sound the annunciation system horn. They shall require acknowledgement. Generator set pre-alarm annunciation points shall reset automatically as the alarm condition is cleared.

3. Generator Set Shutdown Alarm Points - These annunciation points shall show fault conditions that have caused the shutdown of one (1) or more generator sets. Generator set shutdown annunciation points shall sound the annunciation system horn. They shall require acknowledgement. Generator set shutdown annunciation points shall cause the generator set to shutdown and the generator main to trip open. The generator main is then locked out until the cause of the shutdown is corrected, the engine control switch is placed in Off/Reset, and then placed back in Auto or Manual position.

4. Utility Alarm Points These annunciation points will indicate utility related fault conditions. Utility annunciation points shall sound the annunciation system horn. They shall require acknowledgement.

5. EPS Alarm Points These annunciation points will indicate system wide fault conditions. EPS annunciation points shall sound the annunciation system horn. They shall require acknowledgement.

2.029 EPS SECURITY

A. EPS setting changes and adjustments shall be password protected.

B. A minimum of two (2) password protected security levels shall be provided.

2.030 Functional Sequence of Operations

A. The EPS automation shall be provided with the following modes of operation:

1. Automatic/Standby Mode

a. The utility main breaker is closed serving utility power to the generator/load bus.

b. The generator set main breakers are open.

c. The automation is standing by to act in response to a utility failure.

2. Emergency Mode

a. Utility Failure

1. Utility protective relaying senses utility voltage or frequency out of tolerance.

2. The utility main breaker is opened.

3. Load shed sequence is executed.

4. A run request is sent to the generator plant.

5. The first generator set up to voltage and frequency is closed to the bus.

6. ([ With Generator Bus Tie Breaker]The generator bus tie breaker is closed.

7. The remaining generator sets are synchronized and paralleled to the bus as they come up to voltage and frequency.

8. The system is now in emergency mode.

b. Utility Restoration and Exit from Emergency Mode

1. Utility protective relaying senses utility voltage and frequency within tolerance.

2. Following an adjustable time delay to assure that the utility power source is stable, a small frequency slew rate is established between the generator plant and the utility. The generator plant is passively synchronized and paralleled to the utility source by closing the utility main breaker.

3. The generator plant is soft ramp unloaded until the utility source is nominally serving the entire system load.

4. The generator set breakers are opened.

5. The generator sets are allowed to run for their programmed cool down period and shut down.

6. The system is returned to automatic/standby mode.

3. Transfer to Emergency Mode

a. Entry

1. The operator places the system into the closed transfer to emergency mode.


3. The generator sets are paralleled to the bus at no load.

4. When all generator sets are on the bus they are soft ramp loaded until the generator plant assumes the entire load on the bus and the utility main breaker is opened.-- (OR --

5. [With Generator Bus Tie Breaker] When all generator sets are on the bus, they are paralleled across the generator bus tie breaker. They are then soft ramp loaded until the generator plant assumes the entire load on the bus and the utility main is opened.

6. The system is now running in emergency mode.

b. Exit from Emergency Mode

1. The operator returns the system to the automatic mode.

2. Following an adjustable time delay, the generator plant is synchronized and paralleled to the utility source by closing the utility main breaker.

3. The generator plant is soft ramp unloaded until the utility source assumes the entire system load.

4. The generator set breakers are opened.

-- (OR --

1.[With Generator Bus Tie Breaker] The generator bus tie breaker is opened and then all of generator breakers are opened.2.The generators are allowed to run for their programmed cool down period and shut down.3.The system is returned to the automatic/standby mode.

4. Load Management Mode

a. Entry

1. The operator selects one of the following modes of operation:

i. Import Limit The system maintains utility kW import level at an operator defined minimum utility import limit.

ii. Export Limit The system maintains utility kW export level at an operator defined utility export setpoint.

iii. Base Load Import The system maintains an operator defined base load kW setpoint, subject to a minimum utility kW import limit.

iv. Base Load Export The system maintains an operator defined base load setpoint, regardless of whether power is being imported or exported.

2. The operator places the system in the load management mode.


4. The generator sets are allowed to run for an adjustable warm-up time.

5. The generator sets are synchronized and paralleled to the bus at no load after completion of the warm-up time.

6. When all generators are on the bus, they are soft ramp loaded until the generator plant assumes the required amount of the load on the bus to meet the mode of operation selected.

7. Should the utility fail at any time during load management operation, the utility protective relays shall cause the utility main to open and be locked out, thus placing the system in emergency mode until the utility is restored (as described in Emergency Mode exit).

b. Exit

1. The operator returns the system to the automatic mode.

2. The generator plant is soft ramp unloaded until the utility source assumes the system load, and the generator main breakers are opened.


4. The system is returned to the Automatic/Standby Mode.

5. No Load Test Mode

a. Entrance into No Load Test Mode

1. No load test is initiated by the operator.

2. All available generator sets are started.

3. All generator sets come up to voltage and frequency and remain running disconnected from the bus.

4. The system is now in no load test mode.

b. Exit from No Load Test Mode

1. No load test is terminated by the operator.


3. The system is returned to the Automatic/Standby mode.

6. Utility Fail Test Mode

a. Entrance into Utility Fail Test Mode

1. Utility fail test is initiated by the operator.

2. Voltage sensing at the utility protective relay is opened, which simulates a loss of utility.

3. The system enters into emergency mode as described in the emergency mode sequence above.

b. Exit from Utility Fail Test Mode

1. Utility fail test is terminated by the operator.

2. Voltage sensing at the utility protective relay is restored, which simulates the return of utility power.

3. The system exits from emergency mode as described in the emergency mode sequence above.

B. The EPS automation shall support two (2) sub-modes: Load Shed/Load Add, and Generator Demand Priority.

1. Load Shed

a. Conditional Load Shed: Upon entrance into emergency mode of operation, the load shed control shall open all sheddable circuit breakers. As generator sets come to the bus, essential priority level loads shall be added conditionally based on the number of generator sets on line. When the first generator set comes to the bus, priority level 1 loads shall be added; second generator set, priority 2, etc. After a time delay that allows all operational generator sets to come to the bus, the system shall shift to load sensitive mode.

b. Load Sensitive Load Shed: The system shall compare generator on-line capacity (in kW) to system load. If surplus generator capacity exists, load shed priority level(s) are added. If system load exceeds generator on-line capacity, load shed priority level(s) are shed. The load shed control, in its automatic shedding and adding of loads, shall not override any manual load shed/add operation.

c. Bus Underfrequency: Should the load bus frequency fall below the bus underfrequency setpoint, all priority level loads shall be shed. Load addition shall not resume until manually reset. The bus underfrequency protection shall override any manual load add operation.

Note to Spec. Writer:The following only applies to systems with two or more generator sets

2. Generator Demand Priority Control

a. Upon entrance into emergency or load management modes, all generator sets shall be started and paralleled to the bus. After a load stabilization delay, generator sets are automatically added to or removed from the bus according to system load demand.

2.031 spare parts

A. The EPS Supplier shall have factory trained technicians that maintain a stock of spare parts and programming tools.

B. Provide a complete listing of available spares parts with O&M Documents.

C. (At a minimum, provide 10% (minimum 1 each) of the following components as included in the Emergency Power System:

1. Controllers.

2. Generator set unit display.

3. Control relays.

4. Control fuses.

5. HMI touchscreen and touch screen processor.

6. Control power transformer.

7. System master I/O block.

8. Load Shed / Load Add I/O block.

9. Ethernet switch.

PART 3 execution

3.01 Factory Testing

A. The switchboard shall be completely and functionally tested in the manufacturer's facility prior to shipment. For systems shipped in multiple sections, the switchboard shall be quality tested utilizing the plug-together wiring system which shall be unplugged prior to shipment and plugged together again when the equipment is installed in order to maintain the integrity of the manufacturer's quality assurance testing.

B. The following standard factory tests shall be performed on the equipment provided under this section. All tests shall be in accordance with the latest version of ANSI and NEMA standards.

1. The switchboard shall be completely assembled, wired, adjusted, and tested at the factory. After assembly, the complete switchboard shall be tested for operation under simulated service conditions to assure the accuracy of the wiring and the functioning of all equipment. The main circuits shall be given a dielectric test of 2200 volts for one (1) minute between live parts and ground, and between opposite polarities. The wiring and control circuits shall be given a dielectric test of 1500 volts for one (1) minute between live parts and ground.

C. The manufacturer shall provide three (3) certified copies of factory test reports.

D. (The owners representative(s) shall conduct factory witness testing:

1. The owners representative shall provide a test plan to the manufacturer at least four (4) weeks prior to scheduled witness testing.

2. The manufacturer shall notify the owner two (2) weeks prior to the date the tests are to be performed.

3. The manufacturer shall include the cost of transportation and lodging for up to three (3) owners representatives. The cost of meals and incidental expenses shall be the owners responsibility.

3.02 Installation

A. Store equipment in a clean, dry place. Protect from weather, dirt, fumes, water, construction debris, and physical damage.B. The Contractors shall install all equipment per the manufacturers instructions, contract drawings and National Electrical Code.

C. The equipment shall be installed and checked in accordance with the manufacturers recommendations. This shall include but not limited to:

1. Checking to ensure that the pad location is level to within 0.125 inches per three foot of distance in any direction.

2. Checking to ensure that all bus bars are torqued to the manufacturers recommendations.

3. Assembling all shipping sections, removing all shipping braces and connecting all shipping split mechanical and electrical connections.

4. Securing assemblies to foundation or floor channels.

5. Measuring and recording Megger readings phase-to-phase, phase-to-ground, and neutral-to-ground (four wire systems only).

6. Inspecting and installing all circuit breakers in their proper compartments.

D. The assembly shall be provided with adequate lifting means and shall be capable of being moved into installation position and bolted directly to ([Contractor supplied floor sills to be set level in concrete per manufacturers recommendations] [the floor without the use of floor sills providing the floor is level to 1/8 inch per 3-foot distance in any direction]. Provisions shall be made for jacking of shipping groups, for removal of skids or insertion of equipment rollers. Base of assembly shall be suitable for rolling directly on pipes without skids. The base shall be equipped with slots in the base frame members to accommodate the use of pry bars for moving the equipment to its final position.

3.03 Field Quality Control AND startup

A. Provide the services of a qualified factory-trained manufacturers representative for start-up of the equipment specified under this section for a period of (____ working days. The manufacturers representative shall provide technical direction and assistance to the contractor in general assembly of the equipment, connections and adjustments, and testing of the assembly and components contained therein.

B. The manufacturers representative shall provide inspection of the final installation, perform functional testing, and start-up the EPS.

C. Functional Testing shall include testing of the following as a minimum:1. Pre-startup inspection of the generator, dc system, control wiring, power cables, and switchboard/switchgear.

2. Crank and run engine/generators at the local engine control panel.

3. Crank and run engine/generators from the HMI touchscreen.

4. Verify engine/generator alarms and shutdowns to HMI.

5. Verify protective relay/breaker trip units are set to coordination study if applicable.

6. Test all modes of operation.

7. Verify and test all system alarms to HMI.

8. Test with EPS with Load.

3.04 Training

A. The manufacturer shall provide an eight (8) hour "hands-on" training course for the customer's operating personnel which shall cover the following topics:

1. Overall system description and theory of operation.

2. Automatic operation.

3. Manual operation.

4. Safeties and protective relaying.

5. Recommended system check lists and log sheets.

6. Recommended preventive maintenance.

7. Instruction on the operation of the assembly, circuit breakers, and major components within the assembly.( Note to Spec. Writer Insert data in blanks

( Note to Spec. Writer Optional [Select one]

( Note to Spec. Writer Insert data in blanks

( Note to Spec. Writer - Optional


( Note to Spec. Writer Select one

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16429E-

02/20/13

switchboard - lv gen transfer and load management.doc

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emergency power system

control system

emergency distribution

power monitoring

generator control switchboard

psg section

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total system