Relion 615 series Line Differential Protection and Control RED615 Ver. 2.0 Technical Presentation

Transcription

1 Relion 615 series Line Differential Protection and Control RED615 Ver. 2.0 Technical Presentation ABB Oy Distribution Automation July 1, MRS B Slide 1

2 Contents RED615 Technical Presentation highlights July 1, 2009 Slide 2

3 July 1, 2009 Slide 3

4 Relion 615 series RED615 RED615 is a member of ABB s Relion product family and part of its 615 protection and control product series The 615 series IEDs are characterized by their compactness and withdrawable design Other members of the 615 product series: REF615 REM615 RET615 July 1, 2009 Slide 4

5 Description RED615 is a phase-segregated two-end line differential protection and control IED (intelligent electronic device) designed for utility and industrial power systems, including looped and meshed distribution networks with or without decentralized power generation July 1, 2009 Slide 5

6 Selective protection for a dedicated zone Unit protection for applications calling for absolutely selective protection for a dedicated zone Main application area: twoterminal protection for cable or overhead line feeders Phase segregated protection algorithm Protection communication using a dedicated optical link Designed for IEC July 1, 2009 Slide 6

7 A pre-configured IED Three standard configurations available Possibility to add, delete and change signal connections for binary inputs, binary outputs and between function blocks using PCM600 The number and type of function blocks is fixed July 1, 2009 Slide 7

8 Standard configurations Standard configuration A Line differential protection Standard configuration B Line differential protection with directional earth-fault protection Standard configuration C Line differential protection with non-directional earth-fault protection July 1, 2009 Slide 8

9 Standard configurations, page 1(3) Standard configuration A B C Protection functions Line differential protection and related measurements, stabilized and instantaneous stages Three-phase non-directional overcurrent, low stage, instance 1 Three-phase non-directional overcurrent, high stage, instance 1 Three-phase non-directional overcurrent, high stage, instance 2 Three-phase non-directional overcurrent, instantaneous stage, instance 1 Non-directional earth-fault protection, low stage (SEF), instance Non-directional earth-fault protection, low stage, instance Non-directional earth-fault protection, high stage, instance Non-directional earth-fault protection, instantaneous stage, instance Directional earth-fault protection, low stage (SEF), instance Directional earth-fault protection, low stage, instance Directional earth-fault protection, high stage, instance Transient / intermittent earth-fault protection - - = included, = optional at the time of order July 1, 2009 Slide 9

10 Standard configurations, page 2(3) Standard configuration A B C Protection functions, cont d Non-directional (cross-country) earth-fault protection, using calculated I o - - Negative sequence overcurrent protection, instance 1 Negative sequence overcurrent protection, instance 2 Phase discontinuity protection - Three-phase thermal protection for feeders, cables and distribution transformers - Binary signal transfer Circuit-breaker failure protection Three-phase inrush current detector Master trip, instance 1 Master trip, instance 2 Control functions Circuit-breaker control Disconnector position indication, instance 1 Disconnector position indication, instance 2 = included, = optional at the time of order July 1, 2009 Slide 10

11 Standard configurations, page 3(3) Standard configuration A B C Control functions, cont d Disconnector position indication, instance 3 Earthing switch indication Auto-reclosing - O O Condition monitoring Circuit-breaker condition monitoring - Trip circuit supervision, instance 1 Trip circuit supervision, instance 2 Current circuit supervision Protection communication supervision Measurement Disturbance recorder Three-phase current measurement Sequence current measurement Residual current measurement - Residual voltage measurement - - = included, = optional at the time of order July 1, 2009 Slide 11

12 July 1, 2009 Slide 12

13 Why line differential protection? Application examples Case Overcurrent protection challenges Solution Fault current contribution from more than one source (direction) Protection co-ordination Varying fault current levels Load currents magnitudes close to fault current levels Selective protection scheme still required Protection co-ordination based on definite or inverse time delays might result in too high accumulated time delays within the chain of protection devices Difficult to find protection setting parameters that would suit all cases Difficult to separate fault conditions from normal loading RED615 RED615 RED615 RED615 July 1, 2009 Slide 13

14 Line differential protection application examples Application examples Parallel feeders Looped feeder construction Doubled feeders Two interconnected feeders between a primary substation Reserve connections or meshed type of network Distributed generation Power generation at the remote end of the feeder Weak grid supplying relatively long distribution lines July 1, 2009 Slide 14

15 Unit protection with overcurrent back-up protection Application examples The phase currents of CT core #2 are summated externally to the IED, and used as CT supervision (MCS3I) reference current The two lowest overcurrent stages are used for remote back-up protection The two highest overcurrent stages are blocked under normal conditions and released in case of protection communication failure Binary signal transfer, 8 signals for user definable purpose (BST) Protection communication supervision (PCS) Standard configuration A July 1, 2009 Slide 15

16 Unit protection with directional earth-fault protection Application examples Standard configuration B The cable CT I 0 input is used for directional earth-fault protection and for CT supervision (MCS3I) reference current Non-directional earth-fault protection stage, based on calculated I 0,, for cross-country earthfault protection Auto-reclosing option for overheadlines Thermal overload protection for feeders The two lowest overcurrent stages are used for remote back-up protection Two highest overcurrent stages are blocked under normal conditions and released in case of protection communication failure Binary signal transfer, 8 signals for user definable purpose (BST) Protection communication supervision (PCS) July 1, 2009 Slide 16

17 Unit protection with non-directional earth-fault protection Application examples Standard configuration C The fourth CT (I 0 ) input is used for nondirectional earth-fault protection and for CT supervision (MCS3I) reference current The same phase CT cores can be used for main protection and for earth-fault protection (external summation), but in that case the CT supervision shall not be used Auto-reclosing option for overheadlines Thermal overload protection for feeders The two lowest overcurrent stages are used for remote back-up protection Two highest overcurrent stages are blocked under normal conditions and released in case of protection communication failure Binary signal transfer, 8 signals for user definable purpose (BST) Protection communication supervision (PCS) July 1, 2009 Slide 17

18 615 series Supported ABB solutions, page 1(2) Application examples Supported ABB solutions Station Automation COM600 MicroSCADA Pro Version 3.3 or later 9.2 SP1 or later The 615 series IEDs together with COM600 constitute a genuine IEC solution for reliable power distribution in utility and industrial power systems The native IEC support offer: Fast software based communication Continuous supervision of the integrity of the protection and communication system Inherent flexibility for reconfiguration and upgrades ABB s Connectivity Package concept enables: Streamlining of the system engineering and IED configuration Easy integration with COM600 and MicroSCADA Pro July 1, 2009 Slide 18

19 615 series Supported ABB solutions, page 2(2) Application examples Industrial example The 615 series IEDs complemented with COM600 offer several benefits: Enhanced substation level functionality using the data content of the bay level IEDs A web HMI providing single-line mimic diagrams for switchgear bay solutions COM600 can be used as a local data warehouse for technical documentation and for network data Extensive reporting and analyzing of network fault situations Seamless connectivity to MicroSCADA Pro and System 800xA Utility example July 1, 2009 Slide 19

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21 Hardware modules [X000] module with optional station bus ports [X100] Power supply and binary output module [X110] Binary I/O module [X120] Basic analog input module [X130] Additional binary I/O module (option) July 1, 2009 Slide 21

22 module variants [X000] Line differential protection link: 100BASE-FX with a fibre-optic LC connector, multi mode or single mode Station bus : 100BASE-TX with a RJ-45 connector Serial (RS-485): Screw terminal connector 2-wire or 4-wire connection Serial (ST connector) Glass fibre July 1, 2009 Slide 22

23 Power supply and binary output modules [X100] Power supply : 48 V 250 V DC, 100 V 240 V AC Four power output contacts capable of direct CB operation Two contacts with integrated trip circuit supervision; also to be used with double-pole operation Two signal output contacts (1 changeover, 1 normally open) IRF output for self-supervision signalling July 1, 2009 Slide 23

24 Binary I/O module [X110] 8 binary inputs 6 inputs, grouped in pairs of two 2 inputs, separated (potential free) 4 binary outputs 3 outputs, changeover contacts 1 output, normally open Selectable binary input thresholds ( V DC) July 1, 2009 Slide 24

25 Basic analog input modules [X120] Four analog current inputs (I 0,I L1, I L2, and I L3 ), user selectable 1 A or 5 A I 0 used as current circuit supervision reference current One voltage input U 0 (std. conf B) alt. a fourth binary input with dedicated ground Three binary inputs (common ground), thresholds selectable Both for ring and pin type wire terminals Max. wire 1 x 6 mm 2 or 2 x 2.5 mm 2 July 1, 2009 Slide 25

26 Input / output overview Standard configuration Analog inputs Binary inputs/outputs CT VT BI BO A 4-12 (18) 1) 10 (13) 1) B (17) 1) 10 (13) 1) C 4-12 (18) 1) 10 (13) 1) 1) With optional binary I/O module ( ) July 1, 2009 Slide 26

27 highlights July 1, 2009 Slide 27

28 Line differential protection Stabilized low stage and instantaneous high stage The protection algorithm calculation is performed both in the local and the remote IED Direct intertrip between line ends ensures simultaneous tripping of the local and the remote CB Detection (blocking) for inrush conditions based on the second harmonic Possibility to introduce either definite or inverse time delay for the stabilized low stage July 1, 2009 Slide 28

29 Line differential protection, cont d Small tapped loads can be included inside the LD protection zone LD protection selectivity towards the protections on the LV-side of the power transformer can be achieved by introducing a time delay for the low set stage Faults on the feeder with low fault impedance (=> high fault current) cleared by the high set stage Reach of the instantaneous high stage Reach of the stabilized low stage with inverse time delay July 1, 2009 Slide 29

30 Line differential protection, cont d Current transformer ratio correction factor Maximum ratio difference 1:5 Local and remote current transformers secondary side star-point selection Both end on the busbar side or on the line side (by default) One end on the busbar side and the other end on the line side July 1, 2009 Slide 30

31 Current circuit supervision Comparing calculated I 0 to a measured I 0 (I_REF) from a different core or from a core balance current transformer Will block line differential and negative sequence overcurrent protection by default if the calculated and the measured I 0 values do not match Operation is indicated by an alarm LED Enabled on load current levels Can be switched OFF if required, or if there is no connected reference current measurement July 1, 2009 Slide 31

32 Disturbance recorder 12 analog channels and 64 binary channels Triggering by: Analog or binary channel Manual or periodic command Recording modes: Wave form or trend Selectable sampling rate, 32/16/8 samples per cycle Max 2 X 10 sec using the highest sampling rate and maximum number of recorded channels July 1, 2009 Slide 32

33 Operation traceability Non-volatile memory for: Setting values Configuration Trip lock-out Disturbance recorder data Up to 50 event codes Recorded data of the four latest events with time stamp Operation indications and alarm LEDs show the status of the IED July 1, 2009 Slide 33

34 Self-supervision Continuous monitoring of: Memory circuits (RAM, ROM, EEPROM) CPU operation and program execution Internal supply voltages Internal trip path continuity External trip circuit (TCS) Light sensor inputs software configuration July 1, 2009 Slide 34

35 Control functions Control of one circuit breaker Dedicated push-buttons for opening and closing of the CB Interlocking schemes July 1, 2009 Slide 35

36 Access control Individual user accounts with role-based access control Four access levels: viewer, operator, engineer and administrator level Applies to: Front-panel user interface Web-browser based user interface PCM600 Administrator programmable passwords July 1, 2009 Slide 36

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38 615 series Designed for IEC Native support for IEC communication between devices in substations IEC enables GOOSE (Generic Object Oriented Substation Event) horizontal communication between IEDs RED615 can simultaneously report events to five different clients on the station bus RED615 also supports: Modbus TCP/IP and RTU / ASCII DNP3 TCP/IP and serial IEC July 1, 2009 Slide 38

39 615 series IEC GOOSE communication Network control centre MicroSCADA Pro Station Automation COM600 Station bus IEC Standardized horizontal communication enables interoperability between any IEDs supporting GOOSE communication Used for transmitting binary process data to peer IEDs within a substation Ethernet technology offers a fast and reliable station bus for the transfer of data The publisher-subscriber principle allows the IEDs to send and/or receive time critical data July 1, 2009 Slide 39

40 615 series GOOSE communication benefits Expandability and flexibility: Flexible modifications without changing the wiring between the IEDs No IED I/Os are needed for the transer of data between the IEDs Reduced wiring between the IEDs Possible to add functionality like interlocking schemes between the cubicles in existing switchgear (retrofit) Supervised data transfer (connection and data quality) RED615 meets the GOOSE performance requirements for tripping applications in distribution substations, as defined by the IEC standard July 1, 2009 Slide 40

41 GOOSE - Breaker failure protection IED A GOOSE message On detecting a fault on the outgoing feeder IED B sends a trip command to CB B and initiates the CB failure protection function CB B fails to open The CB failure protection function of IED B sends a trip command to IED A using GOOSE The use of GOOSE communication eliminates the need for dedicated wiring CB failure protection can be added without renewing the wiring and with minimum disturbance to the process IED C IED B July 1, 2009 Slide 41

42 Protection communication IED 2 Fibre optic communication link IED 1 Physical communication link: A dedicated pair of optical single mode or multimode fibres Optical LC Distance: < 2 km (multi mode), 2-20 km (single mode) Protection communication supervision: Continuous supervision of sending and receiving of messages In the event of a communication failure an alarm is issued and the LD protection is blocked July 1, 2009 Slide 42

43 Protection communication, cont d IED 2 Fibre optic communication link IED 1 The communication link is used for both the LD protection communication and the binary signal transfer (BST) The current phasor data, for each phase, is exchanged between the terminals 8 times per cycle (20 ms at 50 Hz) Simultaneous tripping of both the local and the remote circuit breaker 8 user definable binary signals can be transferred between the terminals July 1, 2009 Slide 43

44 Protection synchronisation No external time-synchronization devices (GPS) are needed propagation delay measuring of symmetrical communication links Sampling differential time calculation algorithm Synchro-phasors in common time reference July 1, 2009 Slide 44

45 Binary signal transfer (BST) Binary information transfer between the line ends (the two IEDs located apart from each other) using the protection communication link Typically used for interlocking and intertripping schemes For user definable purposes, (8 signals) duplex communication Fast communication between two RED615 IEDs (< 5 ms) Fully user configurable using the signal matrix tool in PCM600 July 1, 2009 Slide 45

46 Binary signal transfer, example 1 Protection communication BI BSTGGIO Output 1 BSTGGIO Output 1 Output 8 Input 8 Output 8 Input 8 Input 1 BO Input 1 July 1, 2009 Slide 46

47 Binary signal transfer, example 2 Protection communication BI BSTGGIO Output 1 BSTGGIO Output 1 Output 8 Input 8 Block Output 8 Input 8 I> Input 1 PHLPTOC Input 1 July 1, 2009 Slide 47

48 Binary signal transfer, example 3 Protection communication Start BSTGGIO Output 1 BSTGGIO Output 1 3I> PHLPTOC Output 8 Input 8 Block Output 8 Input 8 3I>> Input 1 PHHPTOC 1 Input 1 July 1, 2009 Slide 48

49 Supported station communication protocols Interfaces / Protocols Ethernet (RJ-45) Serial (RS-485 / RS-232) + IRIG-B Serial (fibre ST) +IRIG-B IEC IEC DNP3 TCP/IP - - DNP3 serial - Modbus TCP/IP - - Modbus RTU/ASCII - = supported, - = not supported July 1, 2009 Slide 49

50 Station time synchronization Ethernet-based time synchronization: SNTP (Simple Network Time Protocol) With special time synchronization wiring: IRIG-B (Inter-Range Instrumentation Group - Time Code Format B) Remote-end station time reference: Line-differential Time stamp resolution: 1 ms July 1, 2009 Slide 50

51 Front port communication RJ45 Ethernet connector IED configuration using PCM600 IED access using the webbrowser-based HMI LED indication on the local HMI during data transfer Both crossover and regular cables can be used July 1, 2009 Slide 51

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53 615 series Patented and compact plug-in design Speeds up installation, maintenance and testing of the protection Contributes to a shortened MTTR (mean time to recover) Allows the cases to be installed and wired before the plug-in units are delivered Mechanical coding system for preventing insertion of a wrong plug-in unit in a case Sealable pull-out handle to prevent accidental (or unauthorized) withdrawal of the plug-in unit July 1, 2009 Slide 53

54 615 series IED case and plug-in unit Height: frame 177 mm, case 164 mm Width: frame 177 mm (4U), case 160 mm Depth: case 155 mm IP classification IP54 IP20 When panelmounted Rear side July 1, 2009 Slide 54

55 615 series Flush and semi-flush mounting Flush mounting The same cut-out on the cubicle front as for the 610 series IEDs (height: ±1, width: ±1) Semi-flush mounting With a 50 mm rising frame July 1, 2009 Slide 55

56 615 series Semi-flush and wall mounting Semi-flush mounting in a 25 angle With special accessories Wall mounting The IED can be tilted for easy access to the connectors July 1, 2009 Slide 56

57 615 series Panel and rack mounting Mounting using a 19 mounting panel One or two IEDs Mounting with an RTXP test switch in a 19 rack For routine testing purposes July 1, 2009 Slide 57

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59 615 series Three dedicated LEDs: Ready, Start,Trip 4 x 16 character display (LCD) CB Control, OPEN and CLOSE buttons 11 programmable LEDs ENTER button CLEAR button Front communication port MENU button ESC button Navigation buttons LOCAL/REMOTE button, HELP AUTHORIZATION July 1, 2009 Slide 59

60 615 series Display Large LCD, mono-spaced 10 x 20 characters, variable width 8 x 8 (or more) characters Small LCD, mono-spaced 4 x 20 characters, variable width 4 x 8 (or more) characters Background light with power-saving mode Option: Small LCD Large LCD July 1, 2009 Slide 60

61 Display readouts IEC naming, classic IEC symbols or ANSI codes: (LNPLDF, 3ΔI >, 87L) Fault indications Four fault recordings with time stamp Measurements: Currents Historical data July 1, 2009 Slide 61

62 Display readouts, cont d Name or code of protected objects Settings in 4 setting groups Configurations such as protocol settings etc. Product information, serial number, software version, identification etc. July 1, 2009 Slide 62

63 July 1, 2009 Slide 63

64 PCM600 Web-browser-based user interface RED615 Connectivity Package, including the line differential characteristics tool Version 2.0 SP2 or later IE 7.0 or later 2.5 or later July 1, 2009 Slide 64

65 PCM600 Protection and control IED Manager A common tool for new and existing protection IEDs and terminals IED-specific connectivity packages enable the use PCM600 for different ABB protection IEDs and terminals Supports IEC GOOSE messaging configuration (PCM600 Engineering Pro) IED interaction using: Corporate LAN/WAN The IED s communication port July 1, 2009 Slide 65

66 PCM600 All tools needed to manage RED615 are included in PCM600: Signal matrix Signal monitoring IED parameter setting Disturbance recorder handling and viewing IEC (GOOSE) communication configuration Modbus communication configuration DNP3 communication configuration IEC communication configuration Access control management July 1, 2009 Slide 66

67 PCM600 Power system overview PCM600 offers the possibility to create a tree-structure representing your individual power system, including: Project name Substations Voltage levels Bays IEDs/terminals July 1, 2009 Slide 67

68 615 series Web-browser based user interface Local or remote IED access using an IE 7.0 (or later) web browser Disabled by default, enabled by PCM600 or the local front-panel interface Functions: Viewing of alarm LEDs and event lists Saving of event data Parameter setting Signal monitoring Measurement viewing Phasor diagram viewing Reading of disturbance records User access level authentication July 1, 2009 Slide 68

69 Differential characteristics tool Included in the connectivity package Visual presentation of the differential protection characteristics Possibility to read fault records from the IED and present them on the characteristic Writing of parameters to the IED using the local HMI, the web-browser based HMI or PCM600 July 1, 2009 Slide 69

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71 Product summary Phase segregated line differential protection with two stages IEC station communication including GOOSE messaging Binary signal transfer between the IEDs in the substations (located apart from each other) Extensive supervision on protection communication and CT secondary connections All I/Os are fully matrixed, thus enabling optimal use Rapid set-up and commissioning, preconfigured IEDs Versatile tools July 1, 2009 Slide 71

72 Selection and ordering data, digit 1-3 July 1, 2009 Slide 72

73 Selection and ordering data, digit 4-8 July 1, 2009 Slide 73

74 Selection and ordering data, digit 9-11 July 1, 2009 Slide 74

75 Selection and ordering data, digit 9-11 cont d July 1, 2009 Slide 75

76 Selection and ordering data, digit July 1, 2009 Slide 76

77 Selection and ordering data, ordering code July 1, 2009 Slide 77

78 Product pages on the web July 1, 2009 Slide 78

79 Please visit our website for the latest product information July 1, 2009 Slide 79

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