Sel SEL-487E-5 User manual

Schweitzer Engineering Laboratories, Inc. SEL-487E Data Sheet
Transformer Protection Relay With
Sampled Values or TiDL Technology
Key Features and Benefits
The SEL-487E-5 Transformer Protection Relay With Sampled Values or TiDL®Technology provides three-phase differ-
ential protection for transformer applications with as many as five three-phase restraint current inputs. Use the three
independent restricted earth fault (REF) elements for sensitive ground-fault detection in grounded wye-transformer
applications. Detect turn-to-turn winding faults for as little as two percent of the total transformer winding with the neg-
ative-sequence differential element. Apply the two three-phase voltage inputs for over- and undervoltage, frequency, and
volts/hertz protection. Use distance elements to provide transmission line protection or backup transformer protection.
Make any overcurrent element directional using voltage polarized directional elements as torque control inputs to the
overcurrent elements. Monitor and protect critical substation assets with comprehensive breaker wear and transformer
thermal and through-fault monitoring. Perform bay control functions for as many as 5 breakers and 20 disconnect
switches by using the built-in system mimic diagrams.
➤High-Speed Differential Protection. A two-stage slope adapts automatically to external fault conditions, providing
fast, sensitive, dependable, and secure differential protection, even for CT saturation and heavily distorted waveforms.
Two independent differential zones are available, one of which supports additional features that accommodate
transformer differential protection.
➤Inrush and Overexcitation Detection. Combined harmonic blocking and restraint features provide maximum
security during transformer magnetizing inrush conditions. Waveshape-based inrush detection addresses inrush
conditions that contain low second and fourth harmonic content.
➤Turn-to-Turn Winding Fault Protection. Innovative negative-sequence differential elements provide transformer
windings protection from as little as two percent turn-to-turn winding faults.
➤Restricted Earth Fault Protection. Three independent REF elements provide sensitive protection for faults close
to the winding neutral in grounded wye-connected transformers.
➤Combined Overcurrent. Configurations exist for a wide variety of transformer applications. Use the combined
overcurrent elements for transformers connected to ring-bus or breaker and one-half systems. This feature
mathematically sums two terminal current inputs to form a single operating quantity.
SEL-487E-5 Transformer
Protection Relay

SEL-487E Data Sheet Schweitzer Engineering Laboratories, Inc.
2
➤Distance Protection. Mho or quadrilateral characteristics protect transformers and transmission lines with four
zones of phase distance and ground distance elements. Line harmonic blocking, load-encroachment, coupling
capacitor voltage transformer (CCVT) detection, and out-of-step blocking logic add security to your distance
protection scheme.
➤Transformer and Feeder Backup Protection. Adaptive time-overcurrent elements with selectable operating
quantity, programmable pickup, and time-delay settings provide transformer and feeder backup protection.
➤Reclosing Control. You can incorporate programmable three-pole trip and reclose of as many as six independent
breakers into an integrated substation control system.
➤Reverse Power Flow and Overload Condition Protection. The SEL-487E directional real- and reactive-power
elements guard against reverse power flow and overload conditions.
➤Synchronism Check. Synchronism check can prevent circuit breakers from closing if the corresponding phases
across the open circuit breaker are excessively out of phase, magnitude, or frequency. The synchronism-check
function has a user-selectable synchronizing voltage source and incorporates slip frequency, two levels of maximum
angle difference, and breaker close time into the closing decision.
➤Input/Output Scaling. The SEL-2600 RTD Module provides as many as 12 temperature inputs, and the
SEL-2505/SEL-2506 Remote I/O Modules provide a scalable number of discrete I/O points.
➤Two CT Input Levels. Selectable 1 A or 5 A nominal secondary input levels are available for any three-phase
winding input.
➤Large CT Mismatch Ratio. The relay can accommodate CT ratio mismatch as great as 35:1.
➤Breaker Failure. High-speed (less than one cycle) open-pole detection logic reduces coordination times for critical
breaker failure applications. Apply the relay to supply breaker failure protection for all supported breakers. Logic
for breaker failure retrip and initiation of transfer tripping is included.
➤IEC 60255-149 Compliant Thermal Model. The relay can provide a configurable thermal model for the protection
of a wide variety of devices. This function can activate a control action or issue an alarm or trip when equipment
overheats as a result of adverse operation conditions. A separate resistance temperature detector (RTD) module is
required for this application.
➤Ethernet Access. The optional Ethernet card grants access to all relay functions. Use IEC 61850 Manufacturing
Message Specification (MMS) or DNP3 protocol directly to interconnect with automation systems. You can also
connect to DNP3 networks through a communications processor. Use File Transfer Protocol (FTP) for high-speed data
collection. Connect to substation or corporate LANs to transmit synchrophasors by using TCP or UDP internet protocols.
➤Serial Data Communication. The relay can communicate serial data through SEL ASCII, SEL Fast Message,
SEL Fast Operate, MIRRORED BITS®, and DNP3 protocols. Synchrophasor data are provided in either SEL Fast
Message or IEEE C37.118 format.
➤Automation. The enhanced automation features include programmable elements for local control, remote control,
protection latching, and automation latching. Local metering on the large front-panel LCD eliminates the need for
separate panel meters. Serial and Ethernet links efficiently transmit key information, including metering data, protection
element and control I/O status, synchrophasor data, IEC 61850 Edition 2 GOOSE messages, Sequential Events
Recorder (SER) reports, breaker monitoring, relay summary event reports, and time synchronization. Apply expanded
SELOGIC®control equations with math and comparison functions in control applications. Incorporate as many as
1000 lines of automation logic to accelerate and improve control actions.
➤Synchrophasors. You can make informed load dispatch decisions based on actual real-time phasor measurements
from relays across your power system. Record streaming synchrophasor data from the relay for system-wide disturbance
recording. Control the power system by using local and remote synchrophasor data.
➤Breaker and Battery Monitoring. You can schedule breaker maintenance when accumulated breaker duty
(independently monitored for each pole) indicates possible excess contact wear. The relay records electrical and
mechanical operating times for both the last operation and the average of operations since function reset. Alarm
contacts provide notification of substation battery voltage problems (as many as two independent battery monitors
in some SEL-400 series relays) even if voltage is low only during trip or close operations.
➤Digital Secondary Systems (DSS) Technologies. You can order the relay as either an SV subscriber relay or a
TiDL relay. DSS capable relays receive current and voltage information that is published by remote merging units
instead of standard PT and CT inputs. DSS technologies reduce copper cable lengths and associated installation
labor costs and improve the overall safety of the substation.
➤IEC 61850-9-2LE SV Relay. The SV subscriber relay can subscribe to current and voltage information that is
published by as many as seven remote SV merging units that are compliant with the IEC 61850-9-2LE guideline.

Schweitzer Engineering Laboratories, Inc. SEL-487E Data Sheet
3
➤TiDL Relay. The TiDL relay can receive current and voltage information from as many as eight SEL-TMUs (TiDL
Merging Units) over direct point-to-point fiber-optic connections. The TiDL relay automatically synchronizes data
collection, alleviating the need or impact of an external clock on protection.
➤Selective Protection Disabling. The subscriber or TiDL relay provides selective disabling of protection functions
by using hard-coded logic or available torque-control equations in case of a loss of communications between your
merging unit and relay that results in the loss of relevant analog data.
➤Current Summation. The relay can combine multiple SV stream currents to simplify external wiring.
➤Six Independent Settings Groups. The relay includes group logic to adjust settings for different operating conditions,
such as station maintenance, seasonal operations, emergency contingencies, loading, source changes, and adjacent
relay settings changes. Select the active group settings by control input, command, or other programmable conditions.
➤Software-Invertible Polarities. Inverting individual or grouped CT and PT polarities allows you to account for
field wiring or zones of protection changes. CEV files and all metering and protection logic use the inverted polarities,
whereas COMTRADE event reports do not use inverted polarities but rather record signals as applied to the relay.
➤Parallel Redundancy Protocol (PRP). PRP provides seamless recovery from any single Ethernet network failure.
The Ethernet network and all traffic are fully duplicated with both copies operating in parallel.
➤IEC 61850 Operating Modes. The relay supports IEC 61850 standard operating modes such as Test, Blocked,
On, and Off.
➤IEEE 1588, Precision Time Protocol (PTP). PTP provides high-accuracy timing over an Ethernet network.
➤Digital Relay-to-Relay Communications. MIRRORED BITS communications can monitor internal element conditions
between bays within a station, or between stations, using SEL fiber-optic transceivers. Send digital, analog, and
virtual terminal data over the same MIRRORED BITS channel.
➤Sequential Events Recorder (SER). The SER records the last 1000 events, including setting changes, startups,
and selectable logic elements.
➤Oscillography and Event Reporting. The relay records voltages, currents, and internal logic points at a sampling
rate as fast as 8 kHz. Offline phasor and harmonic-analysis features allow investigation of bay and system performance.
Time-tag binary COMTRADE event reports with high-accuracy time stamping for accuracy better than 10 s.
➤Digitally Signed Upgrades. The relay supports upgrading the relay firmware with a digitally signed upgrade file.
The digitally signed portion of the upgrade file helps ensure firmware and device authenticity after it is sent over a
serial or Ethernet connection.
➤Increased Security. The relay divides control and settings into seven relay access levels; the relay has separate
breaker, protection, automation, and output access levels, among others. Set unique passwords for each access level.
➤Rules-Based Settings Editor. You can communicate with and set the relay by using an ASCII terminal or use
Grid Configurator to configure the relay and analyze fault records with relay element response. Use as many as
200 aliases to rename any digital or analog quantity in the relay.

SEL-487E Data Sheet Schweitzer Engineering Laboratories, Inc.
4
Functional Overview
SV
The SEL-487E subscribes to data streams that are pub-
lished by merging units, such as the SEL-421-7 SV Pub-
lisher or SEL-401 Protection, Automation, and Control
Merging Unit. The SEL-421-7 SV Publisher provides
additional backup protection while the SEL-401 can pro-
vide basic backup protection with phase-overcurrent and
breaker-failure protection in the absence of communica-
tion. The data may be synchronized using Precision Time
Protocol (PTP).
Figure 1 SEL-487E-5 SV Subscriber or TiDL Relay Functional Overview
ENV
49
DSS
Inputs
Process
Bus
Mapped
Breaker
Status and
Currents
Mapped
Breaker
Status and
Currents
Mapped Y
Terminal
Currents
Mapped
Voltages
Mapped
Breaker
Status and
Currents
SEL-487E-5
24
25
51N
50N
27
46
59
50BF
87T
50
50 51 67
REF
50BF
50BF
81
6751
32
21 68 79 87B
BRM DFR HMI LGC MET
PMU SBMRTU SER TRM
85
RIO SIP HBL
Five-port Ethernet card ordering option depicted.
4
EIA-232
2
Ethernet
Station Bus
(Ports 5C, 5D)
1
IRIG-B
2
Ethernet
Process Bus
(Ports 5A, 5B)
1
Ethernet
Enginnering
Access
(Port 5E)
16 S
E
C
ANSI NUMBERS/ACRONYMS AND FUNCTIONS
16 SEC Access Security (Serial, Ethernet)
21* Phase and Ground Distance
24 Volts/Hertz
25 Synchronism Check
27 Undervoltage
32 Directional Power
46 Current Unbalance
49 IEEE C59.71 and IEC 60255-Compliant Thermal Model
50BF Dual Breaker Failure Overcurrent
50N Neutral Overcurrent
50 Overcurrent
(Phase, Zero-Sequence, and Negative-Sequence)
51N Neutral Time-Overcurrent
51 Time-Overcurrent
(Phase, Zero-Sequence, and Negative-Sequence)
59 Overvoltage
67 Directional Overcurrent
(Phase, Zero-Sequence, and Negative-Sequence)
68* Out-of-Step Block
79* Autoreclosing
81 Over- and Underfrequency
85 RIO SEL M
IRRORED
B
ITS
Communications
87T Transformer Differential
(Unrestrained, Restrained, Neg. Seq.)
87B* Bus Differential (Restrained)
ADDITIONAL FUNCTIONS
BRM Breaker Wear Monitor
DFR Event Reports
ENV SEL-2600 RTD Module*
HBL Harmonic Blocking
HMI Operator Interface
LDP Load Data Profiling
LGC SEL
OGIC
Control Equations
MET High-Accuracy Metering
PMU Synchrophasors
REF Restricted Earth Fault
RTU Remote Terminal Unit
SBM Station Battery Monitor
SER Sequential Events Recorder
SIP Software-Invertible Polarities
TRM Transformer Monitor
* Optional Feature
Note: Both copper and fiber-optic Ethernet ports are available.
Figure 2 SV Network
q
Process Bus
qTime synchronization
is required for SV
communications. Time
synchronization can be
done over a process
bus or station bus

Schweitzer Engineering Laboratories, Inc. SEL-487E Data Sheet
5
TiDL
The SEL-487E-5 TiDL receives and automatically syn-
chronizes data streams from connected and commis-
sioned SEL-TMU devices. The TiDL technology does
not require an external time source for local relay protec-
tion functions.
Protection Features
Differential Element
In the SEL-487E, the phase differential elements employ
operate (IOPn, where n= A, B, C) and restraint (IRTn)
quantities that the relay calculates from the selected wind-
ing input currents. Figure 4 shows the characteristic of
the filtered differential element as a straight line through
the origin of the form:
IOPA (IRTA) = SLPc• IRTA
For operating quantities (IOPA) exceeding the threshold
level O87P and falling in the operate region of Figure 4,
the filtered differential element issues an output. There
are two slope settings, namely Slope 1 (SLP1) and Slope 2
(SLP2). Slope 1 is effective during normal operating
conditions, and Slope 2 is effective when the fault detec-
tion logic detects an external fault condition. In general,
the relay uses filtered and unfiltered (instantaneous) ana-
log quantities in two separate algorithms to form the dif-
ferential element. The adaptive differential element responds
to most internal fault conditions in less than one and a
half cycles.
The differential element includes one harmonic blocking
and one harmonic restraint element; select either one or
both of them. The combination of harmonic blocking and
restraint elements provides optimum operating speed and
security during inrush conditions. Waveshape-based
inrush detection addresses inrush conditions that contain
low second- and fourth-harmonic content. Fast subcycle
external fault detection supervision adds security during
external faults with CT saturation. The harmonic block-
ing element includes common or independent second-
and fourth-harmonic blocking and independent fifth-
harmonic blocking.
Negative-Sequence Differential
Element
Turn-to-turn internal faults on transformer windings may
not cause enough additional current flow at the transformer
bushing CTs to assert a phase-current differential element,
but left undetected can be very destructive to the trans-
former. When turn-to-turn faults occur, the autotransformer
effect on the shorted section of winding causes a very large
current flow relative to the shorted windings but small
compared to the remainder of the unaffected winding. To
detect these destructive internal faults,the SEL-487E uses a
sensitive negative-sequence current differential element.
This element detects the phase-current unbalance caused
by internal fault by using a single-slope characteristic. Using
negative-sequence restraint, the differential element is not
affected by fluctuating negative-sequence quantities on
the power system and is able to detect turn-to-turn short cir-
cuit conditions in as little as two percent of the total trans-
former winding. External fault detection logic from the
phase-differential element is used to block the negative-
sequence differential element, keeping it secure during
external faults and inrush conditions when CT saturation
may occur.
V/Hz Elements
The SEL-487E provides comprehensive V/Hz protection
(24). The SEL-487E maintains frequency tracking from
40.0 to 65.0 Hz when voltage inputs are provided to the
relay. Two independent V/Hz curves with definite and
custom 20-point curve characteristics can be selected using
programmable logic. Use the two independent V/Hz curves
for loaded versus unloaded transformer protection, allow-
ing maximum sensitivity to overexcitation conditions during
Figure 3 SEL TiDL System
T-Protocol
Figure 4 Adaptive Slope Differential Characteristics
IOPA (IRTA)
Operating Region
SLP2
087P
SLP1
Restraining Region
IRTA

SEL-487E Data Sheet Schweitzer Engineering Laboratories, Inc.
6
all modes of transformer operation. The single V/Hz element
in the relay can be assigned to either set of three-phase
voltage inputs.
Distance Elements
The SEL-487E protects transformers and transmission
lines with as many as four zones of phase distance and
ground distance elements with either mho or quadrilateral
characteristics. You can set all four zones independently
in the forward or reverse direction. The distance elements
are secured with load-encroachment logic, which prevents
operation of the phase distance elements under high load
conditions; line harmonic-blocking logic, which prevents
element operation when a transformer in the protection
zone is being energized or experiencing an overexcitation
condition; and CCVT transient detection, which blocks
the distance elements when there is transient on the system
with CCVTs that may cause the distance element to over-
reach. All mho elements use positive-sequence memory
polarization that expands the operating characteristic in
proportion to the source impedance. This provides depend-
able and secure operation for close-in faults. The quadri-
lateral phase and ground distance elements provide improved
fault and arc resistance coverage, including application
on short lines.
Out-of-Step Detection
The SEL-487E supports out-of-step detection by using
timers and blinders that are set outside any of the distance
elements. A power swing is declared when an impedance
locus travels through the blinders slower than a preset
time. This logic blocks the distance elements in case of a
stable power swing.
Adaptive Time-Overcurrent
Elements (51S)
The relay supports 20 adaptive time-overcurrent elements
with selectable operate quantity and programmable time-
delay and pickup levels. Choose from the ten time-
overcurrent curves shown in Table 1 (five IEC and
five U.S.). Each torque-controlled time-overcurrent ele-
ment has two reset characteristics. One choice resets the
elements if current drops below pickup for one cycle
while the other choice emulates the reset characteristic of
an electromechanical induction disk relay.
The adaptive time-overcurrent elements in the SEL-487E
allow the selection of a wide variety of current sources as
operate quantities to the element. Select the time-overcurrent
element operate quantity from any one of the following
current sources:
➤Filtered phase currents: IAmFM, IBmFM, ICmFM
➤Maximum filtered phase current: IMAXmF
➤Combined filtered phase currents (any two
terminals): IAmmFM, IBmmFM, ICmmFM
Figure 5 Volts/Hertz Curve Diagrams
Time (seconds)
Volts/Hertz (%)
24U101 (110,33)
24U109 (150,22)
24U116 (200,14)
Volts/Hertz (%)
Time (seconds) 33
24U101 (110,33)
24U102 (150,22)
24U103 (200,14)
24U104 (120,30)
24U107 (130,27)
Figure 6 Mho Characteristics
Table 1 Supported Time-Overcurrent Curves
U.S. Curves IEC Curves
U1 (moderately inverse) C1 (standard inverse)
U2 (inverse) C2 (very inverse)
U3 (very inverse) C3 (extremely inverse)
U4 (extremely inverse) C4 (long-time inverse)
U5 (short-time inverse) C5 (short-time inverse)
Expanded
Characteristic
Steady State
Characteristic
Relay Reach
Z
R
Z
S
X
R

Schweitzer Engineering Laboratories, Inc. SEL-487E Data Sheet
7
➤Maximum filtered combined phase current:
IMAXmmF
➤Filtered positive-, negative-, and zero-sequence:
I1mFM, 3I2mFM, 3I0mFM, I1mmM, 3I2mmM,
3I0mmM
➤RMS currents: IAmRMS, IBmRMS, ICmRMS,
IMAXmR IAmmRMS, IBmmRMS, ICmmRMS,
IMAXmmR
where:
m= Relay current terminals S, T, U, W, X, Y
mm = Relay current terminals ST, TU, UW, WX
F = Filtered
M = Magnitude
MAX = Maximum magnitude A-, B-, C-phase currents
In addition to the selectable operate quantity, the 51S ele-
ment time-delay and pickup level inputs are SELOGIC-
programmable settings. This flexibility allows these inputs
to be set to fixed numerical values to operate as standard
time overcurrent elements, or the pickup and time-dial
settings can be programmed as SELOGIC math variables.
Programming the time-delay and pickup levels as math
variables allows the numeric value of the pickup and time-
delay settings to change based on system conditions with-
out the added delay of having to change relay setting groups.
For example, change pickup and time-delay settings
dynamically in a parallel transformer application based
upon single or parallel transformer configurations. Another
example would be changing feeder time-overcurrent ele-
ment pickup and coordination delays based upon distributed
generation being connected downstream of a transformer.
REF Protection
Apply the REF protection feature to provide sensitive detec-
tion of internal ground faults on grounded wye-connected
transformer windings and autotransformers. Use single-
phase neutral current inputs for providing neutral CT oper-
ating current for as many as three windings. Polarizing
current is derived from the residual current calculated for
the corresponding protected winding. A directional ele-
ment determines whether the fault is internal or external.
Zero-sequence current thresholds supervise tripping. The
relay can accommodate CT ratio mismatch as great as 35:1.
Synchronism Check
Synchronism-check elements prevent circuit breakers
from closing if the corresponding phases across the open
circuit breaker are excessively out of phase, magnitude,
or frequency. The SEL-487E synchronism-check ele-
ments selectively close circuit breaker poles under the
following criteria:
➤The systems on both sides of the open circuit
breaker are in phase (within a settable voltage
angle difference).
➤The voltages on both sides of the open circuit
breaker are healthy (within a settable voltage
magnitude window).
The synchronism-check function is available for as many
as six breakers with a user-selectable reference voltage.
Each element has a user-selectable synchronizing voltage
source and incorporates slip frequency, two levels of
maximum angle difference, and breaker close time into
the closing decision. Include the synchronism-check ele-
ment outputs in the close SELOGIC control equations to
program the relay to supervise circuit breaker closing.
Current Unbalance Elements
The current unbalance logic uses the average terminal cur-
rent to calculate the percentage difference between the
individual phase current and the terminal median current.
If the percentage difference is greater than the pickup value
setting, the phase unbalance element is asserted. To pre-
vent this element from asserting during fault conditions
and after a terminal circuit breaker has closed, the final
terminal unbalance output is supervised using current,
fault detectors, and the open-phase detection logic.
Fault Identification Logic
The purpose of the fault identification logic is to deter-
mine, on a per-terminal basis, which phase(s) was involved
in a fault for which the transformer tripped. Determining
the faulted phase is based on current inputs from wye-
connected CTs. The logic does not determine the faulted
phase for the following cases:
➤Delta-connected CTs (CTCONm= D)
➤Where only zero-sequence current flows through
the relay terminal (no negative-sequence current
and no positive-sequence current)
This logic identifies a sector in which a faulted phase(s)
can appear by comparing the angle between the negative-
and zero-sequence currents I2mand I0m(m= S, T, U, W,
X, Y).
Application Examples
The SEL-487E-5 SV Subscriber offers comprehensive
transformer protection features. Around the clock wind-
ing phase compensation simplifies setting the trans-
former protection elements. Harmonic restraint and
blocking using second and fourth harmonic quantities

SEL-487E Data Sheet Schweitzer Engineering Laboratories, Inc.
8
provide secure operation during transformer energiza-
tion, while maintaining sensitivity for internal faults.
Waveshape-based inrush detection addresses inrush con-
ditions that contain low second and fourth harmonic con-
tent. For applications without voltage inputs (therefore
no volts/hertz element), use the fifth harmonic monitor-
ing to detect and alarm on over-excitation conditions.
The SEL-487E-5 SV Subscriber can be used in applica-
tions with as many as five three-phase current inputs. For
the application shown in Figure 7, the SEL-487E sub-
scribes to a total of four IEC 61850 9-2 SV streams from
two different merging units. The SV publishers and sub-
scriber for this application are connected through a pro-
cess bus network switch. The same network switch is
being used to communicate GOOSE messages and time-
synchronize the system by using a PTP time source.
Use the negative-sequence differential element for sensi-
tive detection of inter-turn faults within the transformer
winding.
Phase, negative-, and zero-sequence overcurrent ele-
ments provide backup protection. Use breaker failure
protection with subsidence detection to detect breaker
failure and minimize system coordination times.
When voltage inputs are provided to the SEL-487E, volt-
age-based protection elements and frequency tracking
are made available. Frequency tracking from 40.0 to
65.0 Hz over- and undervoltage, and frequency elements,
along with volts/hertz elements provide the SEL-487E
with accurate transformer protection for off-frequency
events and overexcitation conditions.
Use the SEL-487E for complete protection of generator
step-up (GSU) transformer applications. Use built-in
thermal elements for monitoring both generator and
transformer winding temperatures. Apply the volts/hertz
element with two level settings for overexcitation protec-
tion of loaded and unloaded generator operating condi-
tions. Set the directional power elements to detect
forward and reverse power flow conditions for monitor-
ing and protection of the generator step-up (GSU) trans-
former in prime power, standby, base load, and peak
shaving applications.
In the TiDL version of this application, you can connect
the SEL-487E-5 TiDL Relay to two SEL-TMU devices.
as shown in Figure 7.
Figure 7 Wye-Delta Transformer With Grounding Bank (SV)
Substation Yard
Control House
SV Publication
1. IW, VYw
2. IX, VZw
GOOSE Publications
1. 52AA1
IW IX
PTP Time Source
Process Bus
Network
SV Publication
1. IW, VYw
2. IX, VZw
GOOSE Publications
1. 52AA1
GOOSE Publications
1. TRPXFMR, TRIPS, TRIPT, CLS, CLT
IW IX
qq
(REF) (REF)
52 52
HV Bus LV Bus
ST
3
1
3
1
qDC connections for breaker
status and control.
wNo physical connection.
Published data do not contain
valid analog measurements.
SV Subscriber
Merging Unit #1 Merging Unit #2

Schweitzer Engineering Laboratories, Inc. SEL-487E Data Sheet
9
You can also apply the SEL-487E to an autotransformer
with both HV and LV busbars installed in a breaker-and-
a-half configuration. In the SV version of the application
shown in Figure 9, the SEL-487E-5 SV Subscriber Relay
subscribes to a total of five IEC 61850 9-2 SV streams
from three different merging units. The SV publishers
and subscriber for this application are connected through
a process bus network switch. The same network switch
communicates GOOSE messaging and time-synchro-
nizes the system by using a PTP time source.
Figure 8 Wye-Delta Transformer With Grounding Bank (TiDL)
Substation Yard
Control House
qq
(REF) (REF)
52 52
ST
3
1
3
1
qDC connections for breaker
status and control.
TiDL Relay
#1 #2

SEL-487E Data Sheet Schweitzer Engineering Laboratories, Inc.
10
Distance Protection
The SEL-487E-5 simultaneously supports as many as
four zones of phase and ground distance protection,
using mho or quadrilateral characteristics. You can use
expanded SELOGIC control equations to tailor the relay
further to your particular application. The SEL-487E-5
distance elements are flexible enough to be used for
transmission line or transformer winding protection, as
shown in Figure 10 and Figure 11.
For distance protection, the SEL-487E-5 uses one SEL
TiDL Merging Unit (SEL-TMU) with 4 CT and 4 PT
inputs. The CT and PT connections are wired to the
SEL-TMU, and the SEL-TMU publishes these current
and voltage values to the SEL-487E-5 TiDL relay over a
fiber-optic connection by using SEL T-protocol. The
SEL-487E-5 sends trip and control signals to the
SEL-TMU over the same fiber-optic connection.
Figure 9 Autotransformer Application
Merging Unit #2
52 52
HV Busbar 1 HV Busbar 2
ST
3
1
52
IW IX VY
52 5252
IW
IX
VY
Substation Yard
Control House PTP Time Source
Process Bus
Network
GOOSE Publications
1. TRPXFMR, TRIPS, TRIPT, TRIPU,
TRIPW, CLS, CLT, CLU, CLW
qDC connections for breaker
status and control.
wNo physical connection.
Published data do not contain
valid analog measurements.
UW
LV Busbar 1 LV Busbar 2
q
q
IW
q
q
SV Publication
1. IW, VY
2. IX, VZw
GOOSE Publications
1. 52AA1, 52AA2
SV Publication
1. IW, VY
2. IX, VZw
GOOSE Publications
1. 52AA1, 52AA2
Autotransformer
Neutral CT
SV Publication
1. IW, VYw
3
3
3
3
3
Merging Unit #3
Merging Unit #1
SV Subscriber

Schweitzer Engineering Laboratories, Inc. SEL-487E Data Sheet
11
Six Terminal Feeder Protection
Use the six three-phase current terminals on the SEL-487E to provide comprehensive feeder protection and control
including overcurrent, reclosing, directional overcurrent, and breaker failure protection for six feeders. A single
SEL-487E can provide full feeder functionality of six single function feeder relays thereby reducing the device count
within the system. Figure 12 shows a TiDL system that can be used for this application; however, an IEC 61850 9-2 sys-
tem is also supported.
Synchrophasor Applications
Use the SEL-487E as a station-wide synchrophasor mea-
surement and recording device. The SEL-487E provides
as many as 24 analog channels of synchrophasor data
and can serve as a central phasor measurement unit in
any substation or power generation facility. The
SEL-487E can be configured to send five unique syn-
chrophasor data streams over serial and Ethernet ports,
measure voltage and current phase angle relationships at
generators and transformers, key source nodes for stabil-
ity studies, and load angle measurements. Use the
SEL-487E to store as much as 120 seconds of
IEEE C37.118 binary synchrophasor data for all 24 ana-
log channels at a recording rate of 60 messages per sec-
ond. A SELOGIC control equation triggers storage of
data. Capture data as necessary, and then store this infor-
mation in SEL-487E nonvolatile memory. Use this capa-
bility to record system transients for comparison to state
machine estimations.
Figure 10 Transformer Distance Application (TiDL)
5252
Substation Yard
Control House
qDC connections
for breaker
status and control.
S
HV Busbar LV Busbar
q
33
Zone 1
Zone 2
TiDL Relay
Figure 11 Transmission Line Distance Application (TiDL)
52
Substation Yard
Control House
qDC connections
for breaker
status and control.
q
33
Zone 1
Zone 2
TiDL Relay
Figure 12 Six Terminal Feeder Application (TiDL)
Substation Yard
Control House
352
3
52
52
5252 52
#1 #2 #3 #4 #5 #6
TiDL Relay

SEL-487E Data Sheet Schweitzer Engineering Laboratories, Inc.
12
Additional Features
Front-Panel Display
The LCD shows event, metering, setting, and relay self-
test status information. The target LEDs display relay
target information as shown in Figure 13.
The LCD is controlled by the navigation pushbuttons
(Figure 14), automatic messages the relay generates, and
user-programmed analog and digital display points. The
rotating display scrolls through alarm points, display points,
and metering screens. If none are active, the relay scrolls
through displays of the fundamental and rms metering
screens. Each display remains for a user-programmed
time (1–15 s) before the display continues scrolling. Any
message the relay generates because of an alarm condition
takes precedence over the rotating display.
Figure 13 and Figure 14 show close-up views of the front
panel of the SEL-487E. The front panel includes a 128 x
128 pixel, 3" x 3" LCD screen; LED target indicators; and
pushbuttons with indicating LEDs for local control func-
tions. The asserted and deasserted colors for the LEDs
are programmable. Configure any of the direct-acting
pushbuttons to navigate directly to any HMI menu item
for fast viewing of events, alarm points, display points, or
the SER.
Bay Control
The SEL-487E provides dynamic bay one-line diagrams on
the front-panel screen with disconnect and breaker con-
trol capabilities for user-selectable bay types. You can
download the Grid Configurator interface from
selinc.com to obtain additional user-selectable bay types.
The bay control can control as many as ten disconnects
and two breakers, depending on the one-line diagram
selected. Certain one-line diagrams provide status for as
many as three breakers and five disconnect switches.
Operate disconnects and breakers with ASCII com-
mands, SELOGIC control equations, Fast Operate Mes-
sages, and from the one-line diagram. The one-line
diagram includes user-configurable apparatus labels and
as many as six user-definable analog quantities.
One-Line Bay Diagrams
The SEL-487E offers a variety of preconfigured one-line
diagrams for common bus configurations. Once you
select a one-line diagram, you can customize the names for
all of the breakers, disconnect switches, and buses. Most
one-line diagrams contain analog display points. You can
set these display points to any of the available analog
quantities (including remote 87L currents) with labels,
units, and scaling. The SEL-487E updates these values
along with the breakers and switch position in real time
to give instant status and complete control of a bay. The
following diagrams demonstrate some of the preconfig-
ured bay arrangements available in the SEL-487E.
Programmable interlocks help prevent operators from
incorrectly opening or closing switches or breakers. The
SEL-487E not only prevents operators from making an
incorrect control decision, but it can notify and/or alarm
upon initiation of an incorrect operation.
Figure 13 Factory-Default Status and Trip Target LEDs
(12 Pushbutton, 24 Target LED Option)
Figure 14 Factory-Default Front-Panel Display and
Pushbuttons
FAULT QUANTITIES
(pu)
Zone 1 Zone 2
IOPA= 4.35 0.20
IOPB= 4.76 0.12
IOPC= 0.56 0.88
IRTA= 6.65 1.09
IRTB= 6.21 1.81
IRTC= 1.06 1.25
EVENT SUMMARY 10002

Schweitzer Engineering Laboratories, Inc. SEL-487E Data Sheet
13
Circuit Breaker Operations From the
Front Panel
Figure 15–Figure 18 are examples of some of the select-
able one-line diagrams in the SEL-487E. Select the one-
line diagram from the Bay settings. Additional settings
for defining labels and analog quantities are also found in
the Bay settings. One-line diagrams are composed of the
following:
➤Bay names and bay labels
➤Busbar and busbar labels
➤Breaker and breaker labels
➤Disconnect switches and disconnect switch labels
➤Analog display points
Figure 19 shows the breaker control screens available
when the ENT pushbutton is pressed with the circuit
breaker highlighted as shown in Figure 19(a).
Figure 15 Breaker-and-a-Half
Figure 16 Ring Bus With Ground Switch
BAYNAME
BK2
BK1
SW1 SW2
BK3
BAYLAB2BAYLAB1
BUSNAM1
BUSNAM2
ESCNAVIG
BAYNAME
6 ANALOGS
I:99999.9 A
V:99999.9 KV
P:99999.9 MW
Q:99999.9 MV
F:99.9 HZ
BAYLAB1
SW2
SW3
BK1
BK2
SW1
BAYLAB2
ESCNAVIG
Figure 17 Double Bus/Double Breaker
Figure 18 Source Transfer Bus
BAYNAME
6 ANALOGS
I:99999.9 A
V:99999.9 KV
P:99999.9 MW
Q:99999.9 MV
F:99.9 HZ
BUSNAM1
SW2
SW3
BK1 BK2
SW1
BUSNAM2
ESCNAVIG
BAYNAME
BUSNAM1
BK1 BK2
BUSNAM2
BAYLAB1
I:99999.9 A
V:99999.9 KV
P:99999.9 MW
I:99999.9 A
V:99999.9 KV
P:99999.9 MW
ESCNAVIG

SEL-487E Data Sheet Schweitzer Engineering Laboratories, Inc.
14
Rack-Type Breakers Mosaics
The SEL-487E supports the display of rack-type (also
referred to as truck-type) circuit breakers. The rack-type
breakers have three positions: racked out, test, and racked
in. When in the test or racked-in positions, the breaker
can be displayed as open or closed. When racked out, no
breaker open/close display are available. The rack-type
breakers are a display-only functionality and do not impact
any circuit breaker control capabilities.
Status and Trip Target LEDs
The SEL-487E includes programmable status and trip tar-
get LEDs, as well as programmable direct-action control
pushbuttons on the front panel. Figure 13 shows these targets.
The SEL-487E features a versatile front panel that you
can customize to fit your needs. Use SELOGIC control
equations and slide-in configurable front-panel labels to
change the function and identification of target LEDs
and operator control pushbuttons and LEDs. The blank
slide-in label set is included with the SEL-487E. You can
use templates supplied with the relay or hand label sup-
plied blank labels and print label sets from a printer.
Alarm Points
You can display messages on the SEL-487E front-panel
LCD that indicate alarm conditions in the power system.
The relay uses alarm points to place these messages on
the LCD.
Figure 20 shows a sample alarm points screen. The relay
can display as many as 66 alarm points. The relay auto-
matically displays new alarm points while in manual-
scrolling mode and in autoscrolling mode. You can con-
figure the alarm points message and trigger it either
immediately by using inputs, communications, or condi-
tionally by using powerful SELOGIC control equations.
The asterisk next to the alarm point indicates an active
alarm. Use the front-panel navigation pushbuttons to
clear inactive alarms.
Figure 19 Screens for Circuit Breaker Selection
Bus Labels
BAYNAME
BAYNAME
OPEN BREAKER
CLOSE BREAKER
OPEN
Bkrnam
PRESS TO ACTIVATE
Bay not in
LOCAL Control!
Cannot issue
controls.
Press ENT with breaker highlighted
Breaker
Highlighted
(a) Bay Screen
(c) LOCAL bit NOT asserted
(b) Breaker Control Screen
After three seconds,
re-display the previous screen
BUS 2
Dis 4
Bkr 1
Dis 3
Dis 1 Dis 2
BUS 1
BUS T
Bay Name
Disconnect
Switch Label
Disconnect
Switch Label
Disconnect
Switch Label
Analog
Quantities
Display
Breaker
Label
6 ANALOGS
I:99999.9 A
V:99999.9 KV
P:99999.9 MW
Q:99999.9 MV
F:60.000 HZ
ESCNAVIG
ESCNAVIG

Schweitzer Engineering Laboratories, Inc. SEL-487E Data Sheet
15
Advanced Display Points
Create custom screens showing metering values, special
text messages, or a mix of analog and status information.
Figure 21 shows an example of how you can use display
points to show circuit breaker information and current
metering. You can create as many as 96 display points.
All display points occupy only one line on the display at
all times. The height of the line is programmable as either
single or double, as shown in Figure 21. These screens
become part of the autoscrolling display when the front
panel times out.
Communications Features
See Specifications on page 25 for specific supported protocols.
The relay offers the following communications features:
➤Four independent EIA-232 serial ports.
➤Access to event history, relay status, and meter
information from the communications ports.
➤Password-controlled settings management and
automation features.
➤SCADA interface capability, including FTP,
IEC 61850, DNP3 LAN/WAN (via Ethernet), and
DNP3 (via serial port). The relay does not require
special communications software. You only need
ASCII terminals, printing terminals, or a computer
supplied with terminal emulation and a serial
communications port.
➤Synchrophasor data at 60 message-per-second data
format.
Ethernet Card
The Ethernet card has five small form-factor pluggable
(SFP) ports.aPORT 5A and PORT 5B are reserved for the
process bus network. PORT 5C and PORT 5D are reserved
for the station bus network. The process and station bus
networks support PRP and fast failover redundancy
modes. PORT 5E operates on an isolated network with a
unique IP address making it ideal for engineering and
data access. All ports support 100 Mbps speeds. PORT 5A
and PORT 5B also support 1 Gbps speeds to satisfy poten-
tially large traffic requirements on the process bus. The
process bus, station bus, and engineering access net-
Figure 20 Sample Alarm Points Screen
*Unauthorized Access
*LOP Asserted
*SF6 Low Bk1
ALARM POINTS
Press to acknldge
Figure 21 Sample Display Points Screen
Circuit Breaker 1
--Closed--
DISPLAY POINTS
Circuit BK1 SF6 Gas
--Alarm--
Circuit Breaker 2
A PH= 119.6 A pri
SF6 ALARM
Figure 22 System Functional Overview
Automation
Over Ethernet:
Two Ethernet Ports
10/100BASE-T
100BASE-FX
To Remote SEL Relay
Using MIRRORED BITS
Spare
Front Port Local
Operator or
Engineering
Access
IEC 61850 or
DNP LAN/WAN Communications
Processor
Serial Communication:
Three Rear EIA-232 Ports
One Front EIA-232 Port
aSFP transceivers are not included with the card and must be ordered
separately. See selinc.com/products/sfp for a list of compatible SFP
transceivers.

SEL-487E Data Sheet Schweitzer Engineering Laboratories, Inc.
16
works use separate MAC addresses and are logically
delineated, including in the Configured IED Description
(CID) file.b
Use popular Telnet applications for easy terminal com-
munications with SEL relays and other devices. Transfer
data at high speeds for fast file uploads. The Ethernet
card communicates using FTP applications for easy and
fast file transfers.
Communicate with SCADA by DNP3 and other substa-
tion IEDs by using IEC 61850 Manufacturing Message
Specification (MMS) and GOOSE messaging.
Choose Ethernet connection media options for primary
and standby connections:
➤10/100BASE-T twisted pair networkc
➤100BASE FX fiber-optic network
➤1000BASE-X fiber-optic networkd
Telnet and FTP
Use Telnet to access relay settings, metering, and event
reports remotely by using the ASCII interface. Use FTP
to transfer settings files to and from the relay via the
high-speed Ethernet port.
DNP3 LAN/WAN
DNP3 LAN/WAN provides the relay with DNP3 Level 2
Outstation functionality over Ethernet. Configure DNP3
data maps for use with specific DNP3 masters.
PTP
The Ethernet card provides the ability for the relay to accept
IEEE 1588 PTPv2 for data time synchronization. PTP
support includes the Default, Power System, and Power
Utility Automation Profiles. When connected directly to
a grandmaster clock providing PTP at 1-second synchro-
nization intervals, the relay can be synchronized to an
accuracy of ±100 ns in the PTP time scale.
SNTP Time Synchronization
Use SNTP to synchronize relays to as little as ±1 ms with
no time source delay. Use SNTP as a primary time source,
or as a backup to a higher accuracy time input to the relay.
PRP
Use PRP to provide seamless recovery from any single
Ethernet network failure, in accordance with IEC 62439-3.
The Ethernet network and all traffic are fully duplicated
with both copies operating in parallel.
HTTP Web Server
The relay can serve read-only webpages displaying cer-
tain settings, metering, and status reports. The web server
also allows quick and secure firmware upgrades over
Ethernet. As many as four users can access the embedded
HTTP server simultaneously.
IEC 61850 Ethernet Communications
IEC 61850 Ethernet-based communication protocols
provide interoperability between intelligent devices within
the substation. Standardized logical nodes allow inter-
connection of intelligent devices from different manufac-
turers for monitoring and control of the substation.
Eliminate system RTUs by streaming monitor and con-
trol information from the intelligent devices directly to
remote SCADA client devices.
bThis paragraph describes the five-port Ethernet card ordering option.
It does not apply to the four-port Ethernet card ordering option.
cFour-port Ethernet card ordering option only.
dGigabit speeds are only available on PORT 5A and PORT 5B of the five-
port Ethernet card ordering option.
Figure 23 Example PTP Network
GPS

Schweitzer Engineering Laboratories, Inc. SEL-487E Data Sheet
17
You can order the relay with IEC 61850 protocol for relay
monitor and control functions, including:
➤As many as 128 incoming GOOSE messages. You
can use the incoming GOOSE messages to control
as many as 256 control bits in the relay with <3 ms
latency from device to device depending on network
design. These messages provide binary control
inputs to the relay for high-speed control functions
and monitoring.
➤As many as eight outgoing GOOSE messages.
Configure outgoing GOOSE messages for Boolean
or analog data such as high-speed control and
monitoring of external breakers, switches, and other
devices. Boolean data are provided with <3 ms latency
from device to device depending on network design.
➤IEC 61850 Data Server. The relay equipped with
embedded IEC 61850 Ethernet protocol provides
data according to predefined logical node objects.
Each relay supports as many as seven unbuffered
MMS report client associations. Relevant Relay
Word bits are available within the logical node
data, so status of relay elements, inputs, outputs, or
SELOGIC control equations can be monitored.
➤As many as 256 virtual bits. Configure the virtual
bits within GOOSE messaging to represent a variety
of Boolean values available within the relay. These
bits that the relay receives are available for use in
SELOGIC control equations.
➤As many as 64 remote analog outputs. Assign the
remote analog outputs to virtually any analog quantity
available in the relay. You can also use SELOGIC
math variables to develop custom analog quantities
for assignment as remote analog outputs. Remote
analog outputs that use GOOSE messages provide
peer-to-peer transmission of analog data. Each relay
can receive as many as 256 remote analog inputs
and use those inputs as analog quantities within
SELOGIC control equations.
➤IEC 61850 standard operating modes. The relay
supports Test, Blocked, On, and Off. The relay also
supports Simulation mode for added flexibility.
MMS File Services
This service of IEC 61850 MMS provides support for file
transfers completely within an MMS session. All relay
files that can be transferred via FTP can also be transferred
via MMS file services.
MMS Authentication
When enabled via a setting in the Configured IED Descrip-
tion (CID) file, the relay requires authentication from any
client requesting to initiate an MMS session.
Architect Software
Use ACSELERATOR Architect SEL-5032 Software to
manage the IEC 61850 configuration for devices on the
network. This Windows-based software provides easy-
to-use displays for identifying and binding IEC 61850
network data among logical nodes that use IEC 61850-
compliant CID files. Architect uses CID files to describe
the data available in each relay.
Serial Communications
MIRRORED BITS Communications
The SEL patented MIRRORED BITS technology provides
bidirectional relay-to-relay digital communication.
Figure 24 shows two relays with SEL-2815 Fiber-Optic
Transceivers that use MIRRORED BITS communications.
MIRRORED BITS communications can operate simultane-
ously on any two serial ports. This bidirectional digital
communication creates additional outputs (transmitted
MIRRORED BITS) and additional inputs (received
MIRRORED BITS) for each serial port operating in the
MIRRORED BITS communications mode.
Communicated information can include digital, analog,
and virtual terminal data. Virtual terminal allows opera-
tor access to remote relays through the local relay. You
can use this MIRRORED BITS protocol to transfer infor-
mation between stations to enhance coordination and
achieve faster tripping.
Figure 24 Integral Communication Provides Secure Protection, Monitoring, and Control as Well as Terminal Access to
Both Relays Through One Connection
HV Breaker
MIRRORED BITS Communications
HV Busbars LV Busbars
Remote
LV Breaker
Power
Cable

SEL-487E Data Sheet Schweitzer Engineering Laboratories, Inc.
18
Open Communications Protocols
The relay does not require special communications software. ASCII terminals, printing terminals, or a computer sup-
plied with terminal emulation and a serial communications port are all that is required. Table 2 lists a brief description of
the terminal protocols.
Automation
Flexible Control Logic and
Integration Features
Use the control logic to perform the following:
➤Replace traditional panel control switches
➤Eliminate remote terminal unit (RTU)-to-bay wiring
➤Replace traditional latching relays
➤Replace traditional indicating panel lights
Eliminate traditional panel control switches with 96 local
control points. Set, clear, or pulse local control points
with the front-panel pushbuttons and display. Program
the local control points to implement your control scheme
via SELOGIC control equations. Use the local control
points for such functions as trip testing, enabling/disabling
reclosing, and tripping/closing circuit breakers.
Eliminate RTU-to-bay wiring with 64 remote control
points per relay. Set, clear, or pulse remote control points
via serial port commands. Incorporate the remote control
points into your control scheme via SELOGIC control
equations. Use remote control points for SCADA-type
control operations (e.g., trip, close, settings group selection).
Replace traditional latching relays for such functions as
remote control enable with 64 latching control points.
Program latch set and latch reset conditions with SELOGIC
control equations. Set or reset the latch control points via
control inputs, remote control points, local control points,
or any programmable logic condition. The relay retains
the states of the latch control points after turning on fol-
lowing a power interruption.
Replace traditional indicating panel lights and switches
with as many as 24 latching target LEDs and as many as
12 programmable pushbuttons with LEDs. Define cus-
tom messages (i.e., BREAKER OPEN, BREAKER CLOSED,
RECLOSER ENABLED) to report power system or relay con-
ditions on the large format LCD. Control displayed mes-
sages with SELOGIC control equations by driving the
LCD via any logic point in the relay.
Table 2 Open Communications Protocol
Type Description
ASCII Plain-language commands for human and simple machine communications. Use for metering, setting, self-test
status, event reporting, and other functions.
Compressed ASCII Comma-delimited ASCII data reports. Allows external devices to obtain bay data in an appropriate format for
direct import into spreadsheets and database programs. Data are checksum protected.
Extended Fast Meter, Fast
Operate, and Fast SER
Binary protocol for machine-to-machine communications. Quickly updates SEL-2032 Communications Pro-
cessors, RTUs, and other substation devices with metering information, bay element, I/O status, time-tags,
open and close commands, and summary event reports. Data are checksum protected. Binary and ASCII proto-
cols operate simultaneously over the same communications lines so that control operator metering information
is not lost while a technician is transferring an event report.
Ymodem Support for reading event, settings, and oscillography files.
Optional DNP3 Level 2
Outstation
DNP with point remapping. Includes access to metering data, protection elements, contact I/O, targets, SER,
relay summary event reports, and settings groups.
IEEE C37.118 Phasor measurement protocol.
MIRRORED BITS SEL protocol for exchanging digital and analog information among SEL relays and for use as low-speed termi-
nal connection.
IEC 61850 Ethernet-based international standard for interoperability between intelligent devices in a substation.
PRP PRP provides redundant Ethernet network capabilities for seamless operation in the event of loss to one network.
SNTP Ethernet-based SNTP for time synchronization among relays.
FTP and Telnet Use Telnet to establish a terminal-to-relay connection over Ethernet. Use FTP to move files in and out of the
relay over Ethernet.

Schweitzer Engineering Laboratories, Inc. SEL-487E Data Sheet
19
SELOGIC Control Equations With
Expanded Capabilities and Aliases
Expanded SELOGIC control equations put relay logic in
the hands of the engineer. Assign inputs to suit your
application, logically combine selected bay elements for
various control functions, and assign outputs to your
logic functions.
Programming SELOGIC control equations consists of
combining relay elements, inputs, and outputs with
SELOGIC control equation operators (Table 3). Any ele-
ment in the Relay Word can be used in these equations.
For complex or unique applications, these expanded
SELOGIC functions allow superior flexibility.
Use the relay alias capability to assign more meaningful
names to analog and Boolean quantities. This improves
the readability of customized programming. Use as many
as 200 aliases to rename any digital or analog quantity.
The following is an example of possible applications of
SELOGIC control equations that use aliases.
Add programmable control functions to your relay and
automation systems. New functions and capabilities enable
using analog values in conditional logic statements. The
following are examples of possible applications of
SELOGIC control equations with expanded capabilities.
➤Emulate a motor-driven reclose timer, including
stall, reset, and drive-to-lockout conditions.
➤Scale analog values for SCADA retrieval.
➤Initiate remedial action sequence based on load
flow before fault conditions.
➤Interlock breakers and disconnect switches.
➤Restrict breaker tripping in excessive duty
situations without additional relays.
➤Hold momentary change-of-state conditions for
SCADA polling.
Metering and Monitoring
Access a range of useful information in the relay with the
metering function. Metered quantities include fundamen-
tal primary and secondary current and voltage magni-
tudes and angles for each terminal. RMS voltage and
current metering is also provided. Fundamental phase
and real and reactive power, per-phase voltage magni-
tude, angle, and frequency are displayed in the metering
report for applications that use the relay voltage inputs.
Table 3 SELOGIC Control Equation Operators
Operator Type Operators Comments
Boolean AND, OR, NOT Allows combination of measuring units.
Edge Detection F_TRIG, R_TRIG Operates at the change of state of an internal function.
Comparison >, , =, <=, <, < >
Arithmetic +, –, *, / Uses traditional math functions for analog quantities in an easily programmable equation.
Numerical ABS, SIN, COS, LN, EXP,
SQRT, LOG
Precedence Control ( ) Allows multiple and nested sets of parentheses.
Comment #, (* *) Provides for easy documentation of control and protection logic.
=>>SET T <Enter>
1: PMV01,THETA
(assign the alias “THETA” to math variable PMV01)
2: PMV02,TAN
(assign the alias “TAN” to math variable PMV02)
=>>SET L <Enter>
1: # CALCULATE THE TANGENT OF THETA
2: TAN:=SIN(THETA)/COS(THETA)
(use the aliases in an equation)
Table 4 Metering Capabilities (Sheet 1 of 2)
Capabilities Description
Instantaneous Quantities
Voltages
VA, B, C (V, Z), V3V0, V1, 3V2
Voltages measured at the fundamental frequency of the power system. The relay com-
pensates for delta-connected CTs when reporting primary values.
RMS Voltages
VA, B, C (V, Z), V
RMS voltages include fundamental plus all measurable harmonics.

SEL-487E Data Sheet Schweitzer Engineering Laboratories, Inc.
20
Event Reporting and SER
Event reports and SER features simplify post-fault analy-
sis and help improve your understanding of both simple
and complex protective scheme operations. These fea-
tures also aid in testing and troubleshooting relay settings
and protective schemes.
Oscillography and Event Reporting
In response to a user-selected internal or external trigger,
the voltage, current, and element status information con-
tained in each event report confirms relay, scheme, and
system performance for every fault. The relay provides
sampling rates as fast as 8 kHz for analog quantities in a
COMTRADE file format, as well as eight-sample-per-
cycle and four-sample-per-cycle event reports. The relay
stores as much as 3 seconds of 8 kHz event data. The
relay supports inclusion of user-configurable analogs in
the events. Reports are stored in nonvolatile memory.
Relay settings operational in the relay at the time of the
event are appended to each event report.
Each relay provides event reports for analysis with soft-
ware such as SEL-5601-2 SYNCHROWAVE®Event Soft-
ware. With SYNCHROWAVEEvent, you can display
events from several relays to make the fault analysis eas-
ier and more meaningful. Because the different relays
time-stamp the events with values from their individual
clocks, be sure to time synchronize the relay with an
IRIG-B clock input or PTP source to use this feature.
Compensated Fundamental Currents
IA, B, C (S, T, U, W, X, Y), 3I0, I1, 3I2
IA, B, C (ST, TU, UW, WX), 3I0, I1, 3I2
Currents measured at the fundamental frequency of the power system with transformer
phase-compensation applied.
RMS Currents
IA, B, C (S, T, U, W, X, Y)
IA, B, C (ST, TU, UW, WX)
RMS currents include fundamental plus all measurable harmonics.
Differential Metering
Currents
IA, B, C, I1, 3I2, 3I0
Local terminal/all
Remote Terminals
Differential Current
IA, B, C, I1, 3I2, 3I0
Local terminal/all
Remote terminals
Alpha Plane
k
alpha
Alpha plane ratio
Alpha plane angle
Power/Energy Metering Quantities
Fundamental Power Quantities
SA, B, C, PA, B, C, QA, B, C (S, T, U, W, X, Y)
SA, B, C, PA, B, C, QA, B, C (ST, TU, UW, WX)
S3, P3, Q3(S, T, U, W, X, Y)
S3, P3, Q3(ST, TU, UW, WX)
Power quantities calculated using fundamental voltage and current measurements;
S = MVA, P = MW, Q = MVAR.
Differential Metering
Differential
IOPA, IOPB, IOPC, IRTA, IRTB, IRTC
IOPA2, IOPB2, IOPC2, IRTA2, IRTB2,
IRTC2
IOP, Zone 1 operate current magnitude (per unit).
IRT, Zone 1 restraint current magnitude (per unit).
IOP2, Zone 2 operate current magnitude (per unit).
IRT2, Zone 2 restraint current magnitude (per unit).
Harmonics
2nd: IOPAF2, IOPBF2, IOPCF2
4th: IOPAF4, IOPBF4, IOPCF4
5th: IOPAF5, IOPBF5, IOPCF5
Zone 1 differential harmonic quantities represent the effective harmonic content of the
operate current. This content is what the relay uses for harmonic blocking and harmonic
restraint.
Demand/Peak Demand Metering
IA, B, C, 3I2, 3I0 (S, T, U, W, X, Y)
IA, B, C, 3I2, 3I0 (ST, TU, UW, WX)
IMAX (S, T, U, W, X, Y)
IMAX (ST, TU, UW, WX)
Thermal or rolling interval demand.
Table 4 Metering Capabilities (Sheet 2 of 2)
Capabilities Description
Table of contents
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