Basler Electric GENERATOR PROTECTION SYSTEM BE1-GPS100
INSTRUCTION MANUAL
FOR
GENERATOR PROTECTION SYSTEM
BE1-GPS100
The BE1-GPS100 Generator Protection System is an economical, microprocessor based, multifunction
system that is available in a drawout, H1 (half-rack), S1. and S1 double-ended package. BE1-GPS100
relays provide a comprehensive mix of protective functions to detect generator faults and abnormal
operating conditions in an integrated system. This system is suitable for any generator application and
many utility/co-generation facility Intertie applications. BE1-GPS100 features include:
• Three-phase and Neutral Overcurrent Protection
• Negative Sequence Overcurrent Protection
• Undervoltage and Overvoltage Protection
• Negative Sequence Overvoltage Protection
• Frequency Protection
• Directional Power Protection
• Volts per Hertz Protection
• Loss of Field Protection
• Breaker Failure Protection
• Synchronism Checking
• VT Circuit Monitoring
• Virtual Selector Switches
• General Purpose Timers
• Real-Time Instrumentation
• Reporting Functions
• Communication
• Self Diagnostics
• Logic Programmable (BESTlogic™)
BE1-GPS100 relays have four programmable contact sensing inputs, five programmable outputs, and
one alarm output. Outputs can be assigned to perform protection, control, or indicator operations through
logical programming. For example, protection functions could be programmed to cause a protective trip.
Control functions could be programmed to cause a manual trip, manual close, or automatic reclose.
Indicators could be configured to annunciate relay failure, a settings group change, and others.
Protection scheme designers may select from a number of pre-programmed logic schemes that perform
the most common protection and control requirements. Alternately, a custom scheme can be created
using BESTlogic.
A simplified Getting Started procedure for BE1-GPS100 users is provided in Section 2. Quick Start.
Features
The BE1-GPS100 relay includes many features for the protection, monitoring, and control of power
system equipment. These features include protection and control functions, metering functions, and
reporting and alarm functions. A highly flexible programmable logic system called BESTlogic allows the
user to apply the available functions with complete flexibility and customize the system to meet the
requirements of the protected power system. Programmable I/O, extensive communication features, and
an advanced HMI (human-machine interface) provide easy access to the features provided.
The following information summarizes the capabilities of this multifunction device. Each feature, along
with how to set it up and how to use its outputs is described in complete detail in the later sections of this
manual.
Input and Output Functions
Input functions consist of Power System Measurement and Contact Sensing Inputs. Programmable
Contact Outputs make up the output functions. Input and Output functions are described in the following
paragraphs.
Power System Measurement Functions
Three-phase currents and voltages are digitally sampled and the fundamental is extracted using a
Discrete Fourier Transform (DFT) algorithm. Digital sampling of the measured frequency provides high
accuracy at off-nominal values.
The voltage sensing circuits automatically configure themselves internally for single-phase, three wire or
four wire voltage transformer circuits. Voltage sensing circuitry provides voltage protection, frequency
protection, and watt/var metering. Neutral (residual) and negative sequence voltage magnitudes are
derived from the three-phase voltages. An auxiliary voltage sensing input provides protection capabilities
for over/undervoltage monitoring of the first and third harmonic of the VT source connected to the Vx
input. This capability is useful for stator ground fault protection and sync-check functions.
Each current sensing circuit is low burden and isolated. Neutral (residual) and negative sequence current
magnitudes are derived from the three-phase currents. An optional independent ground current input is
available for direct measurement of the current in a transformer neutral, tertiary winding, or flux balancing
current transformer.
Contact Sensing Inputs
Four programmable contact sensing inputs (IN1. IN2. IN3. and IN4) with programmable signal
conditioning provide a binary logic interface to the protection and control system. Each input function and
label is programmable using BESTlogic. A user-meaningful label can be assigned to each input and to
each state (energized and de-energized) for use in reporting functions.
Contact Outputs
Five programmable general-purpose contact outputs (OUT1. OUT2. OUT3. OUT4. and OUT5) provide a
binary logic interface to the protection and control system. One programmable, fail-safe contact output
(OUTA) provides an alarm output. Each output function and label is programmable using BESTlogic. A
user-meaningful name can be assigned to each output and to each state (open and closed) for use in
reporting functions. Output logic can be overridden to open, close, or pulse each output contact for testing
or control purposes. All output contacts are trip rated.
Protection and Control Functions
Protection functions consist of Overcurrent, Voltage, Frequency, Power, Fuse Loss, Breaker Failure
Protection, and general-purpose logic timers. Setting Groups and Virtual Control Switches make up the
control functions. The following paragraphs describe each protection and control function.
Overcurrent Protection
Phase and one neutral instantaneous overcurrent elements (50TP and 50TN) with settable time delays
provide inadvertent energization protection when properly supervised by voltage and/or frequency
elements (381. 159. 127).
One phase time-overcurrent element can be voltage restrained (51/27R) or voltage controlled (51/27C) to
provide system backup overcurrent protection (51P).
Two neutral inverse time-overcurrent elements provide ground overcurrent protection and/or generator
step-up (GSU) transformer ground backup protection (51TN and 151TN).
Each neutral 50/51 element can be assigned to monitor either the three-phase residual (IN
) or the optional
independent ground input (IG
).
One inverse time, negative sequence overcurrent element provides generator unbalance overload
protection (46).
Time-overcurrent functions employ a dynamic integrating timing algorithm covering a range from pickup to
40 times pickup with selectable instantaneous or integrated reset characteristics.
Time-overcurrent curves conform to the IEEE C37.112 document and include seven curves similar to
Westinghouse/ABB CO curves, five curves similar to GE IAC curves, four IEC curves, a fixed time curve,
and a user programmable curve. Each time current characteristic can be set for integrating or
instantaneous reset.
Digital signal processing filters out unwanted harmonic components while providing fast overcurrent
response with limited transient overreach and over-travel.
Voltage Protection
One volts per hertz protective element provides overexcitation protection for a generator and/or GSU
transformer (24).
Two phase overvoltage and two phase undervoltage element provides over/undervoltage protection (27P,
127P, 59P, and 159P). Phase overvoltage protection can be set for one of three, two of three, or three of
three logic. When a four-wire voltage transformer connection is used, overvoltage protection can be set
for either phase-to-phase voltage or phase-to-neutral voltage.
Two auxiliary overvoltage and two auxiliary undervoltage elements provide over/undervoltage protection
(27X, 127X, 59X, and 159X). Auxiliary voltage protection elements can be set to individually monitor the
auxiliary voltage fundamental, third harmonic, or phase 3V0 voltages. Complete stator ground fault
protection is provided when the auxiliary voltage input is connected to the generator grounding resistor
voltage, the 27X element is set for third harmonic undervoltage, and the 59X is set for the auxiliary
voltage fundamental.
With the auxiliary voltage input connected to the bus, one sync-check function provides synchronism
protection when putting the generator online (25). Sync-check protection checks for phase angle
difference, magnitude difference, frequency difference (slip) and, optionally, if the generator frequency is
greater than the bus frequency.
One negative-sequence overvoltage element provides protection for phase unbalance or a reverse
system phase (47).
Voltage transformer circuit monitoring adds security by detecting problems in the voltage transformer
sensing circuits and preventing misoperations of the 27P, 127P, 47. 59P, 159P, and the 51/27 functions
(60FL).
Directional Power Protection
Two directional power elements provide loss of prime mover protection and/or sequential trip, shutdown
operation (32. 132). Each directional power element can be set individually for forward or reverse power.
The power measurement algorithm is adapted as appropriate for any possible three-phase or single
phase voltage transformer connection. Directional Power is calibrated on a three-phase basis regardless
of the voltage transformer connection used.
Frequency Protection
Four over/underfrequency protection function blocks are provided: 81. 181. 281. and 381. Each function
block can be set for overfrequency or underfrequency operation.
Loss of Excitation
Loss of excitation protection consists of two elements (40Q, 140Q) that use offset sloped var flow
algorithm.
Breaker Failure Protection
One breaker failure protection block (BF) provides programmable breaker failure protection.
General Purpose Logic Timers
Four general-purpose logic timers (62. 162. 262. and 362) with six modes of operation are provided.
Setting Groups
Two setting groups allow adaptive relaying to be implemented to optimize BE1-GPS100 settings for
various operating conditions. Setting group selection can be made via relay logic, 43 auxiliary switches,
and hard-wired inputs.
Virtual Control Switches
BE1-GPS100 virtual control switches include one virtual breaker control switch and four virtual switches.
Trip and close control of a selected breaker can be controlled by the virtual breaker control switch (101).
The virtual breaker control switch is accessed locally from the front panel human machine interface (HMI)
or remotely from the communication ports.
Additional control is provided by the four virtual switches: 43. 143. 243. and 343. These virtual switches
are accessed locally from the front panel HMI or remotely from the communication ports. Virtual switches
can be used to trip and close additional switches or breakers, or enable and disable certain functions.
Metering Functions
Metering is provided for all measured currents, voltages, and frequency and all derived neutral and
negative-sequence currents and voltages. Three phase watts, vars, and power factor is provided. Per
phase watts and vars is also provided when the VT connection is 4W.
Reporting and Alarm Functions
Several reporting and alarm functions provide fault reporting, demand, breaker, and trip circuit monitoring,
as well as relay diagnostic and firmware information.
Energy Data Reporting
Energy information in the form of watt-hours and var-hours is measured and reported by the BE1
GPS100. Both positive and negative values are reported in three-phase, primary units.
Relay Identification
Two free-form fields are provided for the user to enter information to identify the relay. These fields are
used by many of the reporting functions to identify the relay that the report is from. Examples of relay
identification field uses are station name, circuit number, relay system, purchase order, and others.
Clock
A real-time clock is included with a capacitor backup and is available with an optional battery backup.
Depending upon conditions, capacitor backup maintains timekeeping during an eight to 24 hour loss of
operating power. Battery backup maintains timekeeping when operating power is removed for five years
or longer.
IRIG
A standard IRIG input is provided for receiving time synchronization signals from a master clock.
Automatic daylight saving time compensation can be enabled. Time reporting is settable for 12 or 24-hour
format. The date can be formatted as mm/dd/yy or dd/mm/yy.
General Status Reporting
The BE1-GPS100 provides extensive general status reporting for monitoring, commissioning, and
troubleshooting. Status reports are available from the front panel HMI or communication ports.
Demand Reporting
Ampere demand registers monitor phase A, B, C, Neutral, ±Power (kW), ±Reactive Power (kvar), and
Negative-Sequence values. The demand interval and demand calculation method are independently
settable for phase, neutral, and negative measurements. Demand reporting records today’s peak,
yesterday’s peak, and peak since reset with time stamps for each register.
Breaker Monitoring
Breaker statistics are recorded for a single breaker. They include the number of operations, accumulated
interrupted I or I2. and breaker time to trip. Each of these conditions can be set to trigger an alarm.
Trip Circuit Monitoring
A trip circuit monitor function is provided to monitor the trip circuit of a breaker or lockout relay for loss of
voltage (fuse blown) or loss of continuity (trip coil open). The monitoring input is internally connected
across OUT1. Additional trip or close circuit monitors can be implemented in BESTlogic using additional
inputs, logic timers, and programmable logic alarms.
Fault Reporting
Fault reports consist of simple target information, fault summary reports, and detailed oscillography
records to enable the user to retrieve information about disturbances in as much detail as is desired. The
relay records and reports oscillography data in industry standard IEEE Comtrade format to allow using
any fault analysis software. Basler Electric provides a Windows® based program called BESTwave™ that
can read and plot binary or ASCII format files that are in the COMTRADE format.
Sequence of Events Recorder
A 255 event Sequence of Events Recorder (SER) is provided that records and time stamps all relay
inputs and outputs as well as all alarm conditions monitored by the relay. Time stamp resolution is to the
nearest half-cycle. I/O and Alarm reports can be extracted from the records as well as reports of events
recorded during the time span associated with a specific fault report.
Alarm Function
Extensive self-diagnostics will trigger a fatal relay trouble alarm if any of the relay core functions are
adversely affected. Fatal relay trouble alarms are not programmable and are dedicated to the Alarm
output (OUTA) and the front panel Relay Trouble LED. Additional relay trouble alarms and all other alarm
functions are programmable for major or minor priority. Programmed alarms are indicated by major and
minor alarm LEDs on the front panel. Major and minor alarm points can also be programmed to any