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Installation

The FGD-2 is typically preinstalled in an excitation control system.

If replacement is necessary, carefully label and document each of the

connections to the FGD-2 in order to properly reconnect the new module.

FGD-2 connectors and indicators are illustrated in Figure 1. Locator

letters in Figure 1 correspond to the lettered descriptions in Table 1.

When a replacement FGD-2 is installed in a DECS-2100 or ECS2100

system, the system calibration values may need to be updated.

Retrofitting an FGD

Although the FGD-2 is smaller in size than the FGD, it may still be mounted

in place of an FGD using only four of the six existing mounting holes.

Either the upper four or the lower four mounting holes may be used.

BE1-FLEX

The FGD-2 output can be connected to any analog input of the BE1-FLEX.

Field ground protection settings can be configured in BESTCOMSPlus.

Ground Detection Source

The ground detection source supplies approximately –60 Vdc to the positive

side of a machine field and measures the level of leakage current to ground.

The positive side of the field bus is held negative with respect to ground.

Introduction

The FGD-2 Field Ground Detector Module is a transducer that continuously

monitors the resistance of the field circuit of a synchronous machine with

respect to ground. It applies a fixed voltage with respect to ground which

causes a small leakage current to flow. The FGD-2 provides a low voltage

output signal proportional to the leakage current.

The voltage output is measured by a compatible product and used for

field ground protection. Two versions of the FGD-2 are available. A low-

voltage version, rated for 800 Vdc maximum generator field voltage, is

provided for brush or brushless exciter systems. A high-voltage version,

rated for 1.750 Vdc generator field voltage, is provided for static exciter

systems.

The metal enclosure of the FGD-2 offers electric shock protection from

incidental contact. A compatible footprint and identical functionality

make for simple replacement of a Field Ground Detector (FGD) with the

FGD-2.

BESTdata is a powerful tool that enables users to reverse time and analyze

previously recorded event data in high detail.

This level of analysis is essential for identifying the root cause of system

events-especially when basic magnitude measurements alone are insufficient.

— Product Features & Benefits

• View and Analyze COMTRADE records: BESTdata is based upon and

able to work with COMTRADE standardized records.

The software can not only open the records, but also perform complex math

and other functions to further process the data.

Pre-canned visuals allow for quick insight to analog, digital data as well as

phasors, RMS, peak and other commonly used variables.

• Virtual Channels: Digital equipment only measures voltage and current.

All other quantities are calculations of these two pieces. Similarly, COMTRADE

records typically only show voltage and current as separate channels.

Virtual channels are utilized to calculate most any other algorithm that we use

in Power Systems such as Impedance, Power, Differential Current and a wide

variety of other math functions.

Trajectory and Phasor graphics are available to view event progression through

the recordings. Trajectory graphs can be configured for not only voltage and

current, but also calculated quantities such as Impedance, Power and

Symmetrical Component calculations.

Modern digital devices offer a wide range of configurable settings to meet

diverse application needs. With so many parameters and functions available,

it is essential to have a user-focused interface.

BESTCOMSPlus® delivers that, helping users visualize device configurations,

and confidently manage system interactions for commissioning, operation,

and diagnostics.

BESTCOMSPlus® is used to set and monitor the BE1-FLEX, BE1-700V, BE1-11.

DECS-150. DECS-250. DECS-250E, DECS-250N, DECS-450. DGC-2020.

DGC-2020ES, and DGC-2020HD.

— Product Features & Benefits

• Logic:

Graphical Logic with Offline Simulation and Real Time Status: Graphical drag

and drop logic is simple to implement and greatly reduces the possibility of

errors. Logic Simulation and Real Time Logic Status further add visibility to see

exactly how a device configured and what it is doing.

• Metering & Commissioning Tools:

Real Time Analysis and Recording, Step & Frequency Response injection tools,

Control Panels, Phasor Diagrams, Real Time Logic Status, Extensive Metering

and Status capabilities all contribute to improving commissioning time and

confidence. These tools are useful for commissioning, troubleshooting, and

NERC compliance testing.

• Settings:

Graphical settings and logic provide a visual check of the settings to reduce

the possibility of inadvertent settings. Settings are logically organized in a

tree menu, making finding the setting of interest super easy.

System Parameters

All sensing is performed using an IT-D isolation module. Each IT-D isolation

module includes two channels that are capable of sensing either dc current

or dc voltage. The dc system current is sensed using an appropriately scaled

25. 50. 75. or 100-millivolt nominal metering shunt. DC voltages are sensed

by direct connection for nominal levels up to 1.500 Vdc. The BE1-11d can

utilize two IT-D modules to sense a single dc current and up to three dc

voltages.

The IT-D digitally samples the sensed inputs at a rate proportional to the

rectification system nominal power input frequency. The sampling rate is

established to maintain a high accuracy of the measurement for a dc signal

with ripple content.

High-speed fiber optic communications between the IT-Ds and the BE1-11d

transmit the magnitudes of the system measurement to the protection system.

Communications

Three independent communication ports provide access to all BE1-11d

functions. A USB (universal serial bus) port is located on the front panel,

a two-wire RS-485 port is located on the rear panel, and an optional

Ethernet port is located on the rear panel. The RS-485 and Ethernet ports

are electrically isolated.

Modbus® and DNP3 protocols are optionally available for the RS-485 or

Ethernet communication port.

The IEC 61850 protocol is optionally available for the Ethernet port when

RS-485 option is N (None). Separate instruction manuals cover each

available protocol. Consult the product bulletin or Basler Electric for

availability of these options and instruction manuals. Modbus sessions

can be operated simultaneously over the Ethernet and RS-485 ports.

Device Information

The version of the embedded software (firmware), serial number, and style

number are available from the front panel or the communication ports.

Three free-form fields (Device ID, Station ID, and User ID) can be used

to enter information to identify the BE1-11d. These fields are used by

many of the reporting functions to identify the BE1-11d reporting the

information. Examples of BE1-11d identification field uses include station

name, circuit number, relay system, and purchase order.

Device Security

Security settings affect read and write access. Passwords provide access

security for six distinct functional access areas: Read, Control, Operator,

Settings, Design, and Administrator. Each username/password is assigned

an access area with access to that area and each area below it. An

administrator password provides access to all six of the functional areas.

A second dimension of security is provided by the ability to restrict access

for any of the access areas to only specific communication ports.

For example, you could set up security to deny access to control commands

through the Ethernet port.

Setting Groups

Four setting groups allow adaptive relaying to be implemented to optimize

BE1-11d settings for various operating conditions. Automatic and external

logic can be employed to select the active setting group.

Clock

The clock is used by the logging functions to timestamp events. BE1-11d

timekeeping can be self managed by the internal clock or coordinated with

an external source through a network or IRIG device.

A backup capacitor and additional battery backup are provided for the clock.

During a loss of operating power, the backup capacitor maintains timekeeping

for up to 24 hours depending on conditions. As the capacitor nears depletion,

the backup battery takes over and maintains timekeeping. The backup battery

has a life expectancy of greater than five years depending on conditions.

IRIG

A standard unmodulated IRIG-B input receives time synchronization signals

from a master clock. Automatic daylight saving time compensation can be

enabled and set for floating or fixed dates.

General Features

HMI (Human-Machine Interface)

Each BE1-11d has a front-panel display and 12 LED indicators: Power

Supply Status, Relay Trouble Alarm, Minor Alarm, Major Alarm, Trip, and 

Indicator 1 through 7 (programmable in BESTlogicPlus). The backlit, liquid

crystal display (LCD) allows the BE1-11d to replace local indication and

control functions such as panel metering, alarm annunciation, and control 

switches. Four scrolling pushbuttons enable navigation through the LCD

menu tree. Parameters are changed using the Edit pushbutton. Targets,

alarms, and other registers are cleared with the Reset pushbutton.

In Edit mode, the scrolling pushbuttons provide data entry selections.

Edit mode is indicated by an LED on the Edit pushbutton.

Select Control Switch and Operate Control Switch pushbuttons provide a

means to control the logic switches.

The LCD has automatic priority logic to govern which metering values are

displayed on the screen so that when an operator approaches, the metering

data of most interest is automatically displayed without having to navigate

the menu structure. Scrollable metering parameters are selected on the

General Settings, Front Panel HMI settings screen in BESTCOMSPlus.