emergency transfer and load management switchboard …pub/@electrical/... · emergency transfer and...

EMERGENCY TRANSFER AND LOAD MANAGEMENT SWITCHBOARD - LOW VOLTAGE

SECTION 26 24 13.31

26 24 13.31-1 6/06

* Note to Spec. Writer – Insert data in blanks

SECTION 26 24 13.31

EMERGENCY TRANSFER AND LOAD MANAGEMENT SWITCHBOARD

LOW VOLTAGE

GENERALPART 1

SCOPE1.01

The Contractor shall furnish and install, where indicated on the drawings, a complete A.standby power generation and load management power distribution and control system.

The Emergency Power System consists of the following as applicable:B.Generator sets1.Generator Control Switchboard (with associated monitoring and distribution 2.

equipment)Automatic Transfer Switches3.Uninterruptible Power Supply Systems4.Load Banks5.Battery Systems6.

The Emergency Power System Supplier (EPSS) shall be an authorized service provider for C.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.

The Generator Control Switchboard specified in this section shall be a dead front type, low D.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.

The Generator Control Switchboard specified includes overcurrent and protective devices. E.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.

RELATED SECTIONS1.02

Sections 26 36 23.11, 26 36 23.13, 26 36 23.15, & 26 36 13.11 – Automatic Transfer A.Switches

Section 26 09 13.13 – Power Monitoring and Control SystemB.

Section ****** – Uninterruptible Power Supply SystemC.


SECTION 26 24 13.31

26 24 13.31-2 6/06

* Note to Spec. Writer – Insert data in blanks

Section ****** – GeneratorsD.

Section ****** – Load BankE.

Section ****** – Battery SystemsF.

Section 26 05 73 – Short Circuit / Coordination StudiesG.

Section 26 05 73.11 – Arc Flash StudyH.

REFERENCES1.03

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

NEMA PB-21.UL Standard 891.2.

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

UL1.CSA2.IEC3.NFPA 704.NFPA 995.NFPA 1106.

SUBMITTALS – FOR REVIEW/APPROVAL1.04

The following information shall be submitted to the Engineer:A.Master drawing index1.Front view elevation2.Floor plan3.Top view4.Single line drawing5.Controls One-Line diagram6.Nameplate schedule7.Component list8.Conduit entry/exit locations9.Assembly ratings including:10.

Short-circuit ratinga.Voltageb.Continuous currentc.

Major component ratings including:11.Voltagea.Continuous currentb.


SECTION 26 24 13.31

26 24 13.31-3 6/06

* Note to Spec. Writer - Optional* Note to Spec. Writer – Select one

Interrupting ratingsc.Circuit Breaker Schedule12.

Cable terminal sizesa.Product data sheets.13.Sequence of operation description14.

Where applicable, the following additional information shall be submitted to the Engineer:B.Busway connection1.Connection details between close-coupled assemblies2.Composite floor plan of close-coupled assemblies3.Key interlock scheme drawing and sequence of operations.4.

SUBMITTALS – FOR CONSTRUCTION1.05

The following information shall be submitted for record purposes:A.Final as-built drawings and information for items listed in Paragraph 1.041.Wiring diagrams2.Certified production test reports3.Installation information4.Seismic certification and equipment anchorage details as specified5.

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

QUALIFICATIONS1.06

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

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

The manufacturer of this equipment shall have produced similar electrical equipment for a C.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.

*Provide Seismic tested equipment as follows:D.The equipment and major components shall be suitable for and certified to meet 1.

all applicable seismic requirements of the International Building Code (IBC) for zone 4 application. Guidelines for the installation consistent with these requirements shall be provided by the switchgear manufacturer and be based upon testing of representative equipment. The test response spectrum shall be based upon a 5% minimum damping factor, IBC: a peak of 2.45g’s (3.2-11 Hz), and a ZPA of 0.98g’s applied at the base of the equipment. The tests shall fully envelop this response spectrum for all equipment natural frequencies up to at least 35 Hz.

-- *OR –


SECTION 26 24 13.31

26 24 13.31-4 6/06

* Note to Spec. Writer – Select one

The equipment and major components shall be suitable for and certified to meet 1.all applicable seismic requirements of the California Building Code (CBC) through zone 4 application. Guidelines for the installation consistent with these requirements shall be provided by the switchgear manufacturer and be based upon testing of representative equipment. The test response spectrum shall be based upon a 5% minimum damping factor, CBC: a peak of 2.15g’s, and a ZPA of 0.86g’s applied at the base of the equipment. The tests shall fully envelop this response spectrum for all equipment natural frequencies up to at least 35 Hz.

-- *OR --The manufacturer may certify the equipment based on a detailed computer 1.

analysis of the entire assembly structure and its components. Guidelines for the installation consistent with these requirements shall be provided by the switchgear manufacturer and be based upon testing of representative equipment. The equipment manufacturer shall document the requirements necessary for proper seismic mounting of the equipment

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

The Contractor shall provide equipment anchorage details, coordinated with the a.equipment mounting provision, prepared and stamped by a licensed civil engineer in the state. Mounting recommendations shall be provided by the manufacturer based upon approved shake table tests used to verify the seismic design of the equipment.The equipment manufacturer shall certify that the equipment can withstand, that is, b.function following the seismic event, including both vertical and lateral required response spectra as specified in above codes.The equipment manufacturer shall document the requirements necessary for proper c.seismic mounting of the equipment. Seismic qualification shall be considered achieved when the capability of the equipment, meets or exceeds the specified response spectra.

REGULATORY REQUIREMENTS1.07

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

DELIVERY, STORAGE AND HANDLING1.08

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

Each switchboard assembly shall be split into shipping groups for handling as determined B.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.

OPERATION AND MAINTENANCE MANUALS1.09

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


SECTION 26 24 13.31

26 24 13.31-5 6/06

* Note to Spec. Writer – Insert data in blanks* Note to Spec. Writer – Select one* Note to Spec. Writer – Optional

PRODUCTSPART 2

MANUFACTURERS2.01

CaterpillarA.

*__________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.

RATINGS2.02

The assembly shall be rated to withstand mechanical forces exerted during short-circuit A.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].

Voltage rating to be as indicated on the drawings.B.

CONSTRUCTION2.03

Switchboard shall consist of the required number of vertical sections bolted together to form A.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.

All sections of the switchboard shall be front and rear aligned with depth as shown on B.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.

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

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

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

BUS2.04

All bus bars shall be *[silver-plated copper] [tin-plated aluminum]. Main horizontal bus bars A.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).

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


SECTION 26 24 13.31

26 24 13.31-6 6/06


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

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

WIRING/TERMINATIONS2.05

Small wiring, necessary fuse blocks and terminal blocks within the switchboard shall be A.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 manufacturer’s wiring diagrams.

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

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

All control wire shall be type SIS, bundled and secured with nylon ties. Insulated locking D.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.

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

INSULATED CASE CIRCUIT BREAKERS – GENERATOR MAIN BREAKERS AND 2.06CONTROLLED (LOAD SHED) DISTRIBUTION BREAKERS

Protective devices shall be drawout UL1066 low-voltage insulated case circuit breakers. A.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.

Circuit breakers shall be electrically operated and equipped with auxiliary contacts, bell B.alarm contacts, and microprocessor based trip units.

Electrically operated breakers shall be complete with 24Vdc shunt trips, and 120VAC motor C.operators, the charging time of the motor shall not exceed 6 seconds.

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

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

To facilitate lifting, the insulated case circuit breaker shall have integral handles on the side F.of the breaker. The insulated case circuit breaker shall have a closing time of not more than


SECTION 26 24 13.31

26 24 13.31-7 6/06

3 cycles. The primary contacts shall have an easily accessible wear indicator to indicate contact erosion.

The insulated case circuit breaker shall have three windows in the front cover to clearly G.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.

The breaker control interface shall have color-coded visual indicators to indicate contact H.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.

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

A position indicator shall be located on the faceplate of the breaker. This indicator shall J.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.

Each insulated case circuit breaker shall offer sixty (60) front mounted dedicated secondary K.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.

The breaker cell shall be equipped with drawout rails and primary and secondary L.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.

The secondary disconnecting devices shall consist of plug-in connectors 1.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.

The removable insulated case circuit breaker element shall be equipped with 2.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.


SECTION 26 24 13.31

26 24 13.31-8 6/06

* Note to Spec. Writer – Optional

MICROPROCESSOR TRIP UNITS - INSULATED CASE CIRCUIT BREAKERS2.07*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 X.

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

Each low voltage insulated case circuit breaker shall be equipped with a solid-state tripping A.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.

The trip unit shall have an information system that provides LEDs to indicate mode of trip B.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.

The trip unit shall be provided with a display panel, including a representation of the C.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.

The trip unit shall be provided with a making-current release circuit. The circuit shall be D.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.

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

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

All circuit breakers shall have adjustments for long delay pickup and time.1.*Main circuit breakers shall have individual adjustments for short delay pickup and time, 2.and include I2t settings.*Main circuit breakers shall have an adjustable instantaneous pickup.3.


SECTION 26 24 13.31

26 24 13.31-9 6/06

* Note to Spec. Writer – Select one* Note to Spec. Writer – Optional

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

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

The trip unit shall provide zone interlocking for the short-time delay and ground fault delay H.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.

The trip unit shall have an information system that utilizes battery backup LEDs to indicate I.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.

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

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

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

The trip unit shall include a power/relay module which shall supply control to the readout M.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.

The trip unit shall include a voltage transformer module, suitable for operation up to 600V, N.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.

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

Metering display accuracy of the complete system, including current sensors, auxiliary CTs, P.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.

The unit shall be capable of monitoring the following data:Q.Instantaneous value of phase, neutral and ground current1.Instantaneous value of line-to-line voltage2.Minimum and maximum current values3.Watts, VARs, VA, watt-hours, var-hours, and VA hours.4.

The energy-monitoring parameter values (peak demand, present demand, and energy R.consumption) shall be indicated in the trip unit’s alphanumeric display panel.


SECTION 26 24 13.31

26 24 13.31-10 6/06


The trip unit shall display the following power quality values: crest factor, power factor, S.percent total harmonic distortion, and harmonic values of all phases through the 31st harmonic.

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

The trip unit shall contain an integral test pushbutton. A keypad shall be provided to enable U.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.

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

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

Programmable long-time setting1.Programmable long-time delay with selectable I2T or I4T curve shaping2.Programmable short-time setting3.Programmable short-time delay with selectable flat or I2T curve shaping, and 4.

zone selective interlockingProgrammable instantaneous setting5.Programmable ground fault setting trip or ground fault setting alarm6.Programmable ground fault delay with selectable flat or I2T curve shaping and 7.

zone selective interlocking.

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

*The trip unit shall have the following advanced features integral to the trip unit:Y.Adjustable under voltage release1.Adjustable over voltage release2.Reverse load and fault current3.Reverse sequence voltage alarm4.Under frequency5.Over frequency6.Voltage phase unbalance and phase loss during current detection7.

MOLDED-CASE CIRCUIT BREAKERS – NON-CONTROLLED DISTRIBUTION BREAKERS 2.08

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

Circuit breakers shall be operated by a toggle-type handle and shall have a quick-make, B.quick-break over-center switching mechanism that is mechanically trip-free. Automatic


SECTION 26 24 13.31

26 24 13.31-11 6/06


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.

Circuit breakers shall have a minimum symmetrical interrupting capacity *[of (65,000) C.(100,000) (150,000) amperes symmetrical at rated voltage] [as shown on the drawings].

Circuit breakers *[250-] [400-] [600-] [800-] ampere frame and below shall be thermal-D.magnetic type trip units and inverse time-current characteristics.

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

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

*Where indicated circuit breakers shall be current limiting. G.

*Where indicated provide UL listed circuit breakers for applications at 100% of their H.continuous ampere rating in their intended enclosure.

MICROPROCESSOR TRIP UNITS – MOLDED-CASE DISTRIBUTION CIRCUIT BREAKERS 2.09

Each molded case circuit breaker microprocessor-based tripping system shall consist of A.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.

An adjustable trip setting dial mounted on the front of the trip unit, or interchangeable ratings B.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.

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

Adjustable long-time setting (set by adjusting the trip setting dial or rating plug) 1.Adjustable short-time setting and delay with selective curve shaping2.Adjustable instantaneous setting3.

*Adjustable ground fault setting and delay.4.

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

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


SECTION 26 24 13.31

26 24 13.31-12 6/06

* Note to Spec. Writer – Optional* Note to Spec. Writer – Select one

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

Breakers shall have built-in test points for testing the long-time delay, instantaneous, and G.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].

ACCESSORIES2.10

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

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

MISCELLANEOUS DEVICES2.11

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

Control power transformers with primary and secondary protection shall be provided, as B.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.]

*Each section of the switchboard shall be provided with a space heater *[thermostatically C.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.

ENCLOSURES2.12

NEMA 1 EnclosureA.

*Outdoor Walk-in EnclosureB.Switchgear shall be enclosed in an outdoor walk-in NEMA 3R enclosure 1.

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.

The enclosure shall be provided with rear hinged padlockable doors with wind 2.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.

Provide panic door hardware on aisle doors at each end of the line-up. External 3.padlocking of the aisle doors shall not prevent operation of the panic hardware from the


SECTION 26 24 13.31

26 24 13.31-13 6/06

* Note to Spec. Writer – Select One* Note to Spec. Writer – Optional

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.

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

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.

An overhead circuit breaker lifter shall be provided in the aisle of the enclosure.6.Each shipping section shall be shipped completely assembled.7.

*Outdoor Non-Walk-in EnclosureC.Switchgear shall be enclosed in an outdoor non-walk-in NEMA 3R enclosure 1.

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.

The enclosure shall be provided with front and rear hinged padlockable doors 2.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.

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

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

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.

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

Each shipping section shall be shipped completely assembled.7.

NAMEPLATES2.13

Engraved nameplates, mounted on the face of the assembly, shall be furnished for all main A.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.


SECTION 26 24 13.31

26 24 13.31-14 6/06


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

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

FINISH2.14

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

*TRANSIENT VOLTAGE SURGE SUPPRESSION2.15

Provide transient voltage surge suppression as specified in Section 26 43 13.A.

EMERGENCY POWER SYSTEM (EPS) AUTOMATION & CONTROLS 2.16

The automation and control system shall facilitate overall EPS operation including automatic A.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, and protective relaying.

The EPS Automation and Controls shall utilize true redundant, distributed processing B.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.

The EPS Automation and Controls shall be by the same manufacturer as the switchgear and C.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, depending on usage of PowerLynx 1000, PowerLynx 2000, and PowerLynx 3000 product

HMI – HUMAN/MACHINE INTERFACE [POWERLYNX 1000 HMI]2.17

EPS Automation interface shall be via a touchscreen with the following characteristics:A.Monochrome LCD display capable of displaying both text and graphics.1.

6” diagonal for EPS’s with one (1) Generator Set.a.10” diagonal for EPS’s with two (2) or more Generator Sets.b.

Resistive touchscreen interface.2.The display shall support a minimum resolution of 320x240 pixels in 6” diagonal size, a.black and white.The display shall support a minimum resolution of 640x480 pixels in 10” diagonal b.size, black and white.

Integral Alarm and Event Recording3.


SECTION 26 24 13.31

26 24 13.31-15 6/06

* Note to Spec. Writer – Select one* Note to Spec. Writer - Optional

-- *OR --


EPS Automation interface shall be via a touchscreen with the following characteristics:A.Color, 12” (diagonal) TFT LCD display capable of displaying both text and 1.

graphics.Resistive touch screen interface.a.The display shall support a minimum resolution of 800x600 pixels, 256 displayable b.colors.

Integral Alarm and Event Recording2.

-- *OR --


EPS system interface shall be via a touchscreen with the following characteristics:A.Color, 15 inch (diagonal) TFT LCD industrial display capable of displaying both 1.

text and graphics.The touch screen shall be clear glass, with light transmission of 95% or better, 2.

furnished with a Surface Acoustic Wave touch interface.The display shall support a minimum resolution of 1024 x 768 pixels, 16 million 3.

displayable colors, 24~60kHZ horizontal scan rate, 56-75kHZ refresh rate.An EPS Touch Screen Processor shall be provided and shall provide the 4.

following additional features:System Report Generationa.

The EPS Automation shall be capable of displaying and printing the 1.following reports:

System Settings Reporti.Generator Settings Reportii.Plant Test Report – including all current operational parametersiii.*[NFPA compliant JCAHO report]iv.Alarm Summary Reportv.

*Provide a printer for local printing of system reports.b.Integral Alarm and Event Recordingc.Integral Short Term Trendingd.Alarm Log shall be exportable to floppy disk drive.e.The EPS Touchscreen Processor shall operate with the following minimum f.characteristics:

Minimum environmental requirements: temperature 0-55 deg. C, 1.Protection Class IP20, Shock resistant up to 5Gs.

Industrial Processor shall have 24 Vdc power supply fed from best source 2.system.


SECTION 26 24 13.31

26 24 13.31-16 6/06

HMI SCREEN LISTING2.18

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

Main Menu Screen with a complete listing of major screens.1.System Overview Screen with a dynamic graphic display of the electrical one 2.

line.System Control Screen 3.System Metering Screen with graphical presentation of all functions.4.System Settings Screen.5.Generator Control Screen for each generator 6.Generator Metering Screen for each generator with graphical presentation of all 7.

functions specified.Generator Settings Screen.8.Generator Demand Priority Control and Status Screen.9.Generator Load Shed Control Screen.10.Engine Monitoring (Engine Meter/Gauge) Screen for each generator that shall 11.

contain a graphical representation of all of the engine gauges and data specifiedGenerator Engine Air / Cool Screen.a.Generator Engine Oil / Fuel Screen.b.

Utility Control Screen for each Utility Main.12.Utility Metering Screen that shall contain graphical representations of all the 13.

electrical metering functions specified.Utility Setting Screen that shall contain all of the adjustments specified.14.Annunciator Menu Screen15.

System Annunciation Screen that shall contain all of the Status, Lamp Test and a.Alarm points specified.Generator Annunciator Screen for each generator that shall contain: Status, Lamp b.Test, Pre-Alarms and Shutdown faults specified.Utility Annunciation Screen that shall contain all of the Status, Lamp Test and Alarm c.points specified.

Report Menu Screen16.Generator Settings Report Screena.Utility Settings Report Screenb.Plant Test Settings Report Screenc.

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 18.

Summary.

*Note to Spec. Writer:The additional HMI Screens listed below apply to PowerLynx 3000 only

System Trend Screen that shall contain trending information described below.19.


SECTION 26 24 13.31

26 24 13.31-17 6/06

* Note to Spec. Writer - Optional

Generator Trending Screen that shall contain trending information described 20.below.

*Engine Historical Trending Screen that shall contain trending information 21.described below under Long Term Historical Trending.

*Note to Spec. Writer: (for systems with Generator Bus Tie Breakers)The additional HMI Screens listed below apply to PowerLynx 2000 and 3000 only

*Tie Control Screen for each Utility Main.22.Tie Metering Screen that shall contain graphical representations of all the 23.

electrical metering functions specified.Tie Setting Screen that shall contain all of the adjustments specified.24.

EMERGENCY POWER SYSTEM (EPS) FEATURES 2.19

The EPS Automation and Controls shall consist of the hardware and software required for A.the control of the Engine-Generator plant and associated Utility, Tie, and Distribution Circuit Breakers. The System shall include all Processors, HMI (Human / Machine Interface) Touchscreens, Power Transducers, Supervisory Network and all ancillary control equipment necessary to automatically execute the specified Functional Sequence of Operations.

The EPS Automation shall be provided with an HMI consisting of a Touchscreen display.B.The HMI shall provide all metering, status, monitoring, and control information to 1.

the operator.The HMI shall serve only as an Operator Interface. The EPS must continue to 2.

function normally with a complete HMI failure.

The EPS Automation and Controls shall be designed to eliminate single points of failure.C.For redundancy, multiple automation processors shall be utilized. 1.At a minimum, the EPS Controls shall utilize a separate automation processor for 2.

each generator power source, each utility power source, and each HMI.Control systems utilizing a single automation processor are not acceptable.3.

For redundancy, all Master Control automation functions shall be capable of being executed D.from any of multiple distributed processors. If the automation processor executing Master Control automation functions should fail, the next available automation processor shall automatically assume control of all Master Control automation functions. The number of redundant processors for Master Control automation functions shall be equal to the number of generators in the system. The redundant automation processors shall each consist of a fully redundant power supply and CPU. Transfer of Master Control functions to a redundant processor shall be bumpless. The Master Control automation functions shall include:

Automatic start of the generator plant when a run request is received1.First-up and dead-bus control logic2.Automatic synchronizing and paralleling of the generator plant3.Automatic generator load and VAR sharing controls4.Automatic Generator Demand Priority control logic5.


SECTION 26 24 13.31

26 24 13.31-18 6/06


Automatic Load Shed / Add control logic6.

An I/O rack with I/O cards or a distributed I/O block shall be provided for all required Master E.Control I/O including Load Shed relay outputs, annunciation inputs and outputs, etc. *[A second (redundant) Master Control I/O rack with I/O cards (or a distributed I/O block) shall be provided with redundant I/O points for all Master Control I/O requirements.]

A separate Load Shed distributed I/O block shall be provided for each group of up to (7) F.electrically operated distribution circuit breakers (as indicated on the drawings) to control the opening and closing of distribution circuit breakers when signaled by the Master Control Automatic Load Shed Control Logic and to monitor the open and closed status of distribution circuit breakers. *[A second (redundant) Load Shed distributed I/O block shall be provided for each group of up to (7) distribution circuit breakers.]

Each Utility Circuit Breaker shall be provided with a separate primary automation processor G.and a redundant automation processor. The redundant automation processor shall consist of a fully redundant power supply, CPU and I/O point hardware. Failure of the primary utility automation processor shall result in a bumpless transfer to the redundant utility automation processor. For systems with tie breakers, the redundant utility automation processors shall also provide control of all tie breaker functions. The utility processor functions shall include:

Automatic sensing of loss and return of utility1.Automatic transfer between utility and generator source.2.Automatic synchronizing of generator source to utility source.3.Automatic control of the open and close signals to the utility or tie circuit 4.

breakers.

The EPS Automation and Controls shall be capable of surviving a fault of any one of its’ H.automation processors. The failure of any single Master Control, or Utility Circuit Breaker automation processor shall in no way hinder the full automatic operation of the entire EPS Automation and Control System. The failure of any single generator power source automation processor shall only cause loss of automatic operation of a single generator.

*Note to Spec. Writer:The following additional control network redundancy (Paragraph I) applies only to PowerLynx 2000 and 3000 Systems.

To eliminate single points of failure, the EPS automation processors shall coordinate their I.control functions via a dedicated fully redundant supervisory network. The redundant supervisory network shall have a 1Mbs data rate or higher and shall be configured so that failure of the primary network shall result in the system operating on the secondary network without any loss of manual or automatic functionality.

The EPS Automation control power shall be protected against single point of failure by the J.utilization of a 24Vdc, Best Source DC system.

Each Engine battery and a Station Battery shall be connected to a common DC 1.bus.

Each Engine battery and the Station Battery shall be furnished with a separate 2.battery charger.


SECTION 26 24 13.31

26 24 13.31-19 6/06

An 80 amp diode and 40 amp circuit breaker shall connect each battery to the 3.common DC bus to protect the common DC bus from the catastrophic failure of any DC source.

All controls and protective relays shall be powered from this Best Source DC bus.4.

The EPS Controls shall be provided with an “Instant Auto” Selector Switch. The Instant Auto K.Selector Switch shall shift the EPS to the fully automatic mode. This insures the EPS, even in the event of a touchscreen failure, can be returned to the fully automatic mode.

Each Generator, Utility, and Tie Circuit Breaker processor shall be furnished with a Power L.Transducer. The Power Transducer shall accept 3 phase Voltage and Current inputs from the associated source, and single phase Voltage input from the load side of the Circuit Breaker. The Power Transducer shall provide all critical power related data to the source processor at least once every 100ms.

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

Real Time TrendingN.The EPS Automation shall support real time trending. 1.Real Time Trending shall display the following:2.

Utility Average Voltagea.Utility Average Currentb.Utility kWc.Utility kVARd.

*Note to Spec. Writer: The following additional trending parameters apply to PowerLynx 3000 Systems only.

Load kWe.Individual Generator kWf.Individual Generator kVARg.Individual Generator Voltageh.Individual Generator Amps per phasei.Individual Generator frequencyj.Individual Engine RPMk.Individual Engine Battery Voltagel.Individual Engine Oil Pressurem.Individual Engine Water Temperaturen.

Each EPS Automation and Control component (nominal 24 Vdc) shall be rated to operate at O.40 Vdc (typical for open circuited 24 Vdc chargers). To eliminate single points of failure, external overvoltage protection components are not acceptable.

In the event of a failure of all EPS controls, the Generator frequency and voltage shall be P.automatically switched to manual, preset, potentiometer control.

EPS AUTOMATION & CONTROLS ENVIRONMENTAL SPECIFICATIONS2.20

The EPS Automation and Control System shall meet or exceed the following environmental A.requirements:


SECTION 26 24 13.31

26 24 13.31-20 6/06

Control Power – 16 to 40 Vdc (24 Vdc nominal)1.Operating Temperature – 0 - 55° C2.Humidity – 5 – 95% non-condensing3.

EPS METERING2.21

All metering functions shall be 0.5% accuracy or better. A.The following meters shall be provided for the system bus, each individual utility, 1.

tie, and generator:Voltmeter with 4-position selector switch to select three phases of voltage.a.Ammeter with 4-position selector switch.b.Kilowatt meterc.Kilovar meterd.Frequency Metere.Power Factor Meterf.Synchroscopeg.

The following additional metering shall be provided for each Engine:B.Engine RPM Meter1.Engine Battery Voltage Meter2.Engine Oil Pressure Gauge3.Engine Coolant Temperature Gauge4.Engine Running Hour Meter 5.Engine Start Counter 6.Percent Engine Load7.Local Control Switch Position8.

*Note to Spec. Writer:Include the following metering when using a Caterpillar, B series or higher, Diesel engine, with ADEM II or III.

Atmospheric Pressure 9.Boost Pressure 10.System Battery Voltage11.Left Turbo Inlet Pressure 12.Right Turbo Inlet Pressure 13.Engine Hour meter 14.Filtered Engine Oil Pressure 15.Engine Coolant Level Status 16.Overspeed Switch Status 17.Remote Emergency Stop Actuated status18.Oil Filter Pressure Differential 19.Fuel Filter Pressure Differential 20.


SECTION 26 24 13.31

26 24 13.31-21 6/06


Engine coolant Temperature 21.Right Exhaust Temperature 22.Left Exhaust Temperature 23.Crankcase Air Pressure 24.Filtered Fuel Pressure 25.Right Air Filter Differential 26.Left Air Filter Differential 27.Fuel Consumption Rate 28.

- *OR -

*Note to Spec. Writer:Include the following metering when using a Caterpillar, B series or higher, Natural Gas engine, with ADEM II or III.

Oil Filter Pressure Differential9.Gas Flow10.Total Engine Hours11.Unfiltered Oil Pressure12.Coolant Pressure13.Fuel Temperature14.Air/Fuel Ratio15.Inlet Air Pressure16.Inlet Air Temperature17.Inlet Air Flow18.Individual Cylinder Ignition Timing19.Individual Cylinder Temperature (where available)20.

*The following metering shall be provided for each distribution breaker:C.Voltmeter with 4-position selector switch to select three phases of voltage.1.Ammeter with 4-position selector switch.2.Kilowatt meter3.Kilovar meter4.Frequency Meter5.Power Factor Meter6.

*Additional MeteringD.Where indicated on the drawings, provide a separate customer metering 1.

compartment with front hinged door.Furnish and install current transformers for each meter. Current transformers 2.

shall be wired to shorting-type terminal blocks.


SECTION 26 24 13.31

26 24 13.31-22 6/06

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

Note to Spec. Writer:See Section 26 27 13.11 Microprocessor Based Metering for functional descriptions.

PROTECTIVE RELAYS2.22

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

Protective Relaying shall be microprocessor, high reliability, as specified below.B.

GENERATOR PROTECTIVE RELAYINGC.As a minimum, the following protective functions shall be provided for each 1.

Generator:Under/Over Voltage (27/59) Relay, 3-phase, percent adjustable, percent reset, with a.time delay.Over/Under Frequency (81 O/U) Relay, single phase, percent adjustable, percent b.reset, with time delay.Reverse Power (32) Relay, 3-phase, percent adjustable with time delay.c.Loss of Field (Reverse VAR, 40) Relay, 3-phase, percent adjustable with time delay.d.Microprocessor Engine Governor Load Sharing and Soft Loading Control (65). e.Automatic Synchronizer (15/25), adjustable sync window and sync window dwell f.time.Manual Paralleling Synch Check (25).g.Var/Power Factor Controller (90 PF).h.

UTILITY PROTECTIVE RELAYINGD.As a minimum, the following protective functions shall be provided for each Utility 1.

Point of Common Coupling (PCC) Under/Over Voltage (27/59) Relay, 3-phase, percent adjustable, percent reset, with a.time delay.Over/Under Frequency (81 O/U) Relay, single phase, percent adjustable, percent b.reset, with time delay.Phase Sequence/Phase Failure (47) Relay (Utility Grade), 3-phase, percent c.adjustable, with time delayReverse Power (32) Relay, 3-phase, percent adjustable with time delay.d.Reverse Direction Overcurrent (32/51) Relay (Utility Grade), 3-phase, percent e.adjustable, with time delay.Utility Lock-out (86) Relay (Utility Grade), manual reset.f.Utility Re-close Lock-out Switch with lockable cover.g.Manual Paralleling Synch Check Relay (25), Industrial Gradeh.Automatic Synchronizer (15/25), adjustable sync window and sync window dwell i.time.Manual Paralleling Synch Check (25).j.


SECTION 26 24 13.31

26 24 13.31-23 6/06

* Note to Spec. Writer – Select one* Note to Spec. Writer – Select one

-- *OR --Each Utility Circuit Breaker shall be provided with a *[Multilin SR-750] [Schweitzer 1.

SEL 351S] [Basler BE1-951] [Basler IPS-100], drawout, utility grade, multi-function protective relay.

TIE PROTECTIVE RELAYING (Where applicable)E.As a minimum, the following protective function shall be provided for each 1.

Distribution Circuit Breaker:Instantaneous/Time Overcurrent (50/51) Relay, 3-phase, percent adjustable, utilizing a.ANSI trip curves.Lock-out (86) Relay (Utility Grade), manual reset.b.Two - Manual Paralleling Synch Check Relay (25), Industrial Grade.c.

-- *OR --Each Tie Circuit Breaker shall be provided with a *[Multilin MIF II] [Schweitzer 1.

SEL 551] [Basler BE1-851] [Siemens 7SJ602], utility grade, multi-function, protective relay.

Lock-out (86) Relay (Utility Grade), manual reset.a.Two - Manual Paralleling Synch Check Relay (25), Industrial Grade.b.

DISTRIBUTION PROTECTIVE RELAYINGF.As a minimum, the following protective function shall be provided for each 1.

Distribution Circuit Breaker:Instantaneous/Time Overcurrent (50/51) Relay, 3-phase, percent adjustable, utilizing a.ANSI trip curves.Lock-out (86) Relay (Utility Grade), manual reset.b.

-- *OR --Each Distribution Circuit Breaker shall be provided with a *[Multilin MIF II] [Schweitzer a.SEL 551] [Basler BE1-851] [Siemens 7SJ602], utility grade, multi-function, protective relay.Lock-out (86) Relay (Utility Grade), manual reset.b.

EPS ANNUNCIATION SYSTEM2.23

The EPS shall be provided with Annunciators to monitor and display critical status, fault, and A.shutdown information. Two (2) distinct Annunciator types shall be provided:

Generator Annunciator – One (1) shall be provided for each generator.1.System Annunciator – One (1) shall be provided for each system.2.

Annunciation shall comply with NFPA 110 requirements and shall conform to Instrument B.Society of America (ISA) F3A standards. The Annunciation System shall be provided with five (5) distinct types of annunciation points:

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


SECTION 26 24 13.31

26 24 13.31-24 6/06

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

Generator Shutdown Alarm Points - These annunciation points shall show fault 3.conditions that have caused the shutdown of one (1) or more generator sets. Generator Shutdown Annunciation points shall sound the Annunciation System Horn. They shall require acknowledgement. Generator 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 operation.

Utility Alarm Points – These annunciation points will indicate Utility related fault 4.conditions. Utility Annunciation points shall sound the Annunciation System Horn. They shall require acknowledgement.

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

The Annunciation System shall be equipped with a fast pulse horn (rated 80-95 dbA at two C.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. One press of the Acknowledge button shall return alarm points to “steady on” except the “first in” alarm, which shall remain flashing. A second press of the Acknowledge button shall return the “first in” alarm point to “steady on”.

The following Annunciator Points shall be furnished for each generator set:D.Status Annunciation Points1.

Local Engine Control Switch Positiona.EPS Engine Control Switch Positionb.EPS Synchronization Selector Switch Positionc.Emergency Mode d.Generator Circuit Breaker Open/Closed e.Engine Running/Stoppedf.

Pre-Alarm Annunciation Points2.High Coolant Temperaturea.Low Oil Pressureb.Low Coolant Temperaturec.Engine Battery Low Voltage d.Engine Battery High Voltage e.Battery Charger Failure f.Engine Low Fuel [Applies to Diesel only]g.Generator Failed to Synchronizeh.Local Engine Control Switch not in Autoi.


SECTION 26 24 13.31

26 24 13.31-25 6/06

EPS Engine Control Switch not in Autoj.EPS Synchronization Selector Switch not in Autok.Ground Fault Alarml.Communications Module Alarmm.Rupture Basin Alarm [Applies to Diesel only]n.Synchronizer Block Faulto.Low Controller Batteryp.

Shutdown Alarm Points3.Engine Overcrank a.Engine Overspeed b.Engine Low Oil Pressure c.Engine High Coolant Temp d.Engine Low Coolant Level e.Engine Remote Emergency Shutdown f.Generator Circuit Breaker Trippedg.Generator Loss of Field h.Generator Reverse Power i.Generator Undervoltage j.Generator Over voltage k.Generator Under frequency l.Generator Over frequency m.Emergency Stopn.Ground Faulto.Critical Low Fuel Shutdown [Applies to Diesel only]p.Hi Winding Temperature Tripq.

The following Annunciator Points shall be furnished for each Utility:E.Status Annunciation Points1.

EPS Synchronization Selector Switch Positiona.Emergency Modeb.Utility Close Lock-out Switch Positionc.Utility Circuit Breaker Open/Closedd.

Utility Alarm Points2.Utility Failurea.Utility Control not in Autob.Utility Circuit Breaker Reverse Powerc.Utility Fail to Synchronized.Utility Circuit Breaker Failed to Close/Opene.Utility Circuit Breaker Trippedf.Utility Protective Relay Failureg.

The following Annunciator Points shall be furnished for each EPS:F.Status Annunciation Points1.

Engine Status (1 for each Engine)a.


SECTION 26 24 13.31

26 24 13.31-26 6/06


Engine Priority (1 for each Engine)b.Master Mode Selector Switch positionc.EPS Test Switch Positiond.Load Shed Enablede.Load Shed Active f.Load Shed Override g.Gen Demand Priority Enabled h.Gen Demand Priority Activei.

EPS Alarm Points2.System in Emergency Modea.System not in Autob.Load Shed Overridec.Generator Bus Underfrequencyd.Master Shutdowne.Controller Faultf.Low Controller Batteryg.System Battery Charger Faulth.

EPS (CONTROL, SYNCHRONIZER, POWER TRANSDUCER AND PROTECTIVE) SETTINGS2.24

EPS Setting changes and adjustments shall be password protected and easily adjustable in A.selectable increments.

System Settings1.Generator Settings2.Generator Demand and Load Shed Settings3.Utility Settings4.

FUNCTIONAL SEQUENCE OF OPERATIONS2.25

The EPS Automation shall be provided with the following Modes of Operation:A.Automatic/Standby Mode1.

The utility main breaker is closed serving utility power to the generator/load bus.a.The generator main breakers are open.b.The automation is standing by to act in response to a utility failure.c.

Emergency Mode2.Utility Failurea.

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

The utility main breaker is opened.2.A run request is sent to the generator plant.3.The first generator up to voltage and frequency is closed to the bus.4.

*[ With Generator Bus Tie Breaker] The generator bus tie breaker is closed.5.


SECTION 26 24 13.31

26 24 13.31-27 6/06


The remaining generators are synchronized and paralleled to the bus as 6.they come up to voltage and frequency.

The system is now in Emergency Mode.7.Utility Restoration and Exit from Emergency Modeb.

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

Following an adjustable time delay (which can be abbreviated by the 2.operator) to assure that the utility power source is stable, the generator plant is passively synchronized and paralleled to the utility source by closing the utility main breaker.

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

The generator breakers are opened.4.The generators are allowed to run for their programmed cool down period.5.The system is now back in Automatic/Standby Mode.6.

Transfer to Emergency Mode3.Entrya.

The operator places the System Mode Selector Switch into the Closed 1.Xfer to Emergency position.

A run request is sent to the generator plant.2.The first generator up to voltage and frequency is paralleled to the bus at 3.

no load.The remaining generators are synchronized and paralleled to the bus at 4.

no load as they come up to voltage and frequency.When all generators are on the bus they are soft ramp loaded until the 5.

generator plant is serving nominally the entire load on the bus and the utility main breaker is opened.

-- *OR --[With Generator Bus Tie Breaker] When all generators are on the bus, 5.

they are paralleled across the generator bus tie breaker. They are then soft ramp loaded until the generator plant is serving all of the load on the bus and the utility main is opened.

The system is now running in Emergency Mode.6.Exit from Emergency Modeb.

The operator removes the System Mode Selector Switch from Transfer to 1.Emergency position and returns it to the Auto position.

Following an adjustable time delay (which can be abbreviated by the 2.operator), the generator plant is passively synchronized and paralleled to the utility source by closing the utility main breaker.

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

The generator breakers are opened.4.

-- *OR --


SECTION 26 24 13.31

26 24 13.31-28 6/06

[With Generator Bus Tie Breaker] The generator bus tie breaker is 4.opened and then all of generator breakers are opened.

The generators are allowed to run for their programmed cool down period.5.The system is now back in Automatic/Standby Mode.6.

Load Management Mode4.Entrya.

Select one of the modes of operation:1.Import Limit - The user places the Import/Export toggle switch in the Import i.position and places the Base Load/Utility Tracking toggle switch in the Utility Tracking position. The user sets the Utility Import Set point to the desired amount of kW that they want to import through the Utility Circuit Breaker during Load Management Mode.Export Limit - The user places the Import/Export toggle switch in the Export ii.position and places the Base Load/Utility Tracking toggle switch in the Utility Tracking position. The user sets the Utility Export Set point to the desired amount of kW that they want to export through the Utility Circuit Breaker during Load Management Mode.Base Load Import - The user places the Import/Export toggle switch in the iii.Import position and places the Base Load/Utility Tracking toggle switch in the Base Load position. The user sets the Base Load Set point to the desired amount of kW that they want the generator plant to assume during Load Management Mode. The controls shall not allow the generator plant to export kW through the Utility Circuit Breaker and shall always maintain a nominal amount of Utility kW imported through the Utility Circuit Breaker.Base Load Export - The user places the Import/Export toggle switch in the iv.Export position and places the Base Load/Utility Tracking toggle switch in the Base Load position. The user sets the Base Load Set point to the desired amount of kW that they want the generator plant to assume during Load Management Mode. The controls shall allow the generator plant to export kW through the Utility Circuit Breaker.

The user places the System Mode Selector Switch in the Load 2.Management position.

A run request is sent to the generator plant.3.The generators are allowed to run for a five-minute warm-up time (which 4.

can be abbreviated by the operator).The generators are synchronized and paralleled to the bus at no load 5.

after completion of the warm-up time.When all generators are on the bus they are soft ramp loaded until the 6.

generator plant is serving nominally the required amount of the load on the bus to meet the mode of operation selected.

The generator output is dynamically adjusted to maintain the set point to 7.meet the mode of operation selected. If at any time the system is unable to maintain the setpoint then a “Set point Exceeded” alarm shall be sounded.

Should the utility fail at any time during Load Management operation, the 8.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).


SECTION 26 24 13.31

26 24 13.31-29 6/06

Exitb.The operator removes the System Mode Selector Switch from Load 1.

Management position and returns it to the Auto position.The generator plant is soft ramp unloaded until the utility source is 2.

nominally serving the entire system load and the generator main breakers are opened.

The generators are allowed to run for their programmed cool down period.3.The system is now back in Automatic/Standby Mode.4.

No Load Test Mode5.Entrance into No Load Test Modea.

The No Load Test Switch is placed in the ON position.1.All available generators are started.2.All generators come up to voltage and frequency and remain running 3.

disconnected from the bus.The system is now in No Load Test Mode.4.

Exit from No Load Test Modeb.The No Load Test Switch is placed in the OFF position.1.The generators are allowed to run for their programmed cool down period.2.The system is now back in Automatic/Standby Mode.3.

Utility Fail Test Mode6.Entrance into Utility Fail Test Modea.

The Utility Fail Test Switch is placed in the ON position.1.Voltage sensing at the utility protective relay is opened, which simulates a 2.

loss of utility.The system enters into Emergency Mode as described in the “Emergency 3.

Mode” sequence above.Exit from Utility Fail Test Modeb.

The Utility Fail Test Switch is placed in the OFF position.1.Voltage sensing at the utility protective relay is restored, which simulates 2.

the return of utility power.The system exits from Emergency Mode as described in the “Emergency 3.

Mode” sequence above.

When the Generator Sets are carrying the facility load, the EPS Automation shall support B.two (2) sub-modes: Load Shed/Load Add, and Generator Demand Priority.

Load Shed Control1.The System Controls shall include a Load Shed Control function to control the loads a.served by the generator plant. The Load Shed Control shall have one Essential Load Shed Priority Level for each b.generator in the system plus one Non-Essential Load Shed Priority Level (which is always shed in the Emergency Mode of operation). The Load Shed Control shall control each of the distribution circuit breakers that are c.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.


SECTION 26 24 13.31

26 24 13.31-30 6/06

Provide the following controls for each Essential Load Shed Priority Level1.Shed Delay Timer, adjustable from 0 to 1024 secondsi.Add Delay Timer, adjustable from 0 to 1024 secondsii.Load Shed Override Selector (shed/auto//add)iii.Status indicators to show whether the Priority Level is Added or Shediv.

Provide the following controls for each Non-Essential Load Shed Priority2.Load Shed Override Selector (shed/auto//add)i.Status indicators to show whether the Priority Level is Added or Shedii.

Additionally, the Load Shed Controls shall have:3.Load Shed Control Switch (On/Off)i.User-settable Load Shed % (as a function of on-line generator capacity)ii.User-settable Load Shed Time Delayiii.User-settable Load Add % (as a function of on-line generator capacity)iv.User-settable Load Add Time Delayv.User-settable Bus Under frequency Set pointvi.User-settable Bus Under frequency time delayvii.Bus Under frequency Reset Pushbuttonviii.Bus Under frequency indicatorix.Conditional Load Shed: Upon entrance into Emergency Mode of 4.

operation, the Load Shed Control shall shed all Essential and Non-Essential loads. As generators come to the bus, Essential Priority Level loads shall be added conditionally based on the number of generators on line. When the first generator comes to the bus, Priority Level 1 loads shall be added; Second generator, priority 2, etc. After a time delay that allows all operational generators to come to the bus, Load Shed Mode shall shift to Load Sensitive Mode.

Load Sensitive Load Shed – After all generators have been given 5.sufficient time to come to the bus, load shed shall shift to “Load Sensitive” mode. The system shall compare current generator on-line capacity (in kW) to current load requirements. If surplus capacity is greater than the calculated Load Add setpoint, after the Load Add Time Delay the next Load Shed Priority shall be added. This calculation shall continue until all Sheddable Loads are added, or until surplus capacity is less than the calculated Load Add setpoint. If surplus capacity is less than the calculated Load Shed setpoint, after the Load Shed Time Delay the next Load Shed Priority shall be shed. This calculation shall continue until all Sheddable Loads are shed, or until surplus capacity is greater than the calculated Load Shed setpoint. The Load Shed Control, in its automatic shedding and adding of loads, shall not override any manual load shed/add operation.

Should the load bus frequency fall below the user selected bus 6.underfrequency setpoint for a period longer than the bus underfrequency time delay, then all Priority Level loads shall be shed and load addition shall not resume until the operator has depressed the Bus Underfrequency Reset button. The bus underfrequency protection shall override any manual load add operation.


SECTION 26 24 13.31

26 24 13.31-31 6/06


Note to Spec. Writer:The following on applies to systems with two or more generators

Generator Demand Priority Control2.The System Controls shall include a Generator Demand Priority Control function to a.automatically match the on-line generator capacity to the loads to avoid unnecessary operation of all the generators when the loads are low. The following controls shall be provided for each generator:b.

User-settable Generator Priority Selector1.Status indicator for the Generator Priority Selected2.Status indicator for generator On-line or Off-line3.

The Generator Demand Priority Control shall have the following controls:c.Generator Demand Priority Control Switch (On/Off)1.User-settable Generator Remove % (as a function of a single generator 2.

capacity)User-settable Generator Remove Delay3.User-settable Generator Add % (as a function of a single generator 4.

capacity)User-settable Generator Add Delay5.

Upon entrance into Emergency or Load Management modes, all generators shall be d.started and paralleled to the bus. After the Remove Time Delay, generators shall be removed from the bus as a function of the generator percentage loading by the user selected Generator Remove time delay. Generators shall be removed from the bus in descending priority. Should the generator percentage loading increase to the user selected Generator Add limits for the user selected Add Delay, the next generator shall be started, synchronized and paralleled to the bus. Generators shall be added to the bus in ascending priority order. Should the generator plant ever reach 95% loading, the next priority generator shall be started and added to the bus with no time delay.

SPARE PARTS2.26

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

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

*At a minimum, provide the following spare parts for the Generator Control Switchboard:C.One of each type of automation processor (including CPU, Power Supply, and 1.

I/O)One of each component required for synchronization, load control, and VAR 2.

controlOne of each control relay3.(10) of each control fuse4.One of each power transducer5.


SECTION 26 24 13.31

26 24 13.31-32 6/06

Note to Spec. Writer:The following options apply to PowerLynx 3000 products only.

*LONG TERM HISTORICAL TRENDING 2.27

Long Term Historical Trending shall log EPS historical data on the system hard drive. This A.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. Long Term Historical Trending shall record and display the following for each Generator set:

Battery Volts1.Coolant Temperature2.Coolant Level Status3.Engine RPM4.Fuel Pressure5.Fuel Usage Rate6.Engine Hour Meter7.kW8.kVAR9.Average 3 phase Current10.Average 3 phase Voltage11.Local Engine Control Switch Position12.Local E-stop Position13.Alarm Status14.Pre-Alarm Status15.

*Note to Spec. Writer:The following Trending information is available when using a Caterpillar, B series or higher, Diesel engine, with ADEM II or III.

Total Fuel Used16.Fuel Filter Differential Pressure17.Oil Pressure18.Oil Filter Differential Pressure19.Right Air Filter Differential Pressure20.Right Turbo Pressure21.Left Turbo Pressure22.Boost Pressure23.Percent Engine Load24.

*Note to Spec. Writer:The following Trending information is available when using a Caterpillar, B series or higher, Natural Gas engine, with ADEM II or III.

Oil Pressure Differential25.


SECTION 26 24 13.31

26 24 13.31-33 6/06


Gas Flow26.Total Engine Hours27.Unfiltered Oil Pressure28.Coolant Pressure29.Fuel Temperature30.Air/Fuel Ratio31.Inlet Air Pressure32.Inlet Air Temperature33.Inlet Air Flow34.Individual Cylinder Temperature (where available)35.

*REMOTE NOTIFICATION2.28

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

Voice notification via cell phone or land lines.1.Fax notification2.Pager notification3.Email notification4.

*REMOTE ANNUNCIATION2.29

An NFPA compliant remote annunciator shall be provided by the EPSS.A.

*EPS SITE MONITORING2.30

The EPS shall be provided with web-based site monitoring services. This service shall be A.capable of monitoring and controlling multiple EPS sites, with no geographical limitation. Web-based EPS access shall employ high security to insure against unauthorized EPS access.

This monitoring service shall be Caterpillar PointGuard or equal.B.

The site monitoring service shall support the following means of communications:C.Cellular Telephone1.Landline Telephone2.Satellite Communications3.Virtual Private Network4.Cable Modem5.Frame Relay6.

Available services for the EPS shall include:D.Continuous monitoring for alarms1.


SECTION 26 24 13.31

26 24 13.31-34 6/06

* Note to Spec. Writer – Select one* Note to Spec. Writer – Select one* Note to Spec. Writer - Optional

Automated alarm notification2.Data gathering and management3.Report Generation4.Site Control5.

*Note to Spec. Writer:The following options apply to all PowerLynx products.

*REMOTE POWER MONITORING SYSTEM 2.31

A PC based Remote Power *[Monitoring][Monitoring and Control] System shall be provided A.to monitor breaker status, alarms, metering and other operating parameters. All *[control functions, displays metering][displays, metering] and other information described previously in these specifications shall be available to the operator of the Remote System.

The Remote System shall be designed such that its operation shall not in any way impede B.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.

The Remote System shall provide the identical screens and resolution at the Remote Screen C.as seen at the Switchgear HMI as noted above.

The Remote System shall communicate with the System Control via high speed network.D.

A PC workstation shall be provided by *[owner] [EPSS] for the Remote Power System with E.the following minimum features:

Intel Pentium CPU operating at 2 GHz1.256 MB RAM2.20 GB Hard Drive3.3.5 inch Floppy Disk Drive4.19 inch LCD SVGA Color Monitor5.Keyboard and Microsoft Mouse6.56Kbps modem7.Network Interface Card8.Windows 2000 or Windows NT 9.Printers10.

Laser printer for historical reportsa.Line printer for alarm and event reports/logsb.

*BUILDING MANAGEMENT SYSTEM INTERFACE2.32

The system shall allow interface from the user’s Building Management System.A.


SECTION 26 24 13.31

26 24 13.31-35 6/06


The interface shall be designed such that the Building Management System or external user B.interface shall in no way compromise the integrity or interfere with the critical operations of the EPS Control System.

Interface to the user’s Building Management System shall be via [RS-232] [RS-485] C.[Ethernet] communications, utilizing [MODBUS RTU] [MODBUS/TCP] Protocol.

EXECUTIONPART 3

FACTORY TESTING3.01

The switchboard shall be completely and functionally tested in the manufacturer's facility A.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.

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

The switchboard shall be completely assembled, wired, adjusted, and tested at 1.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.

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

*Factory tests as outlined above shall be witnessed by the owner’s representative.C.The manufacturer shall notify the owner two (2) weeks prior to the date the tests 1.

are to be performed.The manufacturer shall include the cost of transportation and lodging for up to 2.

three (3) owner’s representatives. The cost of meals and incidental expenses shall be the owner’s responsibility.

INSTALLATION3.02

Store equipment in a clean, dry place. Protect from weather, dirt, fumes, water, construction A.debris, and physical damage.

The Contractors shall install all equipment per the manufacturer’s instructions, contract B.drawings and National Electrical Code.

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

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


SECTION 26 24 13.31

26 24 13.31-36 6/06

* Note to Spec. Writer – Select one* Note to Spec. Writer – Insert data in blanks

Checking to ensure that all bus bars are torqued to the manufacturer’s 2.recommendations.

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

Securing assemblies to foundation or floor channels.4.Measuring and recording Megger readings phase-to-phase, phase-to-ground, 5.

and neutral-to-ground (four wire systems only).Inspecting and installing all circuit breakers in their proper compartments.6.

The assembly shall be provided with adequate lifting means and shall be capable of being D.moved into installation position and bolted directly to *[Contractor supplied floor sills to be set level in concrete per manufacturer’s 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.

FIELD QUALITY CONTROL AND STARTUP3.03

Provide the services of a qualified factory-trained manufacturer’s representative for start-up A.of the equipment specified under this section for a period of *____ working days. The manufacturer’s 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.

The manufacturer’s representative shall provide inspection of the final installation. The B.manufacturer’s representative shall perform site start-up and functional checkout of the Switchboard.

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

and switchboard/switchgear.Crank and run engine/generators at the local engine control panel.2.Crank and run engine/generators from the HMI touchscreen.3.Verify engine/generator alarms and shutdowns to HMI.4.Verify protective relay/breaker trip units are set to coordination study if applicable.5.Test all modes of operation.6.Verify and test all system alarms to HMI.7.Test with EPS with Load.8.The Contractor shall provide three (3) copies of the manufacturer’s field start-up 9.

report.

TRAINING3.04


SECTION 26 24 13.31

26 24 13.31-37 6/06

The Contractor shall provide a training session for up to five (5) owner’s representatives for ***____ normal workdays at a jobsite location determined by the owner.

Upon successful completion of a demonstration of the automated sequences of operation by B.the manufacturer and acceptance by the customer, the manufacturer shall provide an eight-hour "hands-on" training course for the customer's operating personnel which shall cover the following topics:

Overall System Description and Theory of Operation1.Automatic Operation2.Manual Operation3.Safeties and Protective Relaying4.Recommended System Check Lists and Log Sheets5.Recommended Preventive Maintenance6.

The training session shall be conducted by a manufacturer’s qualified representative. The C.training program shall also include instruction on the operation of the assembly, circuit breakers, and major components within the assembly.

FIELD ADJUSTMENTS3.05

The relays shall be set in the field by a qualified representative of the Emergency Power A.System Supplier, retained by the Contractor, in accordance with settings designated in a coordinated study of the system as required elsewhere in the contract documents.

The Contractor shall perform field adjustments of the protective devices as required to place B.the equipment in final operating condition. The settings shall be in accordance with the approved short-circuit study, protective device evaluation study and protective device coordination study.

Necessary field settings of devices and adjustments and minor modifications to equipment to C.accomplish conformance with an approved short circuit and protective device coordination study shall be carried out by the Contractor at no additional cost to the owner.