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Transcript of G GE Power Management UR - The Universal Relay. UR Features FAMILY of relays built on a common...
gGE 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
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Solution: Modular SoftwareSolution: Modular Software
Modular SoftwareModular Software
‘Object Oriented Design’ allows for scalable, flexible and re-useable software and features
Protection Class•TOC•IOC•Distance•Differential•Frequency•Volts/Hz•etc
Obj
ects
g GE Power Management
Hardware IssuesHardware Issues
• Microprocessor / Integrated Circuit Functionality is increasing exponentially
• Components can become obsolete in 1 to 2 years• Utility expect a 20+ year life
• Microprocessor / Integrated Circuit Functionality is 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 Modular Hardware DesignDesign
Concept
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Physical Realization
Common PlatformCommon Platform
• Common hardware modules• Common software modules• Capability to run a wide
variety of applications• Result: Universal Relay (UR)
Application Software
TransformerApplication
Line Application
Generator Application
FeederApplication
Control (PLC)Application
g GE Power Management
HardwareHardware
• Flash memory• Draw-out modules for
serviceability• Expandable I/O• Field upgradable
• Flash memory• Draw-out modules for
serviceability• Expandable I/O• Field upgradable
g GE Power Management
Hardware Hardware
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• 4RU, 19 inch rack-mount chassis• Hinged faceplate allows easy access to modules• Faceplate can be mounted separately on doors
for applications 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 easily inserted or removed for upgrading or repair. Field wiring is left undisturbed
Draw-Out ModulesDraw-Out Modules
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Hardware - InterfacesHardware - 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 InterfacesUser Interfaces
PROGRAM UPDATING– Flash memory
storage of firmware for field updating via communications port. Enables product updating on-site for latest features
PROGRAM UPDATING– Flash memory
storage of firmware for field updating via communications port. Enables product updating on-site for latest features
g GE Power Management
COMMUNICATIONS – Modbus RTU on
RS485 @ 115 kbps– MMS/UCA 2.0 on
Redundant 10BaseF
COMMUNICATIONS – Modbus RTU on
RS485 @ 115 kbps– MMS/UCA 2.0 on
Redundant 10BaseF
POWERFUL PROCESSORS Numerical data
processing using a 32 bit CPU and DSP for high speed complex task processing
POWERFUL PROCESSORS Numerical data
processing using a 32 bit CPU and DSP for high speed complex task processing
FlexLogic minimizes the requirement for auxiliary components and wiring while making more complex schemes possible.
FlexLogicFlexLogic
URPC
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Virtual Inputs / Outputs extend the I/O capability of the relay to LAN communications.
Virtual Inputs / OutputsVirtual Inputs / Outputs
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• Networkable• Peer to peer
communications• Self-defining data• External data
access via corporate 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
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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)
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ConnectivityConnectivity
• Communications– Protocols– Peer to Peer Communications
• URPC™• Integration
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CommunicationsCommunications
PROTOCOLS• Modbus RTU protocol
– Standard Front Port: RS232– Rear Port: RS485 up to 115kbps
• UCA2protocol– 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
• UCA2protocol– Application: MMS– Physical: 10BaseT (Ethernet) or 10BaseF (Fiber Optic) – Transport layer ISO-OSI and TCP/IP
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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
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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 Event Recorder Capture ScreenScreen
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Snapshot DataSnapshot Data
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Oscillographic DataOscillographic Data
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Settings Change DataSettings Change Data
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UR Relay TypesUR Relay Types
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• 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 and individual relay models
Substation AutomationSubstation Automation
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The UR Relay is the Engine for Substation Automation
gGE Power Management
UR - The Universal Relay
gGE 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 Power to Protect Your LinesLines
g GE Power Management
Presentation Presentation OverviewOverview
Applications Protection and Control New & Unique Concepts User Interfaces Order Codes
L90 Line Differential Relay
ApplicationsApplications
The L90 is a digital current differential relay system intended to provide complete protection for transmission lines of any voltage level.
Overhead Lines and CablesLines with 2 TerminalsEHV, HV, Sub-TransmissionWith/ 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 RestraintHigh Speed Tripping, 1/2 - 2 cyclesBackup OvercurrentDirect Transfer TripStub Bus Protection
g GE Power Management L90 Line Differential Relay
Current Differential Current Differential SchemeScheme
Similar to a Percentage Restraint SchemeAdaptive Statistical RestraintAdaptive Based on Relay MeasurementsMore Accurate and Sensitive Fault SensingDetects 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 ConceptPhaselets Concept
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 n12
34
56
78
910 1
1 12 1
3 14 1
5 16
Full Cycle Window= 8 Phaselets
Phaselet( 1/8 cycle)
Disturbance Detector50DD
Disturbance Detector50DD
Phaselets Concept - Phaselets Concept - PrefaultPrefault
g GE Power Management L90 Line Differential Relay
+X
-X
+R
1st Pre-Fault Phaselet:
Disturbance Detector resetscalculation window.
Area ofuncertainty
+X
-X
+R+X
-X
+R
-X
+R
+X
Full CyclePre-Fault Phasor(No uncertainty)
Phaselet 1
Phaselet 4
Phaselet 6
Phaselet 8
Phaselets Concept - Phaselets Concept - FaultFault
g GE Power Management L90 Line Differential Relay
-X
+R
+X
1st Fault Phaselet:
Disturbance Detector resetscalculation window.
+X
-X
+R +X
-X
+R
-X
+R
+X
Full CycleFault Phasor
(No uncertainty)
Phaselet 9
Phaselet 12
Phaselet 14
Phaselet 16
Phaselets Concept - Phaselets Concept - FaultFault
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 Concept - Phaselets Concept - FaultFault
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) asphaslet window size increases.
Convergenceof uncertainty areato equivalent of full cycleFourier 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
ProtectedElement
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 Sampling SynchronizationSynchronization
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 (<0.6 degree)
• Clocks are synchronized to the power system frequency
– Eliminates one source of error in phasor measurements• Loop filter adjusts clock frequency
– Uses frequency and phase angle deviation
L90 uses distributed clock synchronization
Sampling Sampling SynchronizationSynchronization
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
CommunicationsChannel
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 Sampling SynchronizationSynchronization
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 protection curves used for lateral taps 2 and 3 differ; custom FlexCurves can be constructed to coordinate with 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 INDICATORSIN SERVICE: The relay is operating normallyTROUBLE: Self-test detected a problemTEST MODE: The relay is in test modeTRIP: A trip command had been issuedALARM: An alarm condition is presentPICKUP: 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 INDICATORSVOLTAGE: Event caused by voltageCURRENT: Event caused by currentFREQUENCY: Not applicableOTHER: Not applicablePHASE A Indicates whichPHASE B phase wasPHASE 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
GE POWER MANAGEMENT
RELAY
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 fieldupdating via communications port. Enablesproduct updating on-site for latest features.
User InterfacesUser Interfaces
g GE Power Management L90 Line Differential Relay
Order CodeOrder CodeL90 - * 00 - H C * - F ** - H * * - L * *- N* *- S**- U**- W**
g GE Power Management L90 Line Differential Relay
Base Unit L90 Base UnitCPU A RS485 + RS485
C RS485 + 10BaseF D RS485 + Redundant 10BaseF
Software Options 00 No software optionsMounting H HorizontalFaceplate C Faceplate with keypad and displayPower Supply L 24/48 V (Low); 19-60 VDC, 19-81 VAC
H 125/250 V (High); 88-300 VDC, 70-265 VACCT/VT 8A Standard 4CT/4VTDigital I/O XX No module 6G 4 Form-A, 8 inputs
6I 4 SCR outputs, 16 inputsDigital 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
gGE Power Management
UR L90 Line Differential Relay
An integrated transmission line protection system for series compensated lines