Post on 25-Jan-2021
transcript
g GE Power Management
UR - The Universal Relay
URUR Features Features
• FAMILY of relays built on a common platform
– Common “look & feel” for ease of use product to product
– All “bells & whistles”, present and future, available to whole
family
– Reduced training time and drafting costs
• MODULAR architecture
– Scaleable - accommodates a scaleable I/O architecture
– Flexible - accommodates different types of I/O
– Upgradeable - accommodates upgrading to new technologies
• FAMILY of relays built on a common platform
– Common “look & feel” for ease of use product to product
– All “bells & whistles”, present and future, available to whole
family
– Reduced training time and drafting costs
• MODULAR architecture
– Scaleable - accommodates a scaleable I/O architecture
– Flexible - accommodates different types of I/O
– Upgradeable - accommodates upgrading to new technologies
g GE Power Management
URUR Features Features
• COMMUNICATIONS
– High-speed networking capability (Ethernet - fiber, redundancy)
– Multiple Protocols - UCA 2.0, DNP 3.0, Modbus, IEC-870-101
• SUBSTATION Automation - System Solution
– PMCS + UR with UCA 2.0 MMS/Ethernet
• COMMUNICATIONS
– High-speed networking capability (Ethernet - fiber, redundancy)
– Multiple Protocols - UCA 2.0, DNP 3.0, Modbus, IEC-870-101
• SUBSTATION Automation - System Solution
– PMCS + UR with UCA 2.0 MMS/Ethernet
g GE Power Management
Software IssuesSoftware Issues
• Software accounts for 90% of digital relay design
• Most support functions are required in all types of relays
• Market needs are driving shorter development cycles
• Software accounts for 90% of digital relay design
• Most support functions are required in all types of relays
• Market needs are driving shorter development cycles
g GE Power Management
Solution: Modular SoftwareSolution: Modular Software
Modular SoftwareModular Software
‘Object Oriented Design’
allows for scalable,flexible and re-useablesoftware and features
Protection Class
•TOC
•IOC
•Distance
•Differential
•Frequency
•Volts/Hz
•etc
Objects
g GE Power Management
Hardware IssuesHardware Issues
• Microprocessor / Integrated Circuit Functionalityis increasing exponentially
• Components can become obsolete in 1 to 2 years
• Utility expect a 20+ year life
• Microprocessor / Integrated Circuit Functionalityis increasing exponentially
• Components can become obsolete in 1 to 2 years
• Utility expect a 20+ year life
g GE Power Management
Solution: Modular Hardware DesignSolution: Modular Hardware Design
Modular Hardware DesignModular Hardware Design
Concept
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Physical Realization
Common PlatformCommon Platform
• Common hardware modules
• Common software modules
• Capability to run a wide varietyof applications
• Result: Universal Relay (UR)
Application Software
Transformer
Application
Line
ApplicationGenerator
Application
Feeder
Application
Control (PLC)
Application
g GE Power Management
HardwareHardware
• Flash memory
• Draw-out modules forserviceability
• Expandable I/O
• Field upgradable
• Flash memory
• Draw-out modules forserviceability
• Expandable I/O
• Field upgradable
g GE Power Management
HardwareHardware
g GE Power Management
• 4RU, 19 inch rack-mount chassis
• Hinged faceplate allows easy access to modules
• Faceplate can be mounted separately on doors forapplications limited in depth
• Extension cable connects faceplate to main unit
Configurable I/O via sub-modules
Sub-Modules
Hardware - Modular I/OHardware - Modular I/O
g GE Power Management
Modular design allows all modules to be easilyinserted or removed for upgrading or repair.Field wiring is left undisturbed
Draw-Out ModulesDraw-Out Modules
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Hardware - Interfaces Hardware - Interfaces
CONTACT INPUTS (expandable)
Configurable inputs may be used for:
– Breaker status
– Oscillography trigger
– Control inputs
CONTACT INPUTS (expandable)
Configurable inputs may be used for:
– Breaker status
– Oscillography trigger
– Control inputs
g GE Power Management
CONTACT OUTPUTS (expandable)
Fully programmable
– Trip rated Form-A relays
– Form-C relays
– Fast Form-C relays
CONTACT OUTPUTS (expandable)
Fully programmable
– Trip rated Form-A relays
– Form-C relays
– Fast Form-C relays
User Interfaces User Interfaces
PROGRAM UPDATING
– Flash memory storageof firmware for field
updating viacommunications port.
Enables productupdating on-site forlatest features
PROGRAM UPDATING
– Flash memory storageof firmware for field
updating viacommunications port.
Enables productupdating on-site forlatest features
g GE Power Management
COMMUNICATIONS
– Modbus RTU onRS485 @ 115 kbps
– MMS/UCA 2.0 onRedundant 10BaseF
COMMUNICATIONS
– Modbus RTU onRS485 @ 115 kbps
– MMS/UCA 2.0 onRedundant 10BaseF
POWERFUL PROCESSORS
Numerical data processingusing a 32 bit CPU and
DSP for high speedcomplex task processing
POWERFUL PROCESSORS
Numerical data processingusing a 32 bit CPU and
DSP for high speedcomplex task processing
FlexLogic minimizes the requirement for auxiliary components andwiring while making more complex schemes possible.
FlexLogicFlexLogic
URPC
g GE Power Management
Virtual Inputs / Outputsextend the I/O capability of the
relay to LAN communications.
Virtual Inputs / OutputsVirtual Inputs / Outputs
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• Networkable
• Peer to peercommunications
• Self-defining data
• External dataaccess viacorporate WAN
Peer to Peer CommunicationsPeer to Peer Communications
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MeteringMetering
• Current (Phase, Neutral and Ground) -Accuracy: ± 0.25% of reading or ± 0.1% of rating from 0.1 to 2.0 x
CT rating (whichever is greater)
• Voltage (Vab Vbc Vca Van Vbn Vcn) -Accuracy: ± 0.25% of reading from 10 to 208 V
• Apparent Power (VA) - Accuracy: ± 1.0% of reading
• Real Power (Watts) - Accuracy: ± 1% of reading
• Reactive (Vars) - Accuracy: ± 1%
• Power Factor - Accuracy: ± 0.02
• Current (Phase, Neutral and Ground) -Accuracy: ± 0.25% of reading or ± 0.1% of rating from 0.1 to 2.0 x
CT rating (whichever is greater)
• Voltage (Vab Vbc Vca Van Vbn Vcn) -Accuracy: ± 0.25% of reading from 10 to 208 V
• Apparent Power (VA) - Accuracy: ± 1.0% of reading
• Real Power (Watts) - Accuracy: ± 1% of reading
• Reactive (Vars) - Accuracy: ± 1%
• Power Factor - Accuracy: ± 0.02
g GE Power Management
MonitoringMonitoring
• Oscillography– 64 samples / power frequency cycle
– Adjustable Memory (1 record / 128 cycles to 31 records / 8 cycles)
– 6 Analog, 15 digital channels can be displayed
– Selectable triggers
– Adjustable trigger position
• Event Recorder– 1024 events, events are date and time stamped to nearest millisecond
– Selection of points to monitor (pickup, operation, logic, I/O)
g GE Power Management
ConnectivityConnectivity
•• Communications– Protocols
– Peer to Peer Communications
•• URPC™
•• Integration
g GE Power Management
CommunicationsCommunications
PROTOCOLS
• Modbus RTU protocol
– Standard Front Port: RS232
– Rear Port: RS485 up to 115kbps
• UCA2 protocol– Application: MMS
– Physical: 10BaseT (Ethernet) or 10BaseF (Fiber Optic)
– Transport layer ISO-OSI and TCP/IP
PROTOCOLS
• Modbus RTU protocol
– Standard Front Port: RS232
– Rear Port: RS485 up to 115kbps
• UCA2 protocol– Application: MMS
– Physical: 10BaseT (Ethernet) or 10BaseF (Fiber Optic)
– Transport layer ISO-OSI and TCP/IP
g GE Power Management
URPC Program FeaturesURPC Program Features
• View actual values
• View/edit setting on-line
• View Event Recorder for
troubleshooting
• Upgrade relay firmware
programming
• View relay Status
• View/edit setting off-line with
setting file manager
• On-line instruction manual
• Download & view oscillography
in Comtrade format
Windows 95/ NT Based SoftwareWindows 95/ NT Based Software
g GE Power Management
The three main types of data - Snapshot data, Oscillographic data, and
Settings data - can be accessed from this screen, the Event recorder.
Snapshot Data
Oscillographic Data
Settings Change Data
Event Recorder Capture ScreenEvent Recorder Capture Screen
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Snapshot DataSnapshot Data
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OscillographicOscillographic Data Data
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Settings Change DataSettings Change Data
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UR Relay TypesUR Relay Types
g GE Power Management
•• F30 Feeder Management Relay (9/98)• L90 Line Current Differential (11/98)• C30 Controller/Metering (2/99)• C60 Controller/Metering/Breaker Failure (4/99)• F60 Feeder Management Relay (4/99)• T60 Transformer Management relay (4/99)• D60 Line Distance Relay (5/99)• L60 Line Current Phase Comparison Relay (6/99)
Staged release of enhancements to platform andindividual relay models
Substation AutomationSubstation Automation
g GE Power Management
The UR Relay is the Engine for Substation Automation
g GE Power Management
UR - The Universal Relay
g GE Power Management
UR L90 Line Differential Relay
An integrated transmission line protection
system for series compensated lines
g GE Power Management L90 Line Differential Relay
The second Relay designed from the ground
up around the MMS/UCA 2TM Ethernet
communications standard. Giving you the
flexibility, connectivity and power to manage
your facility.
Connectivity
� ModBus RTU
� MMS/UCA2TM Protocols
� SI Compatibility
Flexibility
� FlexCurves
� FlexLogic
� FlexModules
� Other Features
Power to Protect Your LinesPower to Protect Your Lines
gGE Power Management
Presentation OverviewPresentation Overview
� Applications� Protection and Control� New & Unique Concepts� User Interfaces� Order Codes
L90 Line Differential Relay
ApplicationsApplications
The L90 is a digital current differential relay systemintended to provide complete protection fortransmission lines of any voltage level.
�Overhead Lines and Cables�Lines with 2 Terminals�EHV, HV, Sub-Transmission�With/ without Series Compensation
g GE Power Management L90 Line Differential Relay
Transmission LineTransmission Line
Protection & Metering Protection & Metering
g GE Power Management L90 Line Differential Relay
Protection & Control FunctionsProtection & Control Functions
�Current Differential with Adaptive Restraint�High Speed Tripping, 1/2 - 2 cycles�Backup Overcurrent�Direct Transfer Trip�Stub Bus Protection
g GE Power Management L90 Line Differential Relay
Current Differential SchemeCurrent Differential Scheme
�Similar to a Percentage Restraint Scheme�Adaptive Statistical Restraint�Adaptive Based on Relay Measurements�More Accurate and Sensitive Fault Sensing�Detects High Impedance Single Line to Ground Faults that Existing Systems may not Detect
g GE Power Management L90 Line Differential Relay
New & Unique ConceptsNew & Unique Concepts
� Data Consolidation� Restraint Characteristic� Sampling Synchronization
g GE Power Management L90 Line Differential Relay
Three key technical considerations in
designing a new current differential relay:
Data ConsolidationData Consolidation
� Balance between transient response and bandwidth � Phase consolidation:
– Phase current information is combined
– Faulted phase information is lost
– L90 does not use phase consolidation
� Time consolidation:– Reduces communication bandwidth requirements
– Improves security caused by single corrupted data sample
– L90 uses time consolidation
g GE Power Management L90 Line Differential Relay
Extract appropriate parameters to be transmitted
from raw samples of transmission line currents
Phaselets Phaselets ConceptConcept
g GE Power Management L90 Line Differential Relay
0 16 32 48 64 80 96 112 128 144 160 176 192 208 2246
4
2
0
2
4
65
-5
fy ( )n
2240 n1
2
3
4
5
6
7
89
1
0 1
1 1
2 1
3 1
4 1
5 1
6Full Cycle Window
= 8 Phaselets
Phaselet
( 1/8 cycle)
Disturbance Detector
50DD
Disturbance Detector
50DD
Phaselets Phaselets Concept - Concept - PrefaultPrefault
g GE Power Management L90 Line Differential Relay
+X
-X
+R
1st Pre-Fault Phaselet:
Disturbance Detector resets
calculation window.
Area of
uncertainty
+X
-X
+R+X
-X
+R
-X
+R
+X
Full Cycle
Pre-Fault Phasor
(No uncertainty)
Phaselet 1
Phaselet 4
Phaselet 6
Phaselet 8
Phaselets Phaselets Concept - FaultConcept - Fault
g GE Power Management L90 Line Differential Relay
-X
+R
+X
1st Fault Phaselet:
Disturbance Detector resets
calculation window.
+X
-X
+R +X
-X
+R
-X
+R
+X
Full Cycle
Fault Phasor
(No uncertainty)
Phaselet 9
Phaselet 12
Phaselet 14
Phaselet 16
Phaselets Phaselets Concept - FaultConcept - Fault
g GE Power Management L90 Line Differential Relay
Phaselet Simulation on ‘Noisy’ Waveform
0 8 16 24 32 40 48 56 64 72 80 88 96 104 112 120 128
0f( )n
n
Sinusoid with random white Gaussian noise.
Phaselets Phaselets Concept - FaultConcept - Fault
g GE Power Management L90 Line Differential Relay
0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 160
0.2
0.4
0.6
0.8
1
1.2
1.4
1.6
1.8
2
2.2
2.4
maxmagw
minmagw
w
Decreasing
‘area of uncertainty’
(or variance error) as
phaslet window size
increases.
Convergence
of uncertainty area
to equivalent of full cycle
Fourier Transform.
Phaselets improve operating speed while maintaining security.
Phaselet Simulation on ‘Noisy’ Waveform
Restraint CharacteristicRestraint Characteristic
g GE Power Management L90 Line Differential Relay
Classic Dual-Slope Restraint Characteristic
Protected
Element
I1 I2
Iop = | I1 + I2 |
Ioperate = Iop = | I1 + I2 |
Irestraint = Ir = K [ |I1| + |I2|]
Ioperate
Irestraint
K1
K2
Restraint CharacteristicRestraint Characteristic
g GE Power Management L90 Line Differential Relay
Classic Dual-slope Characteristic L90 - Adaptive Elliptical Restraint Im
Re
Iop
Dynamic restraint region
based on magnitude of
the variance error
measurement (i.e. the
difference between the
actual values measured
and the estimated data
from the Fourier
Transform calculation)
When the waveform is
distorted due to CT
saturation, harmonic
content, or fault initiation
transients, the restraint
region will grow larger.
Static restraint
region formed by
classic method
Im
Re
IopIr
L90 combines the classic method with adaptive elliptical
restraint to improve both security and dependability.
Sampling SynchronizationSampling Synchronization
g GE Power Management L90 Line Differential Relay
• Clocks are synchronized to each other (no master clock)• Phases are synchronized to each other
– Primary source is current measurements
– Secondary source is time tagged messages (ping-pong)
– Timing error is driven to zero
– Phase angle deviations are minimized (
Sampling SynchronizationSampling Synchronization
g GE Power Management L90 Line Differential Relay
Current differential requires both relays to be in
time synchronization for differential calculations.Tx
Rx
Rx
Tx
L90
#1
L90
#2
Communications
Channel
t0
t3
t2
t1
tf
tr
tf = forward travel time
tr = return travel time
tf = tr = t3 - t0 - (t2 - t1) 2
“Ping-Pong”
Synchronization
Technique:
Traditional “Ping-Pong”
synchronization technique assumes
forward time delay (tf) is equal to
the return travel time (tr). This is
NOT the case for communications
equipment found in the
utility/industrial environment.
Sampling SynchronizationSampling Synchronization
g GE Power Management L90 Line Differential Relay
• Minimizes variance on channel delays and jitter by averaging
• “Ping-Pong” calculations
• Implements a DPLL (digital phase-locked-loop) allowing the
Ping-Pong algorithm to stabilize to new path delays.
• Calculates phase error at each end due to channel delays and
compensates clocks at both ends
L90 Improvements on “Ping-Pong” Synchronization scheme:
FlexibilityFlexibility
�� Relay Channels
� FlexCurvesTM
�� FlexLogicTM
�� FlexModulesTM
� Metering and Monitoring
g GE Power Management L90 Line Differential Relay
Relay ChannelsRelay Channels
g GE Power Management L90 Line Differential Relay
• 820 nm Multi-mode Fiber (LED)
• 1300 nm Multi-mode Fiber (LED)
• 1300 nm Single-mode Fiber (ELED)
• 1300 nm Single-mode Fiber (Laser)
• G.703 (April 99)
• RS422 (April 99)
Two Terminal Communication Channels
Three Terminal Available in April ‘99
Typical application of
FlexCurves:
When the protectioncurves used for lateral taps2 and 3 differ; customFlexCurves can beconstructed to coordinatewith both.
FlexCurvesFlexCurves
g GE Power Management L90 Line Differential Relay
MonitoringMonitoring
�� Fault Location
� IRIG-B Time Synchronization
�� CT Failure/Current Unbalance� Trip Circuit Monitors� Channel Monitor� Test Features
– Local loopback for channel
– Manual test mode
– Playback of oscillography files
g GE Power Management L90 Line Differential Relay
PROTECTIVE COVER
� Protects keypad when not in use� Can be fitted with a seal
RESET KEY
� Clears event, EVENT CAUSE LED
� indicators, and latched alarms
User InterfacesUser Interfaces
g GE Power Management L90 Line Differential Relay
STATUS INDICATORS
IN SERVICE: The relay is operating normally
TROUBLE: Self-test detected a problem
TEST MODE: The relay is in test mode
TRIP: A trip command had been issued
ALARM: An alarm condition is present
PICKUP: Pickup condition detected
RS232 SERIAL PORT
� Connect to a PC to run URPC
� Use for downloading settings, monitoring
data, sequence of events reports, Oscillography
User InterfacesUser Interfaces
g GE Power Management L90 Line Differential Relay
EVENT CAUSE LED INDICATORS
VOLTAGE: Event caused by voltage
CURRENT: Event caused by current
FREQUENCY: Not applicable
OTHER: Not applicable
PHASE A Indicates which
PHASE B phase was
PHASE C involved
NEUTRAL/GROUND
RS232 SERIAL PORT
� Connect to a PC to run URPC
� Use for downloading settings, monitoring
data, sequence of events reports, Oscillography
User InterfacesUser Interfaces
g GE Power Management L90 Line Differential Relay
DISPLAY
� 40 character vacuum fluorescent display
� Visible in dim lighting or at any angle
� Used for programming, monitoring, status,
fault diagnosis, user programmable
messages and settings
KEYPAD
� Numerical keypad and command keys
allow full access to the relay
� Rubber keypad is dust tight and
splash-proof with door
� Website address via HELP for technical
support
G E P O W E R M A N A G E M E N TR E L A Y
MENU
HELP
ESCAPE
ENTER
MESSAGE
VALUE
User InterfacesUser Interfaces
g GE Power Management L90 Line Differential Relay
CONTACT INPUTS (Expandable)Configurable inputs may be used for:
� Breaker status
� Oscillography trigger
� Control inputs
CONTACT OUTPUTS (Expandable)
� Trip rated Form-A relays� Form-C relays that may be programmed for
� auxiliary functions
User InterfacesUser Interfaces
g GE Power Management L90 Line Differential Relay
COMMUNICATIONS� ModBus® RTU on RS485 @
115 kbps
� MMS/UCA 2.0 on Redundant
10BaseF
POWERFUL PROCESSORSNumerical data processing using a
32 bit CPU and DSP for high speed
complex task processing
PROGRAM UPDATINGFlash memory storage of firmware for field
updating via communications port. Enables
product updating on-site for latest features.
User InterfacesUser Interfaces
g GE Power Management L90 Line Differential Relay
Order CodeOrder Code
L90 - * 00 - H C * - F ** - H * * - L * *- N* *- S**- U**- W**
g GE Power Management L90 Line Differential Relay
Base Unit L90 Base Unit
CPU A RS485 + RS485
C RS485 + 10BaseF
D RS485 + Redundant 10BaseF
Software Options 00 No software options
Mounting H Horizontal
Faceplate C Faceplate with keypad and display
Power Supply L 24/48 V (Low); 19-60 VDC, 19-81 VAC
H 125/250 V (High); 88-300 VDC, 70-265 VAC
CT/VT 8A Standard 4CT/4VT
Digital I/O XX No module
6G 4 Form-A, 8 inputs
6I 4 SCR outputs, 16 inputs
Digital I/O 6A 6A 6A 6A 2 Form-A, 2 Form-C, 8 inputs
6B 6B 6B 6B 2 Form-A, 2 Form-C, 4 inputs
6C 6C 6C 6C 8 Form-C outputs
6D 6D 6D 6D 16 Inputs
6E 6E 6E 6E 4 Form-C, 8 inputs
6F 6F 6F 6F 4 Form-A, 8 inputs
6G 6G 6G 6G 8 Fast Form-C outputs
6H 6H 6H 6H 4 Form-A, 8 inputs
6I 6I 6I 6I 6 Form-A, 4 inputs
6J 6J 6J 6J 4 SS SCR outputs, 8 inputs
6K 6K 6K 6K 4 Form-C, 4 Fast Form-C
Inter-Relay Communications 7A 820 nm, multi-mode, LED, 2 Terminal
7B 1300 nm, multi-mode, LED, 2 Terminal
7C 1300 nm, single-mode, ELED, 2 Terminal
7D 1300 nm, single-mode, LASER, 2 Terminal
7R G.703 2 Terminal
7T RS422 2 Terminal
g GE Power Management
UR L90 Line Differential Relay
An integrated transmission line protection
system for series compensated lines