369 Motor Management Relay Instruction Manual

The 369 Motor Management Relay is a digital relay that provides protection and monitoring for three phase motors and

their associated mechanical systems. A unique feature of the 369 is its ability to ‘learn’ individual motor parameters and to

adapt itself to each application. Values such as motor inrush current, cooling rates and acceleration time may be used to

improve the 369’s protective capabilities.

The 369 offers optimum motor protection where other relays cannot, by using the FlexCurve™ custom overload curve, or

one of the fifteen standard curves.

The 369 has one RS232 front panel port and three RS485 rear ports. The Modbus RTU protocol is standard to all ports.

Setpoints can be entered via the front keypad or by using the 369PC software and a computer. Status, actual values and

troubleshooting information are also available via the front panel display or via communications. A simulation mode and

pickup indicator allow testing and verification of correct operation without requiring a relay test set.

As an option, the 369 can individually monitor up to 12 RTDs. These can be from the stator, bearings, ambient or driven

equipment. The type of RTD used is software selectable. Optionally available as an accessory is the remote RTD module

which can be linked to the 369 via a fibre optic or RS485 connection.

The optional metering package provides VT inputs for voltage and power elements. It also provides metering of V, kW, kvar,

kVA, PF, Hz, and MWhrs. Three additional user configurable analog outputs are included with this option along with one

analog output included as part of the base unit.

The Back-Spin Detection (B) option enables the 369 to detect the flow reversal of a pump motor and enable timely and safe

motor restarting. 369 options are available when ordering the relay or as upgrades to the relay in the field. Field upgrades

are via an option enabling passcode available from GE Power Management, which is unique to each relay

Motor protection and management shall be provided by a digital relay. Protective functions shall include:

• phase overload standard curves (51)

• overload by custom programmable curve (51)

• I2t modeling (49)

• current unbalance / single phase detection (46)

• starts per hour and time between starts

• short circuit (50)

• ground fault (50G/50N 51G/51N)

• mechanical jam / stall

Optional functions shall include:

• under / overvoltage (27/59)

• phase reversal (47)

• underpower (37)

• power factor (55)

• stator / bearing overtemperature with twelve (12) independent

RTD inputs (49/38)

• backspin detection

Management functions shall include:

• statistical data

• pre-trip data (last 40 events)

• ability to learn, display and integrate critical parameters

to maximize motor protection

• a keypad with 40 character display

• flash memory

The relay shall be capable of displaying important metering functions, including phase voltages, kilowatts, kvars, power factor,

frequency and MWhr. In addition, undervoltage and low power factor alarm and trip levels shall be field programmable.

The communications interface shall include one front RS232 port and three independent rear RS485 ports with supporting

PC software, thus allowing easy setpoint programming, local retrieval of information and flexibility in communication with

SCADA and engineering workstations.

55 LAG POWER FACTOR

Pickup Level: 0.99 to 0.05 in steps of 0.01

Pickup Accuracy: ±0.02

Dropout Level: 0.01 of pickup

Time Delay: 0.1 to 255.0 s in steps of 0.1

Start Delay: 0 to 5000 s in steps of 1

Timing Accuracy: ±300 ms or ±0.5% of total trip time

POSITIVE REACTIVE POWER

Pickup Level: 1 to 25000 in steps of 1

Pickup Accuracy: ±2%

Dropout Level: 96 to 98% of pickup

Time Delay: 0.1 to 255.0 s in steps of 0.1

Start Delay: 0 to 5000 s in steps of 1

Timing Accuracy: ±300 ms or ±0.5% of total trip time

NEGATIVE REACTIVE POWER

Pickup Level: 1 to 25000 kvar in steps of 1

Pickup Accuracy: ±2%

Dropout Level: 96 to 98% of pickup

Time Delay: 0.1 to 255.0 s in steps of 0.1

Start Delay: 0 to 5000 s in steps of 1

Timing Accuracy: ±300 ms or ±0.5% of total trip time

37 UNDERPOWER

Pickup Level: 1 to 25000 kW in steps of 1

Pickup Accuracy: ±2%

Dropout Level: 102 to 104% of pickup

Time Delay: 0.1 to 255.0 s in steps of 0.1

Start Delay: 0 to 15000 s in steps of 1

Timing Accuracy: ±300 ms or ±0.5% of total trip time

REVERSE POWER

Pickup Level: 1 to 25000 kW in steps of 1

Pickup Accuracy: ±2%

Dropout Level: 102 to 104% of pickup

Time Delay: 0.2 to 30.0 s in steps of 0.1

Start Delay: 0 to 50000 s in steps of 1

Timing Accuracy: ±300 ms or ±0.5% of total trip time

87 DIFFERENTIAL SWITCH

Time Delay: <200 ms

14 SPEED SWITCH

Time Delay: 0.5 to 100.0 s in steps of 0.5

Timing Accuracy: ±200 ms or ±0.5% of total trip time

GENERAL SWITCH

Time Delay: 0.1 to 5000.0 s in steps of 0.1

Start Delay: 0 to 5000 s in steps of 1

Timing Accuracy: ±200 ms or ±0.5% of total trip time

DIGITAL COUNTER

Pickup: on count equaling level

Time Delay: <200 ms

BACKSPIN DETECTION

Dynamic BSD: 20 mV to 480 V RMS

Pickup Level: 3 to 300 Hz in steps of 1

Dropout Level: 2 to 30 Hz in steps or 1

Level Accuracy: ±0.02 Hz

Timing Accuracy: ±500 ms or ±0.5% of total trip time

The 369 can be connected to cover a broad range of applications and wiring will vary depending upon the user’s protection

scheme. This section will cover most of the typical 369 interconnections.

In this section, the terminals have been logically grouped together for explanatory purposes. A typical wiring diagram for

the 369 is shown above in Figure 3–4: TYPICAL WIRING on page 3–6 and the terminal arrangement has been detailed in

Figure 3–3: TERMINAL LAYOUT on page 3–5. For further information on applications not covered here, refer to Chapter 7:

APPLICATIONS or contact the factory for further information.

Hazard may result if the product is not used for intended purposes. This equipment can only be serviced

by trained personnel.

The 369 has a built-in switchmode supply. It can operate with either AC or DC voltage applied to it.

Extensive filtering and transient protection has been incorporated into the 369 to ensure reliable operation in harsh industrial

environments. Transient energy is removed from the relay and conducted to ground via the ground terminal. This terminal

must be connected to the cubicle ground bus using a 10 AWG wire or a ground braid. Do not daisy-chain grounds with

other relays or devices. Each should have its own connection to the ground bus.

The internal supply is protected via a 3.15 A slo-blo fuse that is accessible for replacement. If it must be replaced ensure

that it is replaced with a fuse of equal size (see FUSE on page 2–4).

The 369 requires one CT for each of the three motor phase currents to be input into the relay. There are no internal ground

connections for the CT inputs. Refer to Chapter 7: APPLICATIONS for a information on two CT connections.

The phase CTs should be chosen such that the FLA of the motor being protected is no less than 50% of the rated CT primary.

Ideally, to ensure maximum accuracy and resolution, the CTs should be chosen such that the FLA is 100% of CT primary

or slightly less. The maximum CT primary is 5000 A.

The 369 will measure 0.05 to 20 ´ CT primary rated current. The CTs chosen must be capable of driving the 369 burden

(see specifications) during normal and fault conditions to ensure correct operation. See Section 7.4: CT SPECIFICATION

AND SELECTION on page 7–7 for information on calculating total burden and CT rating.

For the correct operation of many protective elements, the phase sequence and CT polarity is critical. Ensure that the convention

illustrated in Figure 3–4: TYPICAL WIRING on page 3–6 is followed