Page 1 Preface Introduction Functions SIPROTEC Mounting and Commissioning Differential Protection Technical Data 7UT613/63x Appendix V4.60 Literature Manual Glossary Index C53000-G1176-C160-2...
Page 2: C53000-G1176-C160
We reserve the right to make technical improvements without SIPROTEC, SINAUT, SICAM and DIGSI are registered trade- notice. marks of SIEMENS AG. Other designations in this manual might be trademarks whose use by third parties for their own purposes would infringe the rights of the owner.
Page 3: Mounting And Commissioning 3
(Low-voltage directive 73/23 EEC). This conformity has been proved by tests conducted by Siemens AG in accor- dance with Article 10 of the Council Directive in agreement with the generic stan- dards EN 61000-6-2 and EN 61000-6-4 (for EMC directive) and the standard EN 60255-6 (for low-voltage directive).
Page 4 Should further information on the SIPROTEC 4 System be desired or should particular problems arise which are not covered sufficiently for the purchaser's purpose, the matter should be referred to the local Siemens representative. Training Courses Individual course offerings may be found in our Training Catalogue, or questions may be directed to our training centre in Nuremberg.
Page 5 Preface Definition QUALIFIED PERSONNEL For the purpose of this instruction manual and product labels, a qualified person is one who is familiar with the installation, construction and operation of the equipment and the hazards involved. In addition, he has the following qualifications: •...
Page 6 Preface External binary output signal with number (device indication) used as input signal Example of a parameter switch designated FUNCTION with the address 1234 and the possible settings ON and OFF Besides these, graphical symbols are used according to IEC 60617-12 and IEC 60617-13 or symbols derived from these standards.
Page 7: Table Of Contents
Contents Introduction..............17 Overall Operation .
Page 8 Contents Differential Protection ........... . 104 2.2.1 Functional Description of the Differential Protection .
Page 9 Contents Dynamic Cold Load Pickup for Time Overcurrent Protection ..... . 191 2.6.1 Function Description ........... . . 191 2.6.2 Setting Notes .
Page 10 Contents 2.13 Forward Power Supervision..........250 2.13.1 Function Description .
Page 11 Contents 2.19 Monitoring Functions ........... . . 279 2.19.1 Measurement Supervision.
Page 12 Contents 2.22 Additional Functions ........... . . 300 2.22.1 Processing of Messages .
Page 13 Contents Mounting and Commissioning ........... 339 Mounting and Connections .
Page 14 Contents Technical Data ..............421 General .
Page 15 Contents 4.23 Dimensions ............491 4.23.1 Panel Surface Mounting (Enclosure Size ) .
Page 16 Contents Literature ..............631 Glossary.
Page 17: Introduction
Introduction Differential ProtectionThe SIPROTEC 4 device 7UT613/63x is introduced in this chap- ter. You are presented with an overview of the scope of application, the properties and functional scope of the 7UT613/63x. Overall Operation Application Scope Characteristics 7UT613/63x Manual C53000-G1176-C160-2...
Page 18: Overall Operation
1 Introduction Overall Operation The digital differential protection devices SIPROTEC 4 7UT613/63x are equipped with a powerful microprocessor system. This provides fully numerical processing of all functions in the device, from the acquisition of the measured values up to the output of commands to the circuit breakers Figure 1-1 Hardware structure of the digital differential current protection relay 7UT613/63x...
Page 19 1.1 Overall Operation and earth, or other single-phase measuring currents. One or two additional inputs can be designed for highly sensitive current detection, This, for example, allows the detec- tion of small tank leakage currents of power transformers or - with an external series resistor - the detection of a voltage (e.g.
Page 20 1 Introduction Binary Inputs and Binary inputs and outputs from and to the computer system are routed via the I/O Outputs modules (inputs and outputs). The computer system obtains the information from the system (e.g remote resetting) or from other devices (e.g. blocking commands). These outputs include, in particular, trip commands to switchgear and signals for remote an- nunciation of important events and conditions.
Page 21: Application Scope
1.2 Application Scope Application Scope The numerical differential protection SIPROTEC 4 7UT613/63x is a fast and selective short-circuit protection for transformers of all voltage levels, for rotating machines, for series and shunt reactors, or for short lines and mini-busbars with 2 to 5 feeders (de- pending on the version).
Page 22 1 Introduction at the ends of the protected zone feed a common (external) high-ohmic resistor The current in this resistor is measured using a high-sensitive current input 7UT613/63x. The device provides backup time overcurrent protection functions for all types of pro- tected objects.
Page 23: Characteristics
1.3 Characteristics Characteristics General Features • Powerful 32-bit microprocessor system. • Complete digital measured value processing and control, from the sampling and digitalization of the analogue input quantities to the initiation of outputs for tripping or closing circuit breakers. • Complete galvanic and reliable separation between the internal processing circuits of the device and the external measurement, control, and power supply circuits because of the design of the analog input transducers, binary input and output mod- ules, and the DC/DC or AC/DC converters.
Page 24 1 Introduction Busbar Protection • 1-phase differential protection for a busbar with up to 9 or 12 feeders (depending on the version) • Either one relay per phase or one relay connected via interposed summation current transformers • Tripping characteristic with current restraint •...
Page 25 1.3 Characteristics • Instantaneous tripping possible at any stage when closing onto a short-circuit • Inrush restraint using the second harmonic of the measured current • Dynamic switchover of the time overcurrent protection settings, e.g. during cold- load start-up of the power plant •...
Page 26 1 Introduction Thermal Overload • Thermal replica of current-initiated heat losses Protection • True RMS current calculation • Can be assigned to any desired side of the protective object • Adjustable thermal warning stage • Adjustable current warning stage • With or without including the ambient or coolant temperature (by means of external resistance temperature detector via RTD-box) •...
Page 27 1.3 Characteristics Frequency Protec- • Three underfrequency stages and one overfrequency stage tion (devices with • Frequency measurement via the positive sequence component of the voltages measured voltage inputs) • Insensitive to harmonics and abrupt phase angle changes • Adjustable undervoltage threshold Circuit Breaker •...
Page 28 1 Introduction User-defined Logic • Freely programmable combination of internal and external signals for the imple- Functions (CFC) mentation of user-defined logic functions • All usual logic functions • Time delays and limit value inquiries Commissioning, • Isolation of one side or measuring point for maintenance work: the isolated line or Operation measuring point is withdrawn from the differential protection system processing, without affecting the remainder of the protection system...
Page 29 1.3 Characteristics • Communication with central control and data storage equipment possible via serial interfaces (depending on the individual ordering variant) by means of data cable, modem or optical fibres Various transmission protocols are provided for this pur- pose. ■ 7UT613/63x Manual C53000-G1176-C160-2...
Page 30 1 Introduction 7UT613/63x Manual C53000-G1176-C160-2...
Page 31: Functions
Functions This chapter describes the individual functions available on the SIPROTEC 4 device 7UT613/63x. It shows the setting possibilities for each function in maximum configu- ration. Guidelines for establishing setting values and, where required, formulae are given. Additionally, on the basis of the following information, it may be defined which functions are to be used.
Page 32 2 Functions 2.23 Average Values, Minimum and Maximum Values 2.24 Command Processing 7UT613/63x Manual C53000-G1176-C160-2...
Page 33: General
2.1 General General A few seconds after the device is switched on, the default display appears on the LCD. In the 7UT613/63x the measured values are displayed. The function parameters, i.e. settings of function options, threshold values, etc., can be entered via the front panel of the device or by means of a PC connected to the op- erator or service interface of the device utilising DIGSI.
Page 34: Device
2 Functions 2.1.1 Device 2.1.1.1 Setting Notes The parameters for the tripping logic of the entire device and the circuit breaker test have already been set in section 2.1.4. Address 201 FltDisp.LED/LCD also decides whether the alarms that are allocated to local LEDs and the spontaneous displays that appear on the local display after a fault should be displayed on every pickup of a protection function (Target on PU) or whether they should be stored only when a tripping command is given (Target on...
Page 35: En100-Modul 1
2.1 General Information Type of In- Comments formation >Reset LED >Reset LED >Test mode >Test mode >DataStop >Stop data transmission Device OK Device is Operational and Protecting ProtActive IntSP At Least 1 Protection Funct. is Active Reset Device Reset Device Initial Start Initial Start of Device Resume...
Page 36: Information List
2 Functions 2.1.2.3 Information List Information Type of In- Comments formation 009.0100 Failure Modul IntSP Failure EN100 Modul 009.0101 Fail Ch1 IntSP Failure EN100 Link Channel 1 (Ch1) 009.0102 Fail Ch2 IntSP Failure EN100 Link Channel 2 (Ch2) 2.1.3 Configuration of the Functional Scope The devices 7UT613/63x contain a series of protective and additional functions.
Page 37 2.1 General If the parameter group changeover function is desired, address 103 Grp Chge Parameter Group OPTION should be set to Enabled. In this case, it is possible to apply up to four dif- Changeover Func- tion ferent groups of settings for the function parameters. During normal operation, a con- venient and fast switch-over between these setting groups is possible.
Page 38 2 Functions Figure 2-1 Transformer bank, consisting of 3 single-phase auto-transformers with current comparison via each single phase • Such current comparison is more sensitive to 1-phase earth faults in one of the transformers than the normal differential protection. This has a certain importance considering that 1-phase earth faults are the most probable faults in such banks.
Page 39 2.1 General The Restricted earth fault protection (address 113 REF PROT.) com- Restricted Earth Fault Protection pares the sum of the phase currents flowing into the three-phase protected object together with the current flowing into the earthed starpoint. Further information is given in section 2.3.
Page 40 2 Functions Time Overcurrent There is another earth current time overcurrent protection which is independent from Protection for Earth the before-described zero sequence time overcurrent protection. This protection, to be configured in address 124 DMT/IDMT Earth, acquires the current connected to a Current single-phase current measuring input.
Page 41 2.1 General lates the overtemperature in the protected object from the flowing current, with refer- ence to the permissible temperature. This method is characterised by its easy han- dling and a low number of setting values. Detailed knowledge about the protected object, the environment and cooling is re- quired for overcurrent protection with hot-spot calculation in accordance with IEC 60354;...
Page 42 2 Functions former, allows for a reasonable calculation of the active power. The definition of the reverse direction is explained in detail elsewhere. The forward power monitoring (address 151 FORWARD POWER) can monitor a protect- Forward Power Monitoring ed object with regard to undershooting as well as exceeding of a preset active power. It can only be used in three-phase protected objects, thus not at address 105 PROT.
Page 43: Settings
2.1 General External Trip The possibilities of two trip commands from external sources can be configured in ad- dresses 186 EXT. TRIP 1 and 187 EXT. TRIP 2. Command Flexible Functions 7UT613/63x provides flexible functions that can be used for protection, monitoring or measuring tasks.
Page 44 2 Functions Addr. Parameter Setting Options Default Setting Comments DMT 1PHASE Disabled Disabled DMT 1Phase Enabled DMT/IDMT Phase2 Disabled Disabled DMT / IDMT Phase 2 Definite Time TOC IEC TOC ANSI User Defined PU User def. Reset DMT/IDMT Phase3 Disabled Disabled DMT / IDMT Phase 3 Definite Time...
Page 45: Power System Data 1
2.1 General Addr. Parameter Setting Options Default Setting Comments FREQUENCY Prot. Disabled Disabled Over / Underfrequency Protection Enabled BREAKER FAILURE Disabled Disabled Breaker Failure Protection Enabled BREAKER FAIL. 2 Disabled Disabled Breaker Failure Protection 2 Enabled DISCON.MEAS.LOC Disabled Disabled Disconnect measurment location Enabled M.V.
Page 46 2 Functions Terminology The large variety of connection facilities of the device requires to create an exact image of the topology of the protected object. The device must be informed in which way the measured quantities derived from the measured value inputs of the device have to be processed by the different protection functions.
Page 47 2.1 General The main protected object is a two-winding transformer YNd with an earthed starpoint at the Y-side. Side S1 is the upper voltage side (Y), side S2 is the lower voltage side (d). This definition of the sides for the main protected object (and only for it) is the basis for the formation of the differential and restraint currents used in the differential pro- tection.
Page 48 2 Functions Figure 2-2 Example for the terminology of a topology Sides: High voltage side of the main protected object (power transformer) Low voltage side of the main protected object (power transformer) Measuring locations 3-phase, assigned: Measuring location, assigned to the main protected object, side 1 Measuring location, assigned to the main protected object, side 1 Measuring location, assigned to the main protected object, side 2 Measuring location, assigned to the main protected object, side 2...
Page 49 2.1 General single-phase overcurrent protection is an autonomous protection function without any relation to a specific side. Figure 2-3 shows an example of a topology which in addition to the main protected object (the three-winding transformer) has another protected object (the neutral reac- tor) with a three-phase measuring location and an additional 1-phase measuring lo- cation assigned to it.
Page 50 2 Functions Determining the You have to determine the topology of the main protected object and further objects Topology (if applicable). The following clarifications are based on the examples given above and the terminology defined above. Further examples will be given where needed. The necessary and possible settings depend on the type of main protected object as defined during configuration of the scope of functions (section 2.1.3).
Page 51 2.1 General Note The determination of the sides and measuring locations is imperative for all further setting steps. It is also important that the currents from the measuring locations (cur- rent transformers) are connected to the associated analogue current inputs of the device: The currents of measuring location M1 must be connected to the device at measuring locations I (in single-phase transformers I...
Page 52 2 Functions Figure 2-4 Example of a topology on a three-winding transformer Sides: High voltage side of the main protected object (power transformer) Low voltage side of the main protected object (power transformer) Tertiary winding side of the main protected object (power transformer) Measuring locations 3-phase, assigned: Measuring location, assigned to the main protected object, side 1 Measuring location, assigned to the main protected object, side 2...
Page 53 2.1 General Figure 2-5 Topology of an auto-transformer with a compensation winding which is used as tertiary winding Sides: High voltage side of the main protected object (auto-transformer) Low voltage side of the main protected object (auto-transformer) Tertiary winding side (accessible compensation winding) of the main protected object Measuring locations 3-phase, assigned: Measuring location, assigned to the main protected object, side 1 Measuring location, assigned to the main protected object, side 1...
Page 54 2 Functions The sum of the three currents measured in the starpoint leads can be connected to an auxiliary 1-phase current input of the device (illustrated dotted) in order to use it for restricted earth fault protection and/or time overcurrent protection. This auxiliary mea- suring location X3 is then assigned to both sides S1 and S2, since the current entering the protected object at X3 must be compared with the sum of the currents at both sides.
Page 55 2.1 General Current comparison for common winding of an auto-transformer: If during configuration of the functional scope in section 2.1.3 a pure current compar- ison via each winding has been selected, then the example of figure 2-7 applies. Besides the common winding terminals of the sides S1 (full winding) and S2 (tap) with the assigned 3-phase measuring locations M1 and M2, one more side S3 is defined at the starpoint terminals with the 3-phase measuring location M3.
Page 56 2 Functions Figure 2-7 Topology of a transformer bank consisting of 3 single-phase auto-transformers, topology definitions for a current comparison protection for each phase Sides: High voltage side of the auto-connected winding of the main protected object Low voltage side (tap) of the auto-connected winding of the main protected object Starpoint side of the auto-connected winding of the main protected object Measuring locations 3-phase, assigned: Measuring location, assigned to the main protected object, side 1...
Page 57 2.1 General If the global data are implausible, the device does not find any meaningful combination of assignment possibilities. In this case you will find address 230 ASSIGNM. ERROR, which shows one of the following options: • No AssigMeasLoc the number of assigned measuring locations is implausible; •...
Page 58 2 Functions Address 224 ASSIGNM. 4M,3S appears if 4 assigned measuring locations (address 212) have been selected for 3 sides (address 213). The following options are possi- ble: • M1+M2,M3,M4, i.e. the 4 measuring locations are assigned: M1 and M2 to side S1, M3 to side S2, M4 to side S3.
Page 59 2.1 General • M1,M2,M3+M4,M5, i.e. the 5 measuring locations are assigned: M1 to side S1, M2 to side S2, M3 and M4 to side S3, M5 to side S4. • M1,M2,M3,M4+M5, i.e. the 5 measuring locations are assigned: M1 to side S1, M2 to side S2, M3 to side S3, M4 and M5 to side S4.
Page 60 2 Functions In the example in figure 2-6 is for a PROT. OBJECT = Autotransf. the side S3 the tertiary winding, thus the accessible and load capable compensation winding. In this example the setting would be: Address 243 SIDE 3 = compensation. This option is only possible for PROT.
Page 61 2.1 General • 1st case: It is essential to assign the 1-phase input to that side of the main protected object whose incoming phase currents are to be compared with the earth fault cur- rent. Make sure that you assign the 1-phase input to the correct side. In case of transformers, this can only be a side with an earthed starpoint (directly or via a neutral earthing transformer in the protected zone).
Page 62 2 Functions • 4th and 5th case: In these cases you set the parameter for the assignment of the auxiliary measuring location to conn/not assig. (connected but not assigned). The auxiliary measuring location is then assigned to neither a specific side of the main protected object nor to any other 3-phase measuring location.
Page 63 2.1 General forward power monitoring, the frequency protection, or for measuring tasks like the display of voltages or the calculation and output of power and energy metering. Figure 2-8 shows the various possible voltage assignments (which, of course do not occur all at the same time in practice).
Page 64 2 Functions If the voltage transformers represented as Ua do not exist in your system, you can, for instance, use the voltages at Measuring loc.2 (represented as Ub), as they are electrically identical (assuming that the circuit breaker is closed). The device then assigns the voltage automatically to side 1 and calculates the power of the side from this voltage and the current of side S1, which is the sum of the currents from the mea- suring locations M1 and M2.
Page 65: General Power System Data (Power System Data 1)
2.1 General As different connections are possible, you must now specify in the device how the con- nected 1-phase voltage should be interpreted. This is done at address 263 VT U4 TYPE. Set Udelta transf. if the voltage assigned acc. to address 262 is a dis- placement voltage.
Page 66 2 Functions Please observe the definition of the sides which you have performed during setting of the topology of the main protected object (cf. Determining the Topology). Generally, side 1 is the reference winding having a current phase angle of 0° and no vector group indicator.
Page 67 2.1 General For side 2, the same considerations apply as for the side 1: The primary rated voltage UN-PRI SIDE 2 (under address 321), the starpoint condition STARPNT SIDE 2 (under address 323). Observe strictly the assignment of the side according to the to- pological definitions made before.
Page 68 2 Functions For the winding assigned to side 3, the following data are relevant: • Address 331 UN-PRI SIDE 3 the primary rated voltage (consider regulating range), • Address 332 SN SIDE 3 the primary rated apparent power, • Address 333 STARPNT SIDE 3 the starpoint treatment, •...
Page 69 2.1 General The primary rated voltage (phase-to-phase) 370 UN BUSBAR is important for voltage- dependent protection functions (such as overexcitation protection, voltage protection, frequency protection, power protection functions). It also influences the calculation of the operational measured values. The feeders of a busbar may be rated for different currents. For instance, an overhead line may be able to carry higher load than a cable feeder or a transformer feeder.
Page 70 2 Functions Object Data with These busbar data are only required if the device is used for single-phase busbar dif- Busbars (1-phase ferential protection. When configuring the scope of functions (see Scope of Functions, address 105), the following must have been set: PROT. OBJECT = 1ph Busbar. In Connection) with up to 6 or 9 or 12 cases other than that, these settings are not available.
Page 71 2.1 General which relate to the non-assigned measuring locations, according to the set topology. Since the main protected object provides at least 2 measuring locations (differential protection would make no sense with fewer), M1 and M2 will never appear here. Address 403 I PRIMARY OP M3 requests the rated primary operating current at the measuring location M3 provided this is not assigned to the main protected object.
Page 72 2 Functions Figure 2-13 Position of CT starpoints at 3-phase measuring locations - example 7UT613/63x Manual C53000-G1176-C160-2...
Page 73 2.1 General Similar applies for the further measuring locations (assigned or non-assigned to the main protected object). Only those addresses will appear during setting which are available in the actual device version. Measuring Location 2 • Address 521 STRPNT->OBJ M2 starpoint position of CTs for measuring location •...
Page 74 2 Functions Current Transform- The operational nominal currents of each feeder have already been set under margin er Data for Single- heading „Object Data with Busbars (1-phase Connection) with up to 9 or 12 Feeders“. phase Busbar Pro- The feeder currents are referred to these nominal feeder currents. However, the rated tection currents of the current transformers may differ from the nominal feeder currents.
Page 75 2.1 General Feeder 1 • Address 561 STRPNT->BUS I1 = transformer starpoint versus busbar for feeder 1, • Address 562 IN-PRI CT I1 = rated primary transformer current for feeder 1, • Address 563 IN-SEC CT I1 = rated secondary transformer current for feeder 1. Feeder 2 •...
Page 76 2 Functions Feeder 11 • Address 661 STRPNT->BUS I11 = transformer starpoint versus busbar for feeder • Address 662 IN-PRI CT I11 = rated primary transformer current for feeder 11, • Address 663 IN-SEC CT I11 = rated secondary current for feeder 11. Feeder 12 •...
Page 77 2.1 General Polarity check for 1-phase current inputs IX1 Figure 2-16 The following applies for the (max. 4, dependent on device version on connections) 1-phase current inputs: For the auxiliary measuring input X1 • Address 711 EARTH IX1 AT with the options Terminal Q7 or Terminal Q8, •...
Page 78 2 Functions Table 2-4 Terminal designation with surface mounted housing Corresponds to surface mounted housing, terminal 1-phase current Flush mounted input housing 7UT613 7UT633 7UT635 Terminal Q7 Terminal Q8 Terminal N7 Terminal N8 Terminal R7 Terminal R8 Terminal P7 – –...
Page 79: Assignment Of Protection Functions To Measuring Locations / Sides
2.1 General If the U4 transformer set is a Uen transformer, then address 817 Uph(U4)/Udelta must be set. 817 Uph(U4)/Udelta (0.10-9.99 ; without 0) 2.1.4.3 Assignment of Protection Functions to Measuring Locations / Sides Main Protection The main protected object, i.e. the protected object which has been selected at address 105 PROT.
Page 80 2 Functions Since the assignment of the 3-phase measuring locations and of the auxiliary measur- ing location is also defined by the topology, you only need to set auto-connected for the restricted earth fault protection REF PROT. AT. This is also true if the auto- connected winding has more than one tap.
Page 81 2.1 General As the above examples show, the protection function can be assigned as desired. Generally speaking: • Where a 3-phase protection function is assigned to a measuring location, the cur- rents are acquired at this location, regardless of whether it is assigned to the main protected object or not.
Page 82 2 Functions The same applies to the second overload protection that is assigned to a side under address 444 THERM. O/L 2 AT. The overexcitation protection (section 2.11) is only possible for devices with voltage connection, and requires a measuring voltage to be connected and declared in the to- pology (section „Topology of the Protected Object“...
Page 83: Circuit Breaker Data
2.1 General Address 427 DMT 1PHASE AT assigns the single-phase time overcurrent protection (section 2.7). This protection function is mainly used for high-sensitivity current mea- surement, e.g. for tank leakage protection or high-impedance differential protection. Therefore a high-sensitivity 1-phase additional measuring input is particularly suited for it.
Page 84: Settings
2 Functions Example: The group „Control Devices“ of the configuration matrix contains a double-point indi- cation „Q0“. Assuming this should be the breaker to be monitored, you have deter- mined during configuration the physical inputs of the device at which the feedback in- dications of the breaker Q0 arrive.
Page 85 2.1 General Addr. Parameter Setting Options Default Setting Comments NUMBER OF ENDS Number of Ends for 1 Phase Busbar ASSIGNM. 2M,2S M1,M2 M1,M2 Assignment at 2 assig.Meas.Loc./ 2 Sides ASSIGNM. 3M,2S M1+M2,M3 M1+M2,M3 Assignment at 3 assig.Meas.Loc./ M1,M2+M3 2 Sides ASSIGNM.
Page 86 2 Functions Addr. Parameter Setting Options Default Setting Comments AUX. CT IX1 Not connected Not connected Auxiliary CT IX1 is used as conn/not assig. Side 1 earth Side 2 earth Side 3 earth Side 4 earth MeasLoc.1 earth MeasLoc.2 earth MeasLoc.3 earth MeasLoc.4 earth AUX.
Page 87 2.1 General Addr. Parameter Setting Options Default Setting Comments VT U4 Not connected Measuring loc.1 VT U4 is assigned conn/not assig. Side 1 Side 2 Side 3 Measuring loc.1 Measuring loc.2 Measuring loc.3 Busbar VT U4 TYPE Udelta transf. Udelta transf. VT U4 is used as UL1E transform.
Page 88 2 Functions Addr. Parameter Setting Options Default Setting Comments VECTOR GRP S2 Vector Group Numeral of Side 2 UN-PRI SIDE 3 0.4 .. 800.0 kV 11.0 kV Rated Primary Voltage Side 3 SN SIDE 3 0.20 .. 5000.00 MVA 10.00 MVA Rated Apparent Power of Transf.
Page 89 2.1 General Addr. Parameter Setting Options Default Setting Comments UN-PRI SIDE 5 0.4 .. 800.0 kV 11.0 kV Rated Primary Voltage Side 5 SN SIDE 5 0.20 .. 5000.00 MVA 10.00 MVA Rated Apparent Power of Transf. Side 5 STARPNT SIDE 5 Earthed Earthed Starpoint of Side 5 is...
Page 90 2 Functions Addr. Parameter Setting Options Default Setting Comments PHASE SELECTION Phase 1 Phase 1 Phase selection Phase 2 Phase 3 I PRIMARY OP M3 1 .. 100000 A 200 A Primary Operating Current Meas. Loc. 3 I PRIMARY OP M4 1 ..
Page 91 2.1 General Addr. Parameter Setting Options Default Setting Comments DMT/IDMT E AT no assig. poss. AuxiliaryCT IX1 DMT / IDMT Earth assigned to AuxiliaryCT IX1 AuxiliaryCT IX2 AuxiliaryCT IX3 AuxiliaryCT IX4 DMT 1PHASE AT no assig. poss. AuxiliaryCT IX1 DMT 1Phase assigned to AuxiliaryCT IX1 AuxiliaryCT IX2 AuxiliaryCT IX3...
Page 92 2 Functions Addr. Parameter Setting Options Default Setting Comments UNBAL. LOAD AT Side 1 Side 1 Unbalance Load (Neg. Seq.) as- Side 2 signed to Side 3 Side 4 Side 5 Measuring loc.1 Measuring loc.2 Measuring loc.3 Measuring loc.4 Measuring loc.5 THERM.
Page 93 2.1 General Addr. Parameter Setting Options Default Setting Comments IN-SEC CT M2 CT Rated Secondary Current Meas. Loc. 2 STRPNT->OBJ M3 CT-Strpnt. Meas. Loc.3 in Dir. of Object IN-PRI CT M3 1 .. 100000 A 2000 A CT Rated Primary Current Meas. Loc.
Page 94 2 Functions Addr. Parameter Setting Options Default Setting Comments IN-PRI CT I5 1 .. 100000 A 200 A CT Rated Primary Current I5 IN-SEC CT I5 CT Rated Secondary Current I5 0.1A STRPNT->BUS I6 CT-Starpoint I6 in Direction of Busbar IN-PRI CT I6 1 ..
Page 95 2.1 General Addr. Parameter Setting Options Default Setting Comments EARTH IX1 AT Terminal Q7 Terminal Q7 Earthing electrod IX1 connected to Terminal Q8 IN-PRI CT IX1 1 .. 100000 A 200 A CT rated primary current IX1 IN-SEC CT IX1 CT rated secondary current IX1 EARTH IX2 AT Terminal N7...
Page 96: Information List
2 Functions Addr. Parameter Setting Options Default Setting Comments SwitchgCBaux M1 (Setting options depend None Switchgear / CBaux at Measuring on configuration) Loc. M1 SwitchgCBaux M2 (Setting options depend None Switchgear / CBaux at Measuring on configuration) Loc. M2 SwitchgCBaux M3 (Setting options depend None Switchgear / CBaux at Measuring...
Page 97: Setting Notes
2.1 General More details on how to navigate between the setting groups, to copy and reset setting groups, and how to switch over between the setting groups during operation, can be found in the SIPROTEC 4 System Description /1/. The preconditions for switching from one setting group to another via binary inputs is described in the Subsection „Mounting and Commissioning“.
Page 98 2 Functions the polarity of currents thus needs to be ensured by means of the polarity settings set out in the section General System Data. Apart from currents and voltages, protection and additional functions use the same definition of current direction as a matter of principle. This applies to 7UT613/63x thus also to reverse power protection, forward power monitoring, operational measured values for power and work, and, if required, user-defined flexible protection functions.
Page 99 2.1 General Address 1121 PoleOpenCurr.M1 for measuring location 1, Address 1122 PoleOpenCurr.M2 for measuring location 2, Address 1123 PoleOpenCurr.M3 for measuring location 3, Address 1124 PoleOpenCurr.M4 for measuring location 4, Address 1125 PoleOpenCurr.M5 for measuring location 5. If parasitic currents (e.g. through induction) can be excluded when the circuit breaker is open, these settings may normally be very sensitive.
Page 100: Settings
2 Functions 2.1.6.2 Settings The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter Setting Options Default Setting Comments 1107 P,Q sign not reversed not reversed sign of P,Q reversed 1111 PoleOpenCurr.S1 0.04 ..
Page 101: Information List
2.1 General Addr. Parameter Setting Options Default Setting Comments 1136 PoleOpenCurr I6 0.04 .. 1.00 A 0.04 A Pole Open Current Threshold End 6 0.20 .. 5.00 A 0.20 A 0.1A 0.004 .. 0.100 A 0.004 A 1137 PoleOpenCurr I7 0.04 ..
Page 102 2 Functions Information Type of In- Comments formation FaultConfig/Set Fault in configuration / setting GenErrGroupConn Gen.err.: Inconsistency group/connection GenErrEarthCT Gen.err.: Sev. earth-CTs with equal typ GenErrSidesMeas Gen.err.: Number of sides / measurements Relay PICKUP Relay PICKUP Relay TRIP Relay GENERAL TRIP command PU Time Time from Pickup to drop out TRIP Time...
Page 103 2.1 General Information Type of In- Comments formation 30257 IL1M3: Primary fault current IL1 meas. loc. 3 30258 IL2M3: Primary fault current IL2 meas. loc. 3 30259 IL3M3: Primary fault current IL3 meas. loc. 3 30260 IL1M4: Primary fault current IL1 meas. loc. 4 30261 IL2M4: Primary fault current IL2 meas.
Page 104: Differential Protection
2 Functions Differential Protection The differential protection represents the main protection feature of the device. It is based on current comparison under consideration of the transformation ratio of the transformer.7UT613/63x is suitable for unit protection of transformers, generators, motors, reactors, short lines, and (under observance of the available number of ana- logue current inputs) and (under observance of the available number of analogue current inputs) busbars.
Page 105 2.2 Differential Protection All following considerations are based on the convention that all currents flowing into the protected zone are defined as positive unless explicitly stated otherwise. Basic Principle with For protected objects with three or more sides or for busbars, the differential principle more than Two is expanded in that the total of all currents flowing into the protected object is zero in Sides...
Page 106 2 Functions = |I | + |I stab The current sum definition is extended for more than 2 measurement locations, e.g. for 4 measuring locations (figure 2-18 or 2-19), therefore: = |I diff = |I | + |I | + |I | + |I stab is derived from the fundamental frequency current and produces the tripping effect...
Page 107 2.2 Differential Protection Figure 2-21 Tripping characteristic of the differential protection and fault characteristic Add-on Restraint Saturation of the current transformers caused by high fault currents and/or long during External system time constants are uncritical for internal faults (fault in the protected zone), Faults since the measured value deformation is found in the differential current as well in the restraint current, to the same extent.
Page 108 2 Functions The add-on restraint acts individually per phase. It can be determined by a setting pa- rameter whether only the phase with detected external fault is blocked when this re- straint criterion is fulfilled or also the other phases of the differential stage. A further stabilisation (restraint) comes into effect when differential secondary currents are simulated by different transient behaviour of the current transformer sets.
Page 109 2.2 Differential Protection Fast Unrestrained High-current faults in the protected zone may be cleared instantaneously without Trip with High- regard to the restraint currents when the current amplitude excludes an external fault. Current Faults If the protected object has a high direct impedance (transformers, generators, series reactors), a threshold can be found which can never be exceeded by a through-fault current.
Page 110 2 Functions Figure 2-22 Increase of pickup value of the stage on startup Tripping Character- Figure 2-23 illustrates the complete tripping characteristic of the 7UT613/63x. The istic characteristic branch a represents the sensitivity threshold of the differential protection (setting I-DIFF>) and considers constant error currents such as magnetising cur- rents.
Page 111 2.2 Differential Protection Differential currents above branch d cause immediate trip regardless of the restraining quantity and harmonic content (setting I-DIFF>>). This is the operating range of the „Fast Unrestrained Trip with High-current Faults“. The area of add-on restraint is the operational area of the saturation indicator (see margin heading „Add-on Restraint during External Faults“).
Page 112 2 Functions Figure 2-25 Tripping logic of the differential protection (simplified) 7UT613/63x Manual C53000-G1176-C160-2...
Page 113: Differential Protection For Transformers
2.2 Differential Protection A dropout is detected when, during 2 cycles, pick-up is no longer recognised in the dif- ferential value, i.e. the differential current has fallen below 70 % of the set value, and the other pickup conditions are no longer fulfilled either. If a trip command has not been initiated, the fault is considered ended on dropout.
Page 114 2 Functions Concerning power transformers with more than two windings, the windings may have different power ratings. In order to achieve comparable currents for the differential pro- tection, all currents are referred to the winding (= side) with the highest power rating. This apparent power is named the rated power of the protected object.
Page 115 2.2 Differential Protection Non-earthed Trans- Figure 2-28 illustrates an example for a power transformer Yd5 (wye-delta with 150° former Starpoint phase displacement) without any earthed starpoint. The figure shows the windings (above) and the vector diagrams of symmetrical currents (below). The general form of the matrix equation is: Matrix of the matched currentsI Constant factor for magnitude matching,...
Page 116 2 Functions Earthed Starpoint Differential protection makes use of the fact that the total of all currents flowing into the protected object is zero in healthy operation. If the starpoint of a power transformer winding is connected to earth, a current can flow into the protected zone across this earth connection in case of earth faults.
Page 117 2.2 Differential Protection · (2 I – 1 I – 1 I · (3 I – I – I – I · (3 I – 3 I – I ) = (I Zero sequence current elimination achieves that fault currents which flow via the transformer during earth faults in the network in case of an earth point in the protected zone (transformer starpoint or starpoint former by neutral earth reactor) are rendered harmless without any special external measures.
Page 118 2 Functions Figure 2-31 Example of an earth fault outside the protected transformer with a neutral earth- ing reactor within the protected zone The disadvantage of elimination of the zero sequence current is that the protection becomes less sensitive (factor because the zero sequence current amounts to in case of an earth fault in the protected area.
Page 119 2.2 Differential Protection the differential protection in case of earth faults in the protected zone is less sensitive by the factor , because the zero sequence current is of the fault current. If, however, the starpoint current is accessible and connected to the device, then all currents flowing into the protected zone are available.
Page 120 2 Functions Figure 2-34 Example of a single-phase transformer with current definition Like with three-phase power transformers, the currents are matched by programmed coefficient matrices which simulate the difference currents in the transformer wind- ings. The common form of these equations is: = k·...
Page 121: Differential Protection For Generators, Motors, And Series Reactors
2.2 Differential Protection The matrix equation in this cases is as follows: Where I is the current measured in the „Starpoint“ connection. The zero sequence current is not eliminated. Instead of this, for each phase half of the starpoint current I is added.
Page 122: Differential Protection For Shunt Reactors
2 Functions Figure 2-37 Definition of current direction with transverse differential protection The currents flow into the protected object even in case of healthy operation, in con- trast to all other applications. For this reason, the polarity of one current transformer set must be reversed, i.e.
Page 123: Differential Protection For Mini-Busbars And Short Lines
2.2 Differential Protection Figure 2-38 Definition of current direction on a shunt reactor 2.2.5 Differential Protection for Mini-Busbars and Short Lines A mini-busbar or branch-point is defined here as a three-phase, coherent piece of con- ductor which is limited by sets of current transformers. Examples are short stubs or mini-busbars.
Page 124: Single-Phase Differential Protection For Busbars
2 Functions Figure 2-41 Definition of current direction at busbar with 4 feeders The differential protection feature of the 7UT613/63x refers all currents to the rated current of the protected object. The device is informed during setting about the rated current of the protected object (in this case the busbar or line), and about the primary rated CT currents.
Page 125 2.2 Differential Protection Phase Dedicated For each of the phases, a 7UT613/63x is used in case of single-phase connection. The Connection fault current sensitivity is equal for all types of faults. 7UT613 and 7UT633 are suitable for up to 9, 7UT635 for up to 12 feeders. The differential protection feature of the 7UT613/63x refers all currents to the rated current of the protective object.
Page 126 2 Functions Figure 2-43 Busbar protection with connection via summation current transformers (SCT) Different schemes are possible for the connection of the current transformers. The same CT connection method must be used for all feeders of a busbar. The scheme as illustrated in figure 2-44 is the most commonly used. The three input windings of the summation transformer are connected to the CT currents I .
Page 127 2.2 Differential Protection Figure 2-45 Summation of the currents in the summation transformer on connection L1-L3-E For the connection L1-L3-E (see figure 2-44), the weighting factors W of the summa- tion currents IM for the various fault conditions and the ratios to that given by the three- phase symmetrical faults are shown in table 2-5.
Page 128 2 Functions Figure 2-46 Summation transformer connection L1-L2-L3 with decreased earth fault sensi- tivity Figure 2-47 Summation of the currents in the summation transformer on connection L1-L2- Table 2-6 Fault conditions and weighting factors for the CT connection L1-L2-L3 for I Fault W/√3 = 100 mA...
Page 129: Setting Notes
2.2 Differential Protection current of the 7UT613/63x) amounts to I = 0.1 A at nominal conditions, with correct matching. Figure 2-48 Winding arrangement of summation and matching transformers 4AM5120 Differential Current Whereas a high sensitivity of the differential protection is normally required for trans- Monitoring formers, reactors, and rotating machines in order to detect even small fault currents, high fault currents are expected in case of faults on a busbar so that a higher pickup...
Page 130 2 Functions Note When delivered from factory, the differential protection is switched OFF. The reason is that the protection must not be in operation unless at least the connection group (of a transformer) and the matching factors have been set before. Without proper set- tings, the device may show unexpected reactions (incl.
Page 131 2.2 Differential Protection Differential Current With busbar protection or short-line protection differential current can be monitored. At address 1208 I-DIFF> MON. the monitoring can be set to ON and OFF. Its use is Monitoring only sensible if one can distinguish clearly between operational error currents caused by missing transformer currents and fault currents caused by a fault in the protected object.
Page 132 2 Functions Figure 2-49 Tripping characteristic of the differential protection The tripping characteristic comprises two further branches. The base point of the first branch is determined by address 1242 BASE POINT 1 and its slope by address 1241 SLOPE 1. This parameter can only be set with DIGSI under Additional Settings. This branch covers current-proportional errors.
Page 133 2.2 Differential Protection The increase of the The increase of the pickup value on startup serves as an additional safety against pickup value on overfunctioning when a non-energised protection object is connected. At address 1205 INC.CHAR.START it can be switched to ON or OFF. Especially for motors or mo- startup tor/transformer units in block connection it should be set to ON.
Page 134 2 Functions mentioned address. The restraint with harmonics does not influence the stage I- DIFF>>. The inrush restraint can be extended by the so-called "crossblock" function. This means that on harmonic content overshoot in only one phase all three phases of the differential stage I stage are blocked.
Page 135: Settings
2.2 Differential Protection 2.2.8 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings. Addr. Parameter Setting Options Default Setting Comments 1201 DIFF. PROT. Differential Protection Block relay 1205 INC.CHAR.START Increase of Trip Char. During Start 1206 INRUSH 2.HARM.
Page 136: Information List
2 Functions Addr. Parameter Setting Options Default Setting Comments 1271 2. HARMONIC 10 .. 80 % 15 % 2nd Harmonic Content in I-DIFF 2 .. 1000 Cycle; 0; ∞ 1272A CROSSB. 2. HARM 3 Cycle Time for Cross-blocking 2nd Harm. 1276 n.
Page 137 2.2 Differential Protection Information Type of In- Comments formation 5684 Diff>> L1 Diff. prot: IDIFF>> L1 (without Tdelay) 5685 Diff>> L2 Diff. prot: IDIFF>> L2 (without Tdelay) 5686 Diff>> L3 Diff. prot: IDIFF>> L3 (without Tdelay) 5691 Diff> TRIP Differential prot.: TRIP by IDIFF> 5692 Diff>>...
Page 138: Restricted Earth Fault Protection
2 Functions Restricted Earth Fault Protection The restricted earth fault protection detects earth faults in power transformers, shunt reactors, neutral earthing transformers/reactors, or rotating machines, the starpoint of which is led to earth. It is also suitable when a starpoint former is installed within a pro- tected zone of a non-earthed power transformer.
Page 139 2.3 Restricted Earth Fault Protection Figure 2-52 Restricted earth fault protection on a non-earthed transformer winding with neutral reactor (starpoint former) within the protected zone Figure 2-53 Restricted earth fault protection on an earthed shunt reactor with CTs in the reactor leads 7UT613/63x Manual C53000-G1176-C160-2...
Page 140 2 Functions Figure 2-54 Restricted earth fault protection on an earthed shunt reactor with 2 CT sets (treated like an auto-transformer) Figure 2-55 Restricted earth fault protection on an earthed auto-transformer 7UT613/63x Manual C53000-G1176-C160-2...
Page 141: Function Description
2.3 Restricted Earth Fault Protection Figure 2-56 Restricted earth fault protection on a generator or motor with earthed starpoint The restricted earth fault protection can operate on one of the sides of the main pro- tected object (power transformer, generator, motor, reactor) or on a further protected object, according to the topology configured.
Page 142 2 Functions Figure 2-57 Example for an earth fault in a transformer with current distribution When an earth fault occurs outside the protected zone (Figure 2-58), a starpoint current I will flow equally; but an equal current 3 I must flow through the phase Ctrl current transformers.
Page 143 2.3 Restricted Earth Fault Protection Figure 2-59 Principle of Restricted Earth Fault Protection For auto-transformers 3I " is valid as the sum of all phase currents flowing to auto-con- nected winding (full winding and tap(s)). When an earth fault occurs outside the protected zone, another earth currents flows through the phase current transformers.
Page 144 2 Functions 1. Through-fault current on an external earth fault: " is in phase opposition with 3I ' and of equal magnitude, i.e 3I " = –3I = |3I from = |3I ' + 3I '| – |3I ' – 3I '| = 2 ·...
Page 145 2.3 Restricted Earth Fault Protection It was assumed in the above examples that the currents 3I " and 3I ' are in counter- phase for external earth faults which is only true for the primary measured quantities. Current transformer saturation may cause phase shifting between the fundamental waves of the secondary currents which reduces the restraint quantity.
Page 146 2 Functions Figure 2-62 Tripping characteristic of the restricted earth fault protection depending on the phase angle between 3I ” and 3I ' at 3I ” = 3I ' (180 = external fault) It is possible to increase the tripping value in the tripping area proportional to the arith- metic sum of all currents, i.e.
Page 147: Setting Notes
2.3 Restricted Earth Fault Protection Figure 2-64 Logic diagram of the earth fault protection (simplified) 2.3.3 Setting Notes General Note The first restricted earth fault protection is described in the setting instructions. The pa- rameter addresses and message numbers of the second restricted earth fault protec- tion are described at the end of the setting instructions under „Additional Restricted Earth Fault Protection Functions“.
Page 148 2 Functions Note When delivered from factory, the restricted earth fault protection is switched OFF. The reason is that the protection must not be in operation unless at least the assigned side and CT polarity have been properly set before. Without proper settings, the device may show unexpected reactions (incl.
Page 149: Settings
2.3 Restricted Earth Fault Protection 2.3.4 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings. Addr. Parameter Setting Options Default Setting Comments 1301 REF PROT. Restricted Earth Fault Protection Block relay 1311 I-REF>...
Page 150: Time Overcurrent Protection For Phase And Residual Currents
2 Functions Time Overcurrent Protection for Phase and Residual Currents The overcurrent protection is used as backup protection for the short-circuit protection of the main protected object and provides backup protection for external faults which are not promptly disconnected and thus may endanger the protected object. It can also be used as short-circuit protection for a further protected object if it has been as- signed to corresponding measuring locations (see Subsection 2.1.4 in „Assignment of Protection Functions to Measuring Locations/Sides“...
Page 151 2.4 Time Overcurrent Protection for Phase and Residual Currents Figures 2-65 and 2-66 show the logic diagrams for the high-set stages I>> and 3I0>>. Figure 2-65 Logic diagram of the high-set stages I>> for phase currents (simplified) 7UT613/63x Manual C53000-G1176-C160-2...
Page 152 2 Functions Figure 2-66 Logic diagram of the high-set stages I>> for residual current (simplified) Each phase current and the zero sequence current 3·I0 are, additionally, compared with the setting value I> (common setting for the three phase currents) and 3I0> (in- dependent setting for 3·I0).
Page 153 2.4 Time Overcurrent Protection for Phase and Residual Currents Figure 2-67 Logic diagram of the overcurrent stage I> for phase currents (simplified) 7UT613/63x Manual C53000-G1176-C160-2...
Page 154: Inverse Time Overcurrent Protection
2 Functions Figure 2-68 Logic diagram for the overcurrent stage 3I0> for residual current (simplified) The pickup values of all stages I> (phases), 3I0> (zero sequence current), I>> (phases), 3I0>> (zero sequence current) and the time delays associated for each stage can be set individually.
Page 155 2.4 Time Overcurrent Protection for Phase and Residual Currents lected tripping characteristic. After expiration of this time period, a trip command is output as long as no inrush current is detected or inrush restraint is disabled. If inrush restraint is enabled and inrush current is detected, there will be no tripping. Neverthe- less, an annunciation is generated indicating that the time expired.
Page 156 2 Functions Figure 2-69 Logic diagram of the inverse overcurrent protection for phase currents — example of IEC characteristic (simplified) 7UT613/63x Manual C53000-G1176-C160-2...
Page 157 2.4 Time Overcurrent Protection for Phase and Residual Currents Figure 2-70 Logic diagram of the definite time overcurrent protection for zero sequence current — example of IEC char- acteristic (simplified) Dropout You can determine whether the dropout of a stage is to follow right after the threshold is undershot or whether it is to be evoked by disk emulation.
Page 158: Manual Close Command
2 Functions User-Specified When user-defined curves are utilized, the tripping curve may be defined point by Curves point. Up to 20 pairs of values (current, time) may be entered. With these values the device approximates the characteristic by means of linear interpolation. If required, the dropout characteristic can also be defined.
Page 159: Inrush Restraint
2.4 Time Overcurrent Protection for Phase and Residual Currents Overcurrent Protection“. The alternative pickup values themselves can be set for each of the stages of the time overcurrent protection. 2.4.1.5 Inrush Restraint When switching unloaded transformers or shunt reactors on a live busbar, high mag- netising (inrush) currents may occur.
Page 160: Fast Busbar Protection Using Reverse Interlocking
2 Functions Since the harmonic restraint operates individually per phase, the protection is fully op- erative even when e.g. the transformer is switched onto a single-phase fault, whereby inrush currents may possibly be present in one of the healthy phases. However, it is also possible to set the protection such that not only the phase with inrush current ex- hibiting harmonic content in excess of the permissible value is blocked but also the other phases of the associated stage are blocked (so called "cross-block function").
Page 161: Time Overcurrent Protection For Phase Currents
2.4 Time Overcurrent Protection for Phase and Residual Currents Figure 2-74 Fast busbar protection using reverse interlock — principle 2.4.2 Time Overcurrent Protection for Phase Currents The function and operation of the definite-time overcurrent protection and of the inverse-time overcurrent protection for residual current is discussed in detail in section „Overcurrent Time Protection - General“...
Page 162 2 Functions characteristic can be performed here. The definite time stages I>> and I> are available in all cases. If a second or third phase overcurrent protection is used, this must be configured ac- cordingly in address 130 DMT/IDMT Phase2 and 132 DMT/IDMT Phase3. Each protection function must be assigned to a side of the main protected object or another 3-phase current measuring location.
Page 163 2.4 Time Overcurrent Protection for Phase and Residual Currents Example: Transformer used in the infeed of a bus supply with the following data: Transformer YNd5 35 MVA 110 kV/20 kV = 15 % Current Transformer 200 A / 5 A on the 110 kV side The time overcurrent protection is assigned to the 110 kV side (= feeding side).
Page 164 2 Functions < I>> < I 1.6 · I startup k 2pol The potential increase in starting current caused by overvoltage conditions is already accounted for by the 1.6 factor. The I>> stage can trip instantaneously (T I>> = 0.00 s), since there is no saturation of shunt reactance for motors, other than for transformers.
Page 165 2.4 Time Overcurrent Protection for Phase and Residual Currents If under address 2225 TOC DROP-OUT the Disk Emulation are set, dropout is pro- duced in accordance with the dropout characteristic, as set out in the functional de- scription of the inverse time overcurrent protection in section „Dropout Behaviour“. Overcurrent Stages The inverse time stage, depending on the configuration of the functional scope with ANSI char-...
Page 166 2 Functions For the stages the following alternative values are set: • For definite time overcurrent protection (phases): address 2111 or 2112 for pickup value I>>, address 2113 for delay time T I>>, address 2114 or 2115 for pickup value I>, address 2116 for delay time T I>, •...
Page 167 2.4 Time Overcurrent Protection for Phase and Residual Currents Table 2-7 Preferred values of standardized currents for user-defined trip characteristics = 1 to 1.94 = 2 to 4.75 = 5 to 7.75 = 8 to 20 1.00 1.50 2.00 3.50 5.00 6.50 8.00...
Page 168 2 Functions For specification of a dropout characteristic please note the following: • For currents select the values from table 2-8 and add the corresponding time values. Deviating values I/I are rounded. This, however, will not be indicated. • Currents greater than the current value of the largest characteristic point do not lead to a prolongation of the dropout time.
Page 169: Settings
2.4 Time Overcurrent Protection for Phase and Residual Currents Addresses of the Addresses of the dynamic Message no. parameters parameters 1. Overcurrent protection for phase currents 20xx 21xx 023.xxxx(.01) 2. Overcurrent protection for phase currents 30xx 31xx 207.xxxx(.01) 3. Overcurrent protection for phase currents 32xx 33xx 209.xxxx(.01)
Page 170 2 Functions Addr. Parameter Setting Options Default Setting Comments 2021 0.10 .. 4.00 A 2.00 A Ip Pickup 0.50 .. 20.00 A 10.00 A 2022 0.10 .. 4.00 I/InS 2.00 I/InS Ip Pickup 0.05 .. 3.20 sec; ∞ 2023 T Ip 0.50 sec T Ip Time Dial 0.50 ..
Page 171: Information List
2.4 Time Overcurrent Protection for Phase and Residual Currents Addr. Parameter Setting Options Default Setting Comments 2121 0.10 .. 4.00 A 4.00 A Ip Pickup 0.50 .. 20.00 A 20.00 A 2122 0.10 .. 4.00 I/InS 4.00 I/InS Ip Pickup 0.05 ..
Page 172: Time Overcurrent Protection For Residual Current
2 Functions 2.4.3 Time Overcurrent Protection for Residual Current The function and operation of the definite-time overcurrent protection and of the inverse-time overcurrent protection for residual current is discussed in detail in the section „Time Overcurrent Protection - General“ above (see subsection 2.4.1). The fol- lowing paragraphs contain the specific information for setting the overcurrent protec- tion for residual current 3I0 O/C.
Page 173 2.4 Time Overcurrent Protection for Phase and Residual Currents In address 2202 InRushRest. 3I0 inrush restraint (inrush restraint with 2nd har- monic) is enabled or disabled. Set ON if the residual current stage of the time overcur- rent protection is applied at the supply side of a transformer whose starpoint is earthed.
Page 174 2 Functions Inverse Time Over- The inverse time stage, depending on the configuration of the functional scope, address 122 (see 2.1.3.1), enables the user to select different characteristics. current Stage3I0p with IEC Character- With the IEC characteristics (address 122 DMT/IDMT 3I0 = TOC IEC) the following istics options are available at address 2226 IEC CURVE: •...
Page 175 2.4 Time Overcurrent Protection for Phase and Residual Currents This means that a pickup will only occur if a current of about 1.1 times the setting value is present. The current value is set in address 2221 or 2222 3I0p. The most relevant for this setting is the minimum appearing earth fault current.
Page 176: Settings
2 Functions protection is activated on the earthed supply side, this inrush restraint is required. Function parameters of the inrush restraint are set in „Inrush“. The inrush restraint is based on the evaluation of the 2nd harmonic present in the inrush current.
Page 177 2.4 Time Overcurrent Protection for Phase and Residual Currents Addr. Parameter Setting Options Default Setting Comments 0.05 .. 35.00 A; ∞ 2211 3I0>> 1.00 A 3I0>> Pickup 0.25 .. 175.00 A; ∞ 5.00 A 0.05 .. 35.00 I/InS; ∞ 1.00 I/InS 2212 3I0>>...
Page 178: Information List
2 Functions Addr. Parameter Setting Options Default Setting Comments 2321 3I0p 0.05 .. 4.00 A 1.00 A 3I0p Pickup 0.25 .. 20.00 A 5.00 A 2322 3I0p 0.05 .. 4.00 I/InS 1.00 I/InS 3I0p Pickup 0.05 .. 3.20 sec; ∞ 2323 T 3I0p 0.50 sec...
Page 179: Time Overcurrent Protection For Earth Current
2.5 Time Overcurrent Protection for Earth Current Time Overcurrent Protection for Earth Current 2.5.1 General The time overcurrent protection for earth current is assigned to a 1-phase measured current input of the device. It can be used for any desired single-phase application. Its preferred application is the detection of an earth current between the starpoint of a pro- tective object and its earth electrode (that's why the description).
Page 180 2 Functions Pickup, Trip Two definite time stages are available for the earth current. For the IE>> stage, the current measured at the assigned 1-phase current input is compared with the setting value IE>>. Current above the pickup value is detected and annunciated.
Page 181: Inverse Time Overcurrent Protection
2.5 Time Overcurrent Protection for Earth Current Figure 2-79 Logic diagram of the overcurrent stage I > for earth current (simplified) 2.5.3 Inverse Time Overcurrent Protection The inverse time overcurrent stage operates with a characteristic either according to the IEC- or the ANSI-standard or to a user-defined characteristic. The characteristics and their equations are given in the „Technical Data“.
Page 182 2 Functions Figure 2-80 Logic Diagram of the Inverse Overcurrent Protection for Earth Currents — example of IEC characteristic (simplified) Dropout You can determine whether the dropout of the stage is to follow right after the thresh- old undershot or whether it is evoked by disk emulation. "Right after" means that the pickup drops out when approx.
Page 183: Manual Close Command
2.5 Time Overcurrent Protection for Earth Current User-defined Char- When user-defined curves are utilised, the tripping curve may be defined point by acteristics point. Up to 20 pairs of values (current, time) may be entered. The device then approx- imates the characteristics by linear interpolation. If required, the dropout characteristic can also be defined (see function description for „Dropout“.
Page 184: Setting Notes
2 Functions Figure 2-81 Logic diagram of the inrush restraint feature (simplified) 2.5.7 Setting Notes General Note The first time overcurrent protection for earth current is described in the setting instruc- tions. The parameter addresses and message numbers of the second and third time overcurrent protection are described at the end of the setting instructions under „Ad- ditional Time Overcurrent Protection Functions for Earth Current“.
Page 185 2.5 Time Overcurrent Protection for Earth Current If time overcurrent protection is applied on the feeding side of a transformer, select the higher stage IE>>, which does not pick up by the inrush current or set the manual close feature to Inactive. At address 2402 InRushRestEarth inrush restraint (inrush restraint with 2nd har- monic) is enabled or disabled.
Page 186 2 Functions If the inverse time trip characteristic is selected, it must be noted that a safety factor of about 1.1 has already been included between the pickup value and the setting value. This means that a pickup will only occur if a current of about 1.1 times of the setting value is present.
Page 187 2.5 Time Overcurrent Protection for Earth Current Since this stage also picks up with earth faults in the network, the time delay (address 2423 D IEp) has to be coordinated with the grading coordination chart of the network for earth faults. In most cases, shorter tripping times than for phase currents may be set since a galvanic separation of the zero sequence systems of the connected power system sections is ensured by a transformer with separate windings.
Page 188: Settings
2 Functions If the current exceeds the value indicated in address 2442 I Max InRr. E, no re- straint will be provoked by the 2nd harmonic. Additional Overcur- In the aforementioned description, the first overcurrent protection is described respec- rent Protection tively.
Page 189: Information List
2.5 Time Overcurrent Protection for Earth Current Addr. Parameter Setting Options Default Setting Comments 2426 ANSI CURVE Very Inverse Very Inverse ANSI Curve Inverse Short Inverse Long Inverse Moderately Inv. Extremely Inv. Definite Inv. 1.00 .. 20.00 I/Ip; ∞ 2431 I/IEp PU T/TEp Pickup Curve IE/IEp - 0.01 ..
Page 190 2 Functions Information Type of In- Comments formation 024.2522 IE> picked up IE> picked up 024.2523 IEp picked up IEp picked up 024.2524 IE> InRush PU IE> InRush picked up 024.2525 IEp InRush PU IEp InRush picked up 024.2529 Earth InRush PU Earth InRush picked up 024.2541 IE>>...
Page 191: Dynamic Cold Load Pickup For Time Overcurrent Protection
2.6 Dynamic Cold Load Pickup for Time Overcurrent Protection Dynamic Cold Load Pickup for Time Overcurrent Protection With the dynamic cold load pickup feature, it is possible to dynamically increase the pickup values of the time overcurrent protection stages when dynamic cold load over- current conditions are anticipated, i.e.
Page 192 2 Functions made with the „normal“ setpoints. The function is inactive and the fast reset time, if ap- plied, is reset. If overcurrent elements are picked up while Active Time is running, the fault gener- ally prevails until pickup drops out, using the dynamic pickup values. Only then are the parameters set back to „normal“.
Page 193: Setting Notes
2.6 Dynamic Cold Load Pickup for Time Overcurrent Protection Figure 2-83 Logic diagram for dynamic cold load pickup feature — illustrated for phase overcurrent protection stage on side 1 (simplified) 2.6.2 Setting Notes General Dynamic cold load pickup can only be enabled if during configuration of the functional scope was set at the address 117 COLDLOAD PICKUP.
Page 194: Settings
2 Functions rion, the feedback information of the assigned breaker must inform the device about the breaker position. The time overcurrent protection for earth current allows the breaker criterion only if an unequivocal relationship exists between its assigned side or measuring location and the feedback information of the breaker (SwitchgCBaux S1, SwitchgCBaux S2 to SwitchgCBaux M5, addresses 831 to 840).
Page 195: Information List
2.6 Dynamic Cold Load Pickup for Time Overcurrent Protection 2.6.4 Information List Information Type of In- Comments formation 025.2413 I Dyn.set. ACT Dynamic settings O/C Phase are ACTIVE 026.2413 IE Dyn.set. ACT Dynamic settings O/C Earth are ACTIVE 049.2404 >BLOCK CLP >BLOCK Cold-Load-Pickup 049.2411 CLP OFF Cold-Load-Pickup switched OFF...
Page 196: Single-Phase Time Overcurrent Protection
2 Functions Single-Phase Time Overcurrent Protection The single-phase time overcurrent protection can be assigned to either of the single- phase measured additional current inputs of the device. This may be a „normal“ input or a high-sensitivity input. In the latter case, a very sensitive pickup threshold is pos- sible (smallest setting 3 mA at the current input).
Page 197 2.7 Single-Phase Time Overcurrent Protection Figure 2-84 Two-stage tripping characteristic of the single-phase time overcurrent protec- tion Figure 2-85 Logic diagram of the single-phase overcurrent protection — example for detection of the current at input II 7UT613/63x Manual C53000-G1176-C160-2...
Page 198: High-Impedance Differential Protection
2 Functions 2.7.2 High-impedance Differential Protection Application With the high-impedance scheme all current transformers at the limits of the protection Example zone operate parallel to a common relatively high-ohmic resistance R whose voltage is measured. With 7UT613/63x the voltage is registered by measuring the current through the external resistor R at the high-sensitivity single-phase current measuring input.
Page 199 2.7 Single-Phase Time Overcurrent Protection Figure 2-87 Earth fault protection using the high-impedance principle In case of an earth fault in the protection zone (figure2-87 right) a starpoint current I will certainly be present. The earthing conditions in the rest of the network determine how strong a zero sequence current from the system is.
Page 200: Tank Leakage Protection
2 Functions For protection against overvoltages it is also important that the device is directly con- nected to the earthed side of the current transformers so that the high voltage at the resistor can be kept away from the device. For generators, motors and shunt reactors high-impedance differential protection can be used analogously.
Page 201 2.7 Single-Phase Time Overcurrent Protection Protection Functions“) and the properties of the 1-phase measuring inputs (section 2.1.4 under „Topology of the Protected Object“, margin heading „High-sensitive 1-phase Additional Measuring Inputs“). • If you have declared the type of the corresponding 1-phase current input as (ad- dress 255 and/or 256) as 1A/5A input, set the pickup value 1Phase I>>...
Page 202 2 Functions The internal burden is often stated in the test report of the current transformer. If not known, it can be derived from a DC measurement on the secondary winding. Calculation Example: = 0.3 Ω Current transformer 800/5; 5P10; 30 VA with R = 5 Ω...
Page 203 2.7 Single-Phase Time Overcurrent Protection The voltage across R is then · ( 2R Furthermore, it is assumed that the pickup value of the 7UT613/63x corresponds to half the knee-point voltage of the current transformers. The extreme case is thus This results in a stability limit I , i.e.
Page 204 2 Functions The required short-term power of the resistor is derived from the knee-point voltage and the resistance: As this power only appears during earth faults for a short period of time, the rated power can be smaller by approx. factor 5. The varistor (see figure below) must be dimensioned in such manner that it remains high-ohmic up to the knee-point voltage, e.g.
Page 205: Settings
2.7 Single-Phase Time Overcurrent Protection Note In the following parameter overview the addresses 2703 and 2706 apply to a high- sensitive current measuring input and are independent from the rated current. 2.7.5 Settings The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer.
Page 206: Unbalanced Load Protection
2 Functions Unbalanced Load Protection Unbalanced load protection (negative sequence protection) detects unbalanced loads on the system. In addition, this protection function may be used to detect interruptions, faults, and polarity problems with current transformers. Furthermore, it is useful in de- tecting phase-to-earth, phase-to-phase, and double phase-to-earth faults with magni- tudes lower than the maximum load current.
Page 207 2.8 Unbalanced Load Protection Figure 2-92 Tripping characteristic of the definite time unbalanced load protection Inverse Time Stage The inverse time overcurrent stage operates with a tripping characteristic either ac- cording to the IEC or the ANSI standard. The characteristics and their equations are given in the „Technical Data“.
Page 208 2 Functions Figure 2-93 Inverse time characteristic for unbalanced load protection Dropout It can be determined whether the dropout of the stage is to follow right after the thresh- old undershot or whether it is evoked by disk emulation. "Right after" means that the pickup drops out when approx.
Page 209 2.8 Unbalanced Load Protection Figure 2-94 Logic diagram of the unbalanced load protection - illustrated for IEC characteristic Thermal Stage With the aid of the thermal stages the unbalanced load protection can be well adapted to the thermal loading of the electrical motor rotor during asymmetric load. Pickup, Warning The permissible continuous load imbalance is determined with the setting „I2 Permis- sible“.
Page 210 2 Functions Thermal Characteris- The thermal characteristic allows an approximate calculation of the thermal loading of the electrical motor rotor by load imbalance in the stator. This follows the simplified equation: with: Tripping time Asymmetry factor Negative sequence current Rated current of the protective object N Obj The asymmetry factor K designates how long a negative sequence current may flow at nominal machine current.
Page 211 2.8 Unbalanced Load Protection Figure 2-95 Resulting characteristic of the thermal asymmetrical load protection Logic Figure 2-96 shows the logic diagram for the breaker failure protection with the thermal stage and the definite time I >> stage. The I > stage is not represented. It is available in this operating mode, but is generally not required because an own warning level is available.
Page 212: Setting Notes
2 Functions Figure 2-96 Logic diagram of the asymmetrical load protection - illustrated for the thermal stage with I>> stage (simpli- fied) 2.8.2 Setting Notes General Unbalanced load protection only makes sense with three-phase protected objects. For PROT. OBJECT = 1ph Busbar or 1 phase transf. (address 105) the following settings are not available.
Page 213 2.8 Unbalanced Load Protection The unbalanced load protection must have been assigned to a side of the main pro- tected object or another 3-phase current measuring location (Subsection 2.1.4 under margin heading „Further 3-Phase Protection Functions“). Consider also the assign- ment of the measured current inputs of the device against the measuring locations (current transformer sets) of the power plant (section 2.1.4 under margin heading „As- signment of 3-phase Measuring Locations“).
Page 214 2 Functions for 1-pole faults: I2> = 0.1 A, i.e. earth fault current as from approx. 0.3 A. = 5 A results in 5 times the secondary value. Consider the current transformer ratios when setting the device with primary values. For a power transformer, unbalanced load protection may be used as sensitive pro- tection for low magnitude phase-to-earth and phase-to-phase faults.
Page 215 2.8 Unbalanced Load Protection I2>> = 0.55 · 545 A = 300 A primary or Setting 0.55· 545 A · (1/600) = 0.50 A secondary Delay T I2>> = 1 s The inverse curves (see below) permit a consideration of load imbalance per unit of time.
Page 216 2 Functions This means that a pickup will only occur if an unbalanced load of about 1.1 times the setting value of I2p (address 4021 or 4022) is present. The corresponding time multiplier is accessible via address 4024 D I2p. The time multiplication factor may also be set to ∞.
Page 217 2.8 Unbalanced Load Protection In example, figure 2-97, the permanently permissible asymmetrical load amounts to 11 % of the machine internal current and the K-factor K = 20. As the relevant measur- ing location for asymmetrical load is usually assigned to the side of the machine to be protected, the setting can be effected directly under address 4034 FACTOR K: FACTOR K = 20.
Page 218: Settings
2 Functions heatup time of the object to be protected. There is the following connection between the asymmetrical factor K and the cool-down time: Example: For asymmetry factor K = 20 s and a permanently permissible asymmetrical load of = 11 % a corresponding cool-down time is derived This value does not depend on whether the respective values were set to secondary values, as the current transformation ratios are reduced in numerator and denomina- tor.
Page 219: Information List
2.8 Unbalanced Load Protection Addr. Parameter Setting Options Default Setting Comments 0.50 .. 15.00 ; ∞ 4024 D I2p 5.00 D I2p Time Dial 4025 I2p DROP-OUT Instantaneous Instantaneous I2p Drop-out Characteris- Disk Emulation 4026 IEC CURVE Normal Inverse Extremely Inv. IEC Curve Very Inverse Extremely Inv.
Page 220: Thermal Overload Protection
2 Functions Thermal Overload Protection The thermal overload protection prevents damage to the protected object caused by thermal overloading, particularly in case of transformers, rotating machines, power re- actors and cables. This protection is not applicable to single-phase busbar protection. It can be assigned to any of the sides of the main protected object, however, not to a non-assigned measuring point.
Page 221 2.9 Thermal Overload Protection The protection function thus represents a thermal profile of the equipment being pro- tected (overload protection with memory capability). Both the previous history of an overload and the heat loss to the environment are taken into account. In steady-state operation the solution of this equation is in an e-function whose asymp- tote represents the final temperature Θ...
Page 222 2 Functions Motor Startup On startup of electrical machines the overtemperature calculated by the thermal replica may exceed the alarm overtemperature or even the trip overtemperature. In order to avoid an alarm or trip, the starting current is acquired and the resulting in- crease of temperature rise is suppressed.
Page 223: Overload Protection Using A Thermal Replica With Ambient Temperature Influence
2.9 Thermal Overload Protection 2.9.3 Overload protection using a thermal replica with ambient temperature influence Principle The calculation basis is based on those of the overload protection, according to Section „Overload protection with Thermal Replica“, the ambient temperature, usually the coolant temperature, is however taken into consideration. The ambient or coolant temperature has to be measured with a temperature detector in the protected object.
Page 224 2 Functions If extra liquid coolants are available, the following types of coolants can be used: • ON (Oil Nnatural = (naturally circulating oil): Because of emerging differences in temperature the coolant (oil) moves within the tank. The cooling effect is not very intense due to its natural convection.
Page 225 2.9 Thermal Overload Protection The life-time of a cellulose insulation refers to a temperature of 98 °C or 208.4 °F in Ageing Rate Calcu- lation the direct environment of the insulation. Experience shows that an increase of 6K means half the life-time. For a temperature which defers from the basic value of 98 °C (208.4 °F), the relative ageing rate B is given by The mean value of the relative ageing rate L is given by the calculation of the mean value of a certain period of time, i.e.
Page 226: Setting Notes
2 Functions 2.9.5 Setting Notes General Note The first thermal overload protection is described in the setting instructions. The pa- rameter addresses and message numbers of the second thermal overload protection are described at the end of the setting instructions under „Additional Thermal Overload Protection Functions“.
Page 227 2.9 Thermal Overload Protection tables. As the nominal data of the protected object and the current transformer ratios are known to the device, the K-FACTOR can be set immediately. When using the method with hot-spot calculation according to IEC 60354, setting K- FACTOR = 1 is advisable as all remaining parameters refer to the rated current of the assigned side of the protected object.
Page 228 2 Functions Environment Tem- If the environmental or coolant temperature must be taken into consideration in the perature Influence thermal replica, the device must be informed as to which of the temperature detectors in Thermal Replica (RTD = Resistance Temperature Detector) is applicable. With RTD-box 7XV5662– xAD up to 6 detectors are possible, with 2 boxes up to 12.
Page 229 2.9 Thermal Overload Protection that corresponds with the setting in accordance with the functional scope (section 2.1.3.1) under address 191 RTD CONNECTION. The characteristic values of the temperature detectors are set separately, see section RTD-boxes 2.10). Hot-Spot Stages There are two annunciation stages for hot-spot temperature. To set a specific hot-spot temperature value (expressed in °C), which is meant to generate the warning signal (stage 1), use address 4222 HOT SPOT ST.
Page 230: Settings
2 Functions 2.9.6 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings. Addr. Parameter Setting Options Default Setting Comments 4201 THERM. OVERLOAD Thermal Overload Protection Block relay Alarm Only 4202 K-FACTOR 0.10 .. 4.00 1.10 K-Factor 4203...
Page 231: Information List
2.9 Thermal Overload Protection 2.9.7 Information List Information Type of In- Comments formation 044.2404 >BLK ThOverload >BLOCK Thermal Overload Protection 044.2411 Th.Overload OFF Thermal Overload Protection OFF 044.2412 Th.Overload BLK Thermal Overload Protection BLOCKED 044.2413 Th.Overload ACT Thermal Overload Protection ACTIVE 044.2421 O/L Th.
Page 232: Rtd-Boxes For Overload Detection
2 Functions 2.10 RTD-Boxes for Overload Detection For thermal overload protection, taking into consideration the ambient or coolant tem- perature as well as the overload protection with hot-spot calculation and relative ageing rate determination, the coolant temperature in the protected object or the tem- perature of the hottest spot of the winding (e.g.
Page 233: Settings
2.10 RTD-Boxes for Overload Detection 2.10.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings. Addr. Parameter Setting Options Default Setting Comments Pt 100 Ω 9011A RTD 1 TYPE Not connected RTD 1: Type Pt 100 Ω...
Page 234 2 Functions Addr. Parameter Setting Options Default Setting Comments -58 .. 482 °F; ∞ 212 °F 9034 RTD 3 STAGE 1 RTD 3: Temperature Stage 1 Pickup -50 .. 250 °C; ∞ 120 °C 9035 RTD 3 STAGE 2 RTD 3: Temperature Stage 2 Pickup -58 ..
Page 235 2.10 RTD-Boxes for Overload Detection Addr. Parameter Setting Options Default Setting Comments -50 .. 250 °C; ∞ 100 °C 9063 RTD 6 STAGE 1 RTD 6: Temperature Stage 1 Pickup -58 .. 482 °F; ∞ 212 °F 9064 RTD 6 STAGE 1 RTD 6: Temperature Stage 1 Pickup -50 ..
Page 236 2 Functions Addr. Parameter Setting Options Default Setting Comments 9092A RTD 9 LOCATION Other RTD 9: Location Ambient Winding Bearing Other -50 .. 250 °C; ∞ 100 °C 9093 RTD 9 STAGE 1 RTD 9: Temperature Stage 1 Pickup -58 .. 482 °F; ∞ 212 °F 9094 RTD 9 STAGE 1...
Page 237: Information List
2.10 RTD-Boxes for Overload Detection Addr. Parameter Setting Options Default Setting Comments 9121A RTD12 TYPE Not connected Not connected RTD12: Type Pt 100 Ω Ni 120 Ω Ni 100 Ω 9122A RTD12 LOCATION Other RTD12: Location Ambient Winding Bearing Other -50 ..
Page 238 2 Functions Information Type of In- Comments formation 14183 RTD 8 St.2 p.up RTD 8 Temperature stage 2 picked up 14191 Fail: RTD 9 Fail: RTD 9 (broken wire/shorted) 14192 RTD 9 St.1 p.up RTD 9 Temperature stage 1 picked up 14193 RTD 9 St.2 p.up RTD 9 Temperature stage 2 picked up...
Page 239: Overexcitation Protection
2.11 Overexcitation Protection 2.11 Overexcitation Protection The overexcitation protection is used to detect increased overflux or overinduction conditions in generators and transformers, especially in power station unit transform- ers, which cause impermissible temperature rise in the iron. An increase in induction above the rated value leads very quickly to saturation of the iron core and to large eddy current losses which cause impermissible temperature rise in the iron.
Page 240 2 Functions U/f >>) has been exceeded, another pickup indication is output and a timer T U/f >> starts. A trip command is issued subsequent to the expiration of this timer. Figure 2-99 Logic diagram of the overexcitation protection (simplified) The thermal replica is realised by a counter which is incremented in accordance with the value U/f calculated from the measured voltages.
Page 241: Setting Notes
2.11 Overexcitation Protection 2.11.2 Setting Notes General A precondition for use of the overexcitation protection is that measured voltages are connected to the device and that a 3-phase protected object has been selected during configuration of the protection functions. Additionally, the overexcitation protection can only operate if it has been configured under address143 OVEREXC.
Page 242 2 Functions If no instructions of the manufacturer are available, the preset standard characteristic should be used; this corresponds to a standard Siemens transformer (figure 2-100). Figure 2-101 Tripping time characteristic of the overexcitation protection Otherwise, any tripping characteristic can be specified by point-wise entering the delay times for the 8 predefined U/f-values: Address 4306 t(U/f=1.05)
Page 243: Settings
2.11 Overexcitation Protection Address 4310 t(U/f=1.25) Address 4311 t(U/f=1.30) Address 4312 t(U/f=1.35) Address 4313 t(U/f=1.40) As mentioned above, the thermal characteristic is effective only if the pickup threshold U/f> is exceeded. Figure 2-101 illustrates the behaviour of the protection on the as- sumption that the setting for the pickup threshold was chosen higher or lower than the first setting value of the thermal characteristic.
Page 244: Information List
2 Functions 2.11.4 Information List Information Type of In- Comments formation 5353 >U/f BLOCK >BLOCK overexcitation protection 5357 >RM th.rep. U/f >Reset memory of thermal replica U/f 5361 U/f> OFF Overexcitation protection is swiched OFF 5362 U/f> BLOCKED Overexcitation protection is BLOCKED 5363 U/f>...
Page 245: Reverse Power Protection
2.12 Reverse Power Protection 2.12 Reverse Power Protection Reverse power protection is used to protect a turbo-generator unit on failure of energy to the prime mover when the synchronous generator runs as a motor and drives the turbine taking motoring energy from the network. This condition endangers the turbine blades the and must be interrupted within a short time by tripping the network circuit- breaker.
Page 246: Setting Notes
2 Functions turbine emergency tripping a short delay T-SV-CLOSED is, however, sufficient. The state of the emergency tripping valve must then be given to the device via a binary input "RLS Fast". The delay time T-SV-OPEN is still effective as back-up stage. In other applications only the delay T-SV-OPEN is generally needed, as they act inde- pendently to the mentioned binary input.
Page 247 2.12 Reverse Power Protection Pickup Value In case of a reverse power, the turbine set must be disconnected from the system as the turbine operation is not permissible without a certain minimum steam throughout (cooling effect). In case of a gas turbine set, the motor load can also become too heavy for the network.
Page 248 2 Functions active power referenced to the rated apparent power of the protected object Nominal apparent power of protected object N Obj Example: Generator 5.27 MVA 6.3 kV Current transformer 500 A/5 A Voltage transformer 6300 V/100 V perm. reverse power 3 % = 0.03 In case of setting related to address 5012 Pr pick-up =...
Page 249: Settings
2.12 Reverse Power Protection short tripping times. This parameter can only be altered in DIGSI at Additional Set- tings. If a delay time is set to ∞, not trip is caused by this time, the pickup by reverse power is however indicated. 2.12.3 Settings Addresses which have an appended "A"...
Page 250: Forward Power Supervision
2 Functions 2.13 Forward Power Supervision The forward power supervision monitors wether the active power undershoots one set value or overshoots a separate second value. Each of these functions can initiate dif- ferent control functions. When, for example, with generators operating in parallel, the active power output of one machine becomes so small that other generators could take over this power, then it is often appropriate to shut down the lightly loaded machine.
Page 251: Setting Notes
2.13 Forward Power Supervision broken wire or voltage failure is recognised or voltage transformer protection breaker failure (via the respective binary input) is indicated (see also Subsection "Technical Data"). Figure 2-103 Logic diagram of the forward active power supervision 2.13.2 Setting Notes General The application of forward power monitoring is only possible in 3-phase protected ob- jects.
Page 252 2 Functions power of the respective side), thus under address 5112 P< fwd for undershooting of active power and under address 5115 P> fwd for exceeding of active power. If, however, the forward power monitoring must be set in amps secondary, the active power must be converted to a secondary value.
Page 253: Settings
2.13 Forward Power Supervision Delay Times The setting of the delay times depend on the application. In the example of transformer switchover or also in case of generator switchover, a long delay (up to one minute = 60 s) will be set so that short-term load fluctuations do not result in repeated switcho- ver.
Page 254: Information List
2 Functions 2.13.4 Information List Information Type of In- Comments formation 5113 >Pf BLOCK >BLOCK forward power supervision 5116 >Pf< BLOCK >BLOCK forw. power superv. Pf< stage 5117 >Pf> BLOCK >BLOCK forw. power superv. Pf> stage 5121 Pf OFF Forward power supervis. is switched OFF 5122 Pf BLOCKED Forward power supervision is BLOCKED...
Page 255: Undervoltage Protection
2.14 Undervoltage Protection 2.14 Undervoltage Protection Undervoltage protection detects voltage dips in electrical machines and avoids inad- missible operating states and possible loss of stability in electrical devices. The stabil- ity and permissible torque thresholds of an induction machine is affected by undervolt- age.
Page 256: Setting Notes
2 Functions Figure 2-104 Logic diagram of the undervoltage protection 2.14.2 Setting Notes General The application of undervoltage protection is only possible in 3-phase protected ob- jects. Furthermore, it is a prerequisite that the device is connected to a three-phase voltage transformer set.
Page 257: Settings
2.14 Undervoltage Protection The respective delay time T U< (address 5213) is supposed to bridge the permissible short-term voltage dips during continuous undervoltage, which may lead to an unsta- ble operation, however, it is supposed to be switched off within a few seconds. For the U<<...
Page 258 2 Functions Information Type of In- Comments formation 033.2502 >BLOCK U<< >BLOCK undervoltage protection U<< 033.2503 >BLOCK U< >BLOCK undervoltage protection U< 033.2521 U<< picked up Undervoltage U<< picked up 033.2522 U< picked up Undervoltage U< picked up 033.2551 U<< TRIP Undervoltage U<<...
Page 259: Overvoltage Protection
2.15 Overvoltage Protection 2.15 Overvoltage Protection The overvoltage protection has the task of preventing from insulation problems by pro- tecting electrical equipment against inadmissible abnormally high voltage levels. High voltages occur in the power station sector, e.g. caused by incorrect manual op- eration of the excitation system, faulty operation of the automatic voltage regulator, (full) load shedding of a generator, separation of the generator from the system or during island operation.
Page 260: Setting Notes
2 Functions Figure 2-105 Logic diagram of the overvoltage protection 2.15.2 Setting Notes General The application of overvoltage protection is only possible in 3-phase protected objects. Furthermore, it is a prerequisite that the device is connected to a three-phase voltage transformer set.
Page 261: Settings
2.15 Overvoltage Protection busbar, the pickup value must be set as reference value under address 5312 U>, e.g. 1.20. When assigned to a measuring location, the value of phase-phase voltage must be set under address 5311 U> in Volt , e.g. 132. V at U = 110 V (120 % of 110 V).
Page 262: Information List
2 Functions 2.15.4 Information List Information Type of In- Comments formation 034.2404 >BLOCK O/V >BLOCK overvoltage protection 034.2411 Overvolt. OFF Overvoltage protection is switched OFF 034.2412 Overvolt. BLK Overvoltage protection is BLOCKED 034.2413 Overvolt. ACT Overvoltage protection is ACTIVE 034.2491 U> err. Obj. Overvoltage: Not avail.
Page 263: Frequency Protection
2.16 Frequency Protection 2.16 Frequency Protection The frequency protection function detects abnormally high and low frequencies. If the network frequency lies outside the admissible range, appropriate actions are initiated. For generators, e.g. the machine is separated from the network. Network decoupling or load shedding can be initiated in networks.
Page 264 2 Functions Maintaining the pickup is ended if the frequency measurement reads again frequen- cies <66 Hz (or <22 Hz) or the frequency protection is blocked via the indication >FQS. Each frequency stage has a set delay time. Each of the four frequency elements can be blocked individually by binary inputs. The entire frequency protection can be blocked via a binary input.
Page 265: Setting Notes
2.16 Frequency Protection 2.16.2 Setting Notes General The application of frequency protection is only possible in 3-phase protected objects. Furthermore, it is required that the device is connected to a three-phase voltage trans- former. Frequency protection is only in effect and accessible if address 156 was set to FREQUENCY Prot.
Page 266: Settings
2 Functions The following example illustrates a setting of the frequency protection for a generator that indicates a delayed warning at approx. 1 % decreased frequency. In case of a further frequency decrease, the generator is disconnected from the network and finally shut down.
Page 267: Information List
2.16 Frequency Protection Addr. Parameter Setting Options Default Setting Comments 0.00 .. 100.00 sec; ∞ 5644 T f> 10.00 sec Delay time T f> 5651 Umin 10.0 .. 125.0 V; 0 65.0 V Minimum Required Voltage for Operation 5652 U MIN 0.10 ..
Page 268: Circuit Breaker Failure Protection
2 Functions 2.17 Circuit Breaker Failure Protection The circuit breaker failure protection provides rapid back-up fault clearance, in the event that the assigned circuit breaker fails to respond to a protective relay. 7UT613/63xis equipped with two breaker failure protection functions that can be used independently from each other and for different locations of the protected object, i.e.
Page 269 2.17 Circuit Breaker Failure Protection Normally, the breaker will open and interrupt the fault current. The current monitoring stage BF-I> quickly resets (typically AC cycle) and stops the timer T-BF. If the trip command is not executed (in case of breaker failure), current continues to flow and the timer runs to its set limit.
Page 270 2 Functions busbar side is supervised. The adjacent circuit breakers are those of the busbar illus- trated. With generators the breaker failure protection usually affects the network breaker. In cases other than that, the supply side must be the relevant one. Initiation The breaker failure protection can be initiated by internal protective functions of the 7UT613/63x, i.e.
Page 271 2.17 Circuit Breaker Failure Protection After initiation the timer T2 is started. When this time has elapsed, the indication „BF T2-TRIP(bus)“ (Fno 047.2655) appears which is also intended for trip of the adja- cent breakers. With two-stage breaker failure protection the trip command of the initiating protection is repeated in a first stage of the breaker failure protection T1 on the feeder circuit breaker, usually on a second trip coil.
Page 272: Setting Notes
2 Functions 2.17.2 Setting Notes General Note The first circuit breaker failure protection is described in the setting instructions. The parameter addresses and message numbers of the second circuit breaker failure pro- tection are described at the end of the setting instructions under „Additional Circuit Breaker Failure Protection Functions“.
Page 273 2.17 Circuit Breaker Failure Protection initiated also by external trip commands (for the same breaker) the device has to be informed about this trip via the binary input „>BrkFail extSRC“ (No 047.2651). The activation of the relay contact set under START WITH REL., only causes the ini- tiation of the circuit breaker failure protection if this activation is effected simultaneous- ly with the indication (fast indication) of a protection function.
Page 274: Settings
2 Functions The delay time T1 (address 7115) is then set to ∞ since it is not needed. The delay times are determined from the maximum operating time of the feeder circuit breaker, the reset time of the current detectors of the breaker failure protection, plus a safety margin which allows for any tolerance of the delay timers.
Page 275: Information List
2.17 Circuit Breaker Failure Protection 2.17.4 Information List Information Type of In- Comments formation 047.2404 >BLOCK BkrFail >BLOCK Breaker failure 047.2411 BkrFail OFF Breaker failure is switched OFF 047.2412 BkrFail BLOCK Breaker failure is BLOCKED 047.2413 BkrFail ACTIVE Breaker failure is ACTIVE 047.2491 BkrFail Not av.
Page 276: External Trip Commands
2 Functions 2.18 External Trip Commands 2.18.1 Function Description Direct Trip Com- Two desired trip signals from external protection or supervision units can be incorpo- mands rated into the processing of the differential protection 7UT613/63x. The signals are couples into the device via binary inputs. Like the internal protection and supervision signals, they can be annunciated, delayed, transmitted to the output trip relays, or blocked individually.
Page 277: Setting Notes
2.18 External Trip Commands Blocking Signal for For transformers so-called sudden pressure relays (SPR) are occasionally installed in External Faults the tank which are meant to switch off the transformer in case of a sudden pressure increase. Not only transformer failures but also high traversing fault currents originat- ing from external faults can lead to a pressure increase.
Page 278: Information List
2 Functions 2.18.4 Information List Information Type of In- Comments formation 4523 >BLOCK Ext 1 >Block external trip 1 4526 >Ext trip 1 >Trigger external trip 1 4531 Ext 1 OFF External trip 1 is switched OFF 4532 Ext 1 BLOCKED External trip 1 is BLOCKED 4533 Ext 1 ACTIVE...
Page 279: Monitoring Functions
2.19 Monitoring Functions 2.19 Monitoring Functions The device incorporates comprehensive supervision functions which cover both hard- ware and software; the measured values are continuously checked for plausibility, so that the CT circuits are also included in the monitoring system to a large extent. It is also possible to implement trip circuit supervision, using appropriate binary inputs as available.
Page 280: Software Monitoring
2 Functions 2.19.1.2 Software Monitoring Watchdog For the continuous monitoring of the program execution, a time monitoring is incorpo- rated in the hardware (hardware watchdog). The watchdog expires and resets the pro- cessor system causing a complete reboot if the processor fails or when a program loses synchronism.
Page 281 2.19 Monitoring Functions Figure 2-114 Current Symmetry Monitoring Voltage Symmetry In healthy network operation it can be expected that the voltages are nearly balanced. If measured voltages are connected to the device, this symmetry is checked in the device by magnitude comparison. To do this, the phase-to-earth voltages are mea- sured.
Page 282 2 Functions Voltage Sum If measured voltages are connected to the device and these are used, voltage sum supervision is possible. A further prerequisite is that the displacement voltage (e-n voltage of an open delta connection) at the same voltage measuring point is connect- ed to the 4th voltage input U of the device.
Page 283 2.19 Monitoring Functions >0.1 · I ), or no zero crossing is registered. The currents flowing in other phases must not exceed 2 I The differential protection and the restricted earth fault protection are blocked imme- diately in the relevant measuring location. The protection functions which react on un- symmetrical currents are blocked as well provided they are assigned to the defective measuring location: the time overcurrent protection for residual current and the unbal- anced load protection.
Page 284 2 Functions is permanently activated (latching of the voltage criterion after 10 s). Only 10 s after the voltage criterion has been removed by correction of the secondary circuit failure, will the blocking automatically reset, thereby releasing the blocked protection func- tions again.
Page 285: Setting Notes
2.19 Monitoring Functions 7UT613/63x this applies to forward power supervision P< and the undervoltage pro- tection. 2.19.1.4 Setting Notes Measured Value The sensitivity of the measured value monitoring can be changed. Default values are Monitoring set at the factory, which are sufficient in most cases. If especially high operating asym- metry in the currents and/or voltages is to be expected for the application, or if it becomes apparent during operation that certain monitoring functions activate sporad- ically, then the setting should be less sensitive.
Page 286: Settings
2 Functions spective measuring location or side (in case of earth faults, below the smallest fault current). This parameter can only be altered in DIGSI at Additional Settings. In address 8403 FUSE FAIL MON. the fuse-failure monitor, in case of asymmetrical tests, for example can be switched off.
Page 287: Information List
2.19 Monitoring Functions Addr. Parameter Setting Options Default Setting Comments 8133A T Sym. I th. M3 5 .. 100 sec 5 sec Symmetry Iph: Pick-up delay 8141 BAL. I LIMIT M4 0.10 .. 1.00 A 0.50 A Current Balance Monitor Meas.
Page 288: Trip Circuit Supervision
2 Functions 2.19.2 Trip Circuit Supervision The differential protection relay 7UT613/63x is equipped with an integrated trip circuit supervision. Depending on the number of binary inputs with isolated control inputs that are still available, a choice can be made between monitoring with one or two binary inputs.
Page 289 2.19 Monitoring Functions The state where both binary inputs are not activated („L“), is only possible during a short transition phase in intact trip circuits (command relay has issued trip command, but the CB has not yet opened). A continuous state of this condition is only possible when the trip circuit has been in- terrupted, a short-circuit exists in the trip circuit, or battery voltage failure occurs.
Page 290 2 Functions Figure 2-119 Logic diagram of the trip circuit supervision using one binary input Trip relay contact Circuit breaker Circuit breaker trip coil Aux1 Circuit breaker auxiliary contact (make) Aux2 Circuit breaker auxiliary contact (break) Control voltage (trip voltage) Input voltage of binary input Voltage across the substitute resistor Bypass resistor...
Page 291: Setting Notes
2.19 Monitoring Functions 2.19.2.2 Setting Notes During configuration of the scope of functions, the number of binary inputs per trip circuit was set at address 182 Trip Cir. Sup. (see 2.1.3.1). If the allocation of the required binary inputs does not match the selected monitoring mode, a message to that effect appears („TripC ProgFail“).
Page 292: Summary Of The Most Important Monitoring Functions
2 Functions 2.19.3.1 Summary of the most important Monitoring Functions Supervision Possible Causes Fault Reaction Alarm Output Auxiliary voltage failure External (aux. voltage) In- Device out of operation All LEDs dark ) drops ternal (converter) or alarm, if necessary Measured value acqui- Internal (converter or Protection out of opera- LED „ERROR“...
Page 293: Parameterisation Error
2.19 Monitoring Functions Supervision Possible Causes Fault Reaction Alarm Output Broken wire external (current trans- All respective protec- „brk. wire IL1M1“ as allocated former secondary circuit) tion functions are „brk. wire IL2M1“ blocked „brk. wire IL3M1“ „brk. wire IL1M5“ „brk. wire IL3M5“ „brk.
Page 294: Protection Function Control
2 Functions 2.20 Protection Function Control The function logic coordinates the sequence of both the protective and ancillary func- tions, processes the functional decisions, and data received from the system. 2.20.1 Pickup Logic for the Entire Device 2.20.1.1 General Device Pickup The fault detection logic combines the pickup signals of all protection functions.
Page 295: Tripping Logic For The Entire Device
2.20 Protection Function Control 2.20.2 Tripping Logic for the Entire Device 2.20.2.1 General Tripping All tripping signals of the protection functions are OR–combined and lead to the alarm „Relay TRIP“. This can be allocated to an LED or output relay as can be each of the individual trip commands.
Page 296 2 Functions “No Trip no Flag” The recording of indications masked to local LEDs, and the maintenance of spontane- ous indications, can be made dependent on whether the device has issued a trip com- mand. Fault event information is then not output when one or more protection func- tions have picked up due to a fault but no tripping of the 7UT613/63x resulted because the fault was removed by another device (e.g.
Page 297: Disconnection Of Measuring Locations
2.21 Disconnection of Measuring Locations 2.21 Disconnection of Measuring Locations 2.21.1 Functional Description During maintenance work, or when parts of the system are shut down during opera- tion, it is sometimes necessary to suspend the processing of individual measuring lo- cations by the differential protection system.
Page 298 2 Functions The disconnection ends when the binary input is deactivated. This requires, once again, that no current is flowing at the moment the disconnection is ended. One can evade the condition that the disconnection mode can only be started or ended when no current is flowing via the measuring location.
Page 299: Information List
2.21 Disconnection of Measuring Locations 2.21.2 Information List Information Type of In- Comments formation 30080 M1 disconnected Measurment location 1 is disconnected 30081 M2 disconnected Measurment location 2 is disconnected 30082 M3 disconnected Measurment location 3 is disconnected 30083 M4 disconnected Measurment location 4 is disconnected 30084 M5 disconnected...
Page 300: Additional Functions
2 Functions 2.22 Additional Functions The additional functions of the 7UT613/63x differential protection relay include: • processing of messages, • processing of operational measured values, • storage of fault record data. 2.22.1 Processing of Messages 2.22.1.1 General For a detailed fault analysis, information regarding the reaction of the protection device and the measured values following a system fault are of interest.
Page 301 2.22 Additional Functions In the quiescent state, i.e. as long as no system fault is present, the LCD can display selectable operational information (overview of the operational measured values) (de- fault display). In the event of a system fault, information regarding the fault, the so- called spontaneous displays, are displayed instead.
Page 302: Operational Annunciations (Buffer: Event Log)
2 Functions 2.22.1.2 Operational Annunciations (Buffer: Event Log) The operational annunciations contain information that the device generates during operation and on operational conditions. Up to 200 operational annunciations are stored in chronological order in the device. New annunciations are added at the end of the list. If the memory has been exceeded, the oldest annunciation is overwritten for each new message.
Page 303: General Interrogation
2.22 Additional Functions update or initiate one. This can be useful help during operation, testing and commis- sioning. Spontaneous indications can be read out via DIGSI. For more information see the SIPROTEC 4 System Description. 2.22.1.5 General Interrogation The present condition of a SIPROTEC 4 device can be examined with DIGSI by viewing the contents of the General Interrogation.
Page 304 2 Functions A correct display of primary and percentage values requires the complete and correct entry of the topology of the protected object and its rated values, as well as of the transformer ratings. For the measuring locations the primary and secondary measured values as per Table 2-12 are issued.
Page 305 2.22 Additional Functions Table 2-12 Operational measured values (magnitudes) of the measuring locations Measured Values Primary Secondary % referred to IL1M1, IL2M1, IL3M1 Phase currents at the measuring loca- A; kA IL1M2, IL2M2, IL3M2 tions M1 to M3 IL1M3, IL2M3, IL3M3 I1M1, I2M1, 3I0M1 Positive, negative and zero sequence A;...
Page 306 2 Functions In addition to the measured and calculated values at the measuring locations, mea- sured values are output at the sides of the main protected object. This makes if pos- sible to obtain the data relevant for the protected object, even if they are fed to the pro- tected object from several measuring locations, as for example the higher voltage side (S1) of the transformer.
Page 307: Settings
2.22 Additional Functions Table 2-14 Operational measured values (phase relationship) Measured Values Dimension % Conversion ϕIL1M1, ϕIL2M1, ϕIL3M1 Phase angle of the currents at the measuring lo- ° 0° = 0 % ϕIL1M2, ϕIL2M2, ϕIL3M2 cations M1 to M3, referred to I L1M1 360°...
Page 308 2 Functions Information Type of In- Comments formation U2 = U2 (negative sequence) P (active power) Q (reactive power) Freq= Frequency S (apparent power) IL1S1= Operat. meas. current IL1 side 1 IL2S1= Operat. meas. current IL2 side 1 IL3S1= Operat. meas. current IL3 side 1 IL1S2= Operat.
Page 309 2.22 Additional Functions Information Type of In- Comments formation 30669 IL3M2= Operat. meas. current IL3 meas. loc. 2 30670 3I0M2= 3I0 (zero sequence) of meas. loc. 2 30671 I1M2= I1 (positive sequence) of meas. loc. 2 30672 I2M2= I2 (negative sequence) of meas. loc. 2 30673 IL1M3= Operat.
Page 310: Thermal Measurement
2 Functions Information Type of In- Comments formation ϕIL2M1= 30737 Phase angle in phase IL2 meas. loc. 1 ϕIL3M1= 30738 Phase angle in phase IL3 meas. loc. 1 ϕIL1M2= 30739 Phase angle in phase IL1 meas. loc. 2 ϕIL2M2= 30740 Phase angle in phase IL2 meas.
Page 311: Information List
2.22 Additional Functions phase concatenation (D windings). For standard vector groups, this information corre- spond to the ends of the windings. In more unusual vector groups (which are created by phase swapping), the phase assignment in the vector group is not always clear. The thermal values are referred to the tripping temperature rise.
Page 312: Differential And Restraining Measured Values
2 Functions Information Type of In- Comments formation 204.2612 2Θ/ΘtrpL1= Th. O/L 2 Temperature rise for phase L1 204.2613 2Θ/ΘtrpL2= Th. O/L 2 Temperature rise for phase L2 204.2614 2Θ/ΘtrpL3= Th. O/L 2 Temperature rise for phase L3 204.2615 2Θ leg L1= Th.
Page 313: Information List
2.22 Additional Functions Table 2-16 Measured values of differential protection Measured Values % referred to IDiffL1, IDiffL2, IDiffL3 Calculated differential currents of the three phases Operational rated current of the protected object IRESTL1, IRESTL2, IRESTL3 Calculated restraining currents of the three phases Operational rated current of the protected object IDiffREF...
Page 314: Energy Metering
2 Functions 2.22.6 Energy Metering Metered values for active and reactive power are determined in the background by the processor system. They can be called up at the front of the device, read out via the operating interface using a PC with DIGSI, or transferred to a central master station via the system interface.
Page 315: Information List
2.22 Additional Functions 2.22.6.2 Information List Information Type of In- Comments formation Meter res IntSP_Ev Reset meter Wp(puls)= Pulsed Energy Wp (active) Wq(puls)= Pulsed Energy Wq (reactive) Wp∆= Increment of active energy Wq∆= Increment of reactive energy Wp+= MVMV Wp Forward Wq+= MVMV Wq Forward...
Page 316 2 Functions currents, then that exact size can be evaluated and the violation of the limit value con- dition can be further processed. Th settings are independent. Derived (calculated) sizes can also be evaluated. Should the positive sequence system from the three phase currents be evaluated, the positive sequence system is calculated from the three analogue input quantities (phase currents) and used as eval- uated quantity.
Page 317: Setting Notes
2.22 Additional Functions Blocking an overcurrent time protection time function can thus be done after detection of inrush currents. The detection of inrushes is functional part of the time overcurrent protection, as per Section 2.4.2. A dynamic cold load pickup can be achieved by twice creating a flexible protective function (time overcurrent protection) with different pickup values.
Page 318 2 Functions • Current I1..I12, if single-phase currents at single-phase additional measuring inputs must be evaluated. Only 3 additional measuring inputs are possible for 7UT613 and 7UT633. Only 1 single-phase additional measuring input is possible for 7UT635, if 5 three-phase inputs have been configured. •...
Page 319 2.22 Additional Functions Furthermore, it can be determined how the currents shall be processed. The respec- tive phase currents can be evaluated jointly or individually or by means of the symmet- rical component calculated from the three phase currents (the latter does not apply to single-phase CT): •...
Page 320 2 Functions and the voltages assigned to the currents. Power functions are only possible if the device has voltage inputs. Set the measuring type for the power functions. Please note that this option has a re- spectively higher operating time due to the averaging over 16 periods. Short trip times are possible with this option as the power is determined over one period only.
Page 321: Settings
2.22 Additional Functions Apart from internal blockings that, for example, are activated outside the working range of the functions, internal monitoring of the measured values can lead to the blocking of a flexible function. If a flexible function has been configured in such manner that it reacts on the process- ing of voltages (voltage or power), a blocking on failure of measured voltages can be effected.
Page 322 2 Functions Addr. Parameter Setting Options Default Setting Comments Pick-up thresh. 0.05 .. 35.00 A 2.00 A Pick-up threshold I3 0.25 .. 175.00 A 10.00 A 0.1A 0.005 .. 3.500 A 0.200 A Pick-up thresh. 0.05 .. 35.00 A 2.00 A Pick-up threshold I4 0.25 ..
Page 323 2.22 Additional Functions Addr. Parameter Setting Options Default Setting Comments Pick-up thresh. 0.01 .. 17.00 P/SnS 1.10 P/SnS Pick-up threshold P-side Pick-up thresh. 1.7 .. 3000.0 VAR 200.0 VAR Pick-up threshold Q meas. location 8.5 .. 15000.0 VAR 1000.0 VAR Pick-up thresh.
Page 324: Information List
2 Functions Addr. Parameter Setting Options Default Setting Comments Func. assigned I-CT 1 I-CT 1 Function is applied to I-CT 2 I-CT 3 I-CT 4 I-CT 5 I-CT 6 I-CT 7 I-CT 8 I-CT 9 I-CT 10 I-CT 11 I-CT 12 Func.
Page 325: Oscillographic Fault Recording
2.22 Additional Functions Information Type of In- Comments formation 235.2125 $00 Time Out Function $00 TRIP Delay Time Out 235.2126 $00 TRIP Function $00 TRIP 235.2128 $00 inval.set Function $00 has invalid settings 235.2701 >$00 Blk Trip12 >Function $00 block TRIP L12 235.2702 >$00 Blk Trip23 >Function $00 block TRIP L23 235.2703 >$00 Blk Trip31...
Page 326: Setting Notes
2 Functions Where transfer to a central device is possible, the request for data transfer can be ex- ecuted automatically. It can be selected to take place after each protection pickup or after a trip only. 2.22.8.2 Setting Notes Other settings pertaining to fault recording (waveform capture) are found in the submenu Oscillographic Fault Records of the Settings menu.
Page 327: Information List
2.22 Additional Functions 2.22.8.4 Information List Information Type of In- Comments formation FltRecSta IntSP Fault Recording Start >Trig.Wave.Cap. >Trigger Waveform Capture 30053 Fault rec. run. Fault recording is running 2.22.9 Commissioning Aids For commissioning of the device, a comprehensive commissioning and monitoring tool is available.
Page 328 2 Functions Figure 2-125 Phasor Diagram of the Secondary Measured Values — Example 7UT613/63x Manual C53000-G1176-C160-2...
Page 329: Average Values, Minimum And Maximum Values
2.23 Average Values, Minimum and Maximum Values 2.23 Average Values, Minimum and Maximum Values Average, minimum and maximum values, minimum and maximum values of average values, long-term average values, are calculated by the 7UT613/63x and can be read out with the time reference (date and time of the last update). The defined values of the average values and minimum and maximum values are to be defined and up to 20 calculation units can be created with the help of DIGSI under menu item „Extended Measuring Values 1-20“...
Page 330: Demand Measurement Setup
2 Functions 2.23.1 Demand Measurement Setup 2.23.1.1 Setting Notes Mean Value Forma- The synchronisation instant within one hour, the time interval and the time interval for tion averaging can be set via parameters. The selection of the time period for measured value averaging is set with parameter 7611 DMD Interval in the corresponding setting group from A to D under MEA- SUREMENT.
Page 331: Settings
2.23 Average Values, Minimum and Maximum Values 2.23.2.2 Settings Addr. Parameter Setting Options Default Setting Comments 7621 MinMax cycRESET Automatic Cyclic Reset Function 7622 MiMa RESET TIME 0 .. 1439 min 0 min MinMax Reset Timer 7623 MiMa RESETCYCLE 1 .. 365 Days 7 Days MinMax Reset Cycle Period 7624...
Page 332: Command Processing
2 Functions 2.24 Command Processing ® A control command process is integrated in the SIPROTEC 7UT613/63x to coordi- nate the operation of circuit breakers and other equipment in the power system. Control commands can originate from four command sources: • Local operation using the keypad on the local user interface of the device ®...
Page 333: Sequence In The Command Path
2.24 Command Processing 2.24.1.2 Sequence in the Command Path Security mechanisms in the command path ensure that a switch command can be carried out only if the test of previously established criteria has been successfully com- pleted. Additionally, user-defined interlocking conditions can be configured separately for each device.
Page 334: Interlocking
2 Functions 2.24.1.3 Interlocking Interlocking can be executed by the user-defined logic (CFC). Switchgear interlocking checks in a SICAM/SIPROTEC 4 system are normally divided in the following groups: • System interlocking checked by a central control system (for interbay interlocking), •...
Page 335 2.24 Command Processing The plus sign indicated in the indication is a confirmation of the command execution: The command output has a positive result, as expected. A minus sign means a neg- ative, i.e. an unexpected result; the command was rejected. Figure 2-126 shows an example in the operational indications command and feedback of a positively run switching action of the circuit breaker.
Page 336 2 Functions Figure 2-127 Standard interlockings Source of Command REMOTE includes LOCAL. LOCAL Command using substation controller REMOTE Command via telecontrol station to power system management and from power system management to the device The display shows the configured interlocking reasons. The are marked by letters as explained in Table 2-19.
Page 337: Recording And Acknowledgement Of Commands
2.24 Command Processing Figure 2-128 Example of configured interlocking conditions Control Logic via For the bay interlocking, an enabling logic can be structured using the CFC. Via spe- cific release conditions the information „released“ or „bay interlocked“ are available, e.g. object „52 Close“ and „52 Open“ with the data values: ON / OFF). 2.24.1.4 Recording and Acknowledgement of Commands During the processing of commands, independently of the further allocation and pro- cessing of indications, command and process feedbacks are sent to the indication pro-...
Page 338: Information List
2 Functions 2.24.1.5 Information List Information Type of In- Comments formation Cntrl Auth IntSP Control Authority Cntrl Auth Control Authority ModeREMOTE IntSP Controlmode REMOTE ModeLOCAL IntSP Controlmode LOCAL ModeLOCAL Controlmode LOCAL CntrlDIGSI Control DIGSI ■ 7UT613/63x Manual C53000-G1176-C160-2...
Page 339: Mounting And Commissioning
Mounting and Commissioning This chapter is primarily intended for experienced commissioning engineers. The commissioning engineer must be familiar with the commissioning of protection and control systems, with the management of power systems and with the relevant safety rules and guidelines. Under certain circumstances adaptations of the hardware to the particular power system data may be necessary.
Page 340: Mounting And Connections
3 Mounting and Commissioning Mounting and Connections General WARNING! Warning of improper transport, storage, installation, and application of the device. Non-observance can result in death, personal injury or substantial property damage. Trouble free and safe use of this device depends on proper transport, storage, instal- lation, and application of the device according to the warnings in this instruction manual.
Page 341 3.1 Mounting and Connections With single-phase busbar protection the measuring inputs are each assigned to one busbar feeder. Appendix A.3 illustrates an example for one phase. The other phases are to be connected accordingly. Also observe the General Diagrams in annex A.2 that apply to the current device.
Page 342 3 Mounting and Commissioning The control signals must be continuously present in order that the selected setting group remains active. The following table shows the relationship between binary inputs and the setting groups A to D. Principal connection diagrams for the two binary inputs are illustrated in the figure below.
Page 343 3.1 Mounting and Connections Figure 3-2 Logic diagram of the trip circuit supervision using one binary input Trip relay contact Circuit breaker Circuit breaker trip coil Aux1 Circuit breaker auxiliary contact (make) Aux2 Circuit breaker auxiliary contact (break) Control voltage (trip voltage) Input voltage of binary input Voltage across the Bypass resistor Bypass resistor...
Page 344 3 Mounting and Commissioning DC resistance of circuit breaker trip coil CBTC maximum voltage on the circuit breaker trip coil that does not lead to CBTC (LOW) tripping If the calculation results in R < R , then the calculation must be repeated with the next lower switching threshold U min, and this threshold must be implemented in the relay using plug-in jumpers.
Page 345: Hardware Modifications
3.1 Mounting and Connections 3.1.2 Hardware Modifications 3.1.2.1 General Hardware modifications concerning, for instance, nominal currents, the control voltage for binary inputs or termination of serial interfaces might be necessary. Follow the pro- cedure described in this subsection, whenever hardware modifications are done. Auxiliary Voltage There are different input ranges for the power supply voltage (refer to the data ordering information in the Appendix).
Page 346: Disassembly
3 Mounting and Commissioning To change the switching threshold of a binary input, one jumper must be changed for each input. The physical arrangement of the binary input jumpers in relation to the pickup voltages is explained below under margin headings „Processor Board C-CPU- 2“...
Page 347 3.1 Mounting and Connections Work on the Printed Circuit Boards Caution! Caution when changing jumper settings that affect nominal values of the device: As a consequence, the ordering number (MLFB) and the ratings on the name plate no longer match the actual device properties. Where such changes are necessary in exceptional cases, they MUST be marked clearly and visibly on the device.
Page 348 3 Mounting and Commissioning When performing work on plug connectors, proceed as follows: • Disconnect the ribbon-cable between the front cover and the C–CPU-2 (1) board. To disconnect the cable, push up the top latch of the plug connector and push down the bottom latch of the plug connector.
Page 349 3.1 Mounting and Connections Figure 3-4 Front view with housing size /1 after removal of the front panel (simplified and scaled down) 7UT613/63x Manual C53000-G1176-C160-2...
Page 350: Switching Elements On Printed Circuit Boards
3 Mounting and Commissioning 3.1.2.3 Switching Elements on Printed Circuit Boards Processor Module The following figure illustrates the layout of the PCB. Check the set rated voltage of C-CPU-2 the integrated power supply, the selected control voltages of binary inputs BI1 to BI5, the quiescent state of the life contact and the type of the integrated RS232/RS485 in- terface using the the tables below.
Page 351 3.1 Mounting and Connections Table 3-2 Jumper settings of the rated voltage of the integrated Power Supply on the C- CPU-2 processor board Nominal voltage Jumper 24 to 48 VDC 60 to 125 VDC 110 to 250 VDC, 220 to 250 VDC, 115 to 230 VAC 115 to 230 VAC Not used...
Page 352 3 Mounting and Commissioning Table 3-6 Jumper setting for CTS (Clear To Send, flow control) on the C-CPU-2 proces- sor board Jumper /CTS from interface RS232 /CTS triggered by /RTS X111 Delivery state Jumper setting 2-3: The connection to the modem is usually established with a star coupler or fibre-optic converter.
Page 353 3.1 Mounting and Connections Input/Output The PCB layout for the C-I/O-1 input/output board is shown in Figure 3-6 and the in- Board(s) C-I/O-1 put/output group C-I/O-10 as from release 7UT6../EE in Figure 3-7. and C-I/O-10 (only 7UT633 and 7UT635) The input/output board C-I/O-1 is only available in the versions 7UT633 and 7UT635. Figure 3-6 C-I/O-1 input/output boards with representation of jumper settings required for checking configuration settings...
Page 354 3 Mounting and Commissioning Figure 3-7 Input/output board C-I/O-10 release 7UT613/63x.../EE or higher, with represen- tation of jumper settings required for checking configuration settings Some of the output contacts can be changed from NO (normally open) operation to NC (normally closed) operation (refer also to the Appendix, Section A.2). For 7UT633 versions this applies for the binary outputs BO9 and BO17 (Figure 3-4, slot 33 left side and slot 19 left side).
Page 355 3.1 Mounting and Connections Table 3-8 Jumper settings of the contact type of relays of the binary outputs BO1, BO9 and BO17 on the input/output boards C-I/O-1 Quiescent Quiescent State State Default Posi- Device Module Jumper open closed tion (close) (open) Slot 33 left side 7UT633...
Page 356 3 Mounting and Commissioning Input/Output Board The input/output board C-I/O-2 is available only in 7UT613 and 7UT633. Mounting lo- C-I/O-2 (only cation: for 7UT613 slot 19, for 7UT633 slot 19 right side 7UT613 and 7UT633) Figure 3-8 C-I/O-2 input/output board release 7UT613/63x .../EE or higher, with represen- tation of jumper settings required for checking configuration settings The relay contacts of the binary outputs BO6 to BO8 can be changed from NO (nor- mally open) to NC (normally closed) operation (refer also to Appendix A.2).
Page 357 3.1 Mounting and Connections Table 3-11 Jumper setting for the contact type of the relay for BO6 to BO8 Jumper Quiescent state open Quiescent state closed (close) (open) Delivery state The relay contacts for binary outputs BO1 through BO5 can be connected to common potential, or configured individually for BO1, BO4 and BO5 (BO2 and BO3 are without function in this context) (see also General Diagrams in the Appendix A.2).
Page 358 3 Mounting and Commissioning The input/output board C-I/O-2 carries the following measured current inputs: • For 3-phase applications and 1-phase transformers: There are 3 measuring inputs for the three-phase measuring location M3: I L1M3 . The jumpers X61, X62, X63 belonging to this measuring location must L2M3 L3M3 be plugged all to the rated secondary current of the connected current transformers:...
Page 359 3.1 Mounting and Connections Input/Output Board The input/output board C-I/O-9 is used in the versions 7UT613, 7UT633 and 7UT635. C-I/O-9 (all models) Mounting location: for 7UT613 slot 33, for 7UT633 and 7UT635 slot 33 right side Figure 3-9 Input/output boards with representation of the jumpers required for checking the settings Jumpers X71 through X73 serve for module identification and must not be changed.
Page 360 3 Mounting and Commissioning The rated currents of the measured current inputs can be determined for each analog input. With default settings all jumpers are set to the same rated current (according to the order number of the device). The measuring inputs available depend on the intended use and the device variant. For the above slots, the following applies to all devices: •...
Page 361 3.1 Mounting and Connections Table 3-16 gives a summary of the jumpers for the rated currents on C–I/O-9. Table 3-16 Assignment of the jumpers for the rated currents to the measured current inputs Application Jumpers 3-phase 1-phase individual common L1M1 L2M1 L3M1 L1M2...
Page 362 3 Mounting and Commissioning Input/Output Board 7UT635 contains a second board C-I/O-9. Mounting location: Slot 19 right side C-I/O-9 (only 7UT635) Figure 3-10 Input/output boards with representation of the jumpers required for checking the settings Jumpers X71 through X73 on the input/output board C-I/O-9 serve for setting the bus address.
Page 363 3.1 Mounting and Connections The rated currents of the measured voltage inputs can be set for each input trans- former by jumpers on the PCB. With default settings all jumpers are set to the same rated current (according to the order number of the device). •...
Page 364: Interface Modules
3 Mounting and Commissioning Table 3-18 Assignment of jumpers for the rated current to the measuring inputs Application Jumpers 3-phase 1-phase individual common L1M3 L2M3 L3M3 L1M4 L2M4 L3M4 — L3M5 — X84/X85/X86 (sensitive) — — in 7UT635 applicable for measuring location M5 3.1.2.4 Interface Modules Note...
Page 365 3.1 Mounting and Connections Exchanging Inter- The interface modules are dependent on the variant ordered. They are located on the face Modules processor board C-CPU-2. Figure 3-11 C-CPU-2 board with interface modules Note Please note the following: Only interface modules of devices with flush mounting housing can be replaced.
Page 366 3 Mounting and Commissioning Table 3-19 Exchange Interface Modules Interface Mounting location / port Exchange module RS232 RS485 System Interface FO 820 nm PROFIBUS FMS RS485 PROFIBUS FMS double ring PROFIBUS FMS single ring PROFIBUS DP RS485 PROFIBUS DP double ring Modbus RS485 Modbus 820 nm DNP 3.0 RS485...
Page 367 3.1 Mounting and Connections With jumper X11 the flow control which is important for modem communication is en- abled. Table 3-20 Jumper setting for CTS (Clear To Send, flow control) on the interface module Jumper /CTS from Interface RS232 /CTS controlled by /RTS Default Setting Jumper setting 2-3: The connection to the modem is usually established with a star coupler or fibre-optic converter.
Page 368 3 Mounting and Commissioning Figure 3-13 Position of terminating resistors and the plug-in jumpers for configuration of the RS485 interface Figure 3-14 Position of the plug-in jumpers for the configuration of the terminating resistors at the Profibus (FMS and DP), DNP 3.0 and Modbus interfaces Terminating resistors can also be implemented outside the device (e.g.
Page 369: Reassembly
3.1 Mounting and Connections 3.1.2.5 Reassembly The device is assembled in the following steps: • Carefully insert the boards into the housing. The mounting locations of the boards are shown in Figures 3-3 and 3-4. For the model of the device designed for surface mounting, use the metal lever to insert the C-CPU-2 board.
Page 370: Rack And Cubicle Mounting
3 Mounting and Commissioning Figure 3-16 Panel flush mounting of a 7UT613 (housing size ) — example Figure 3-17 Panel flush mounting of a 7UT633 or 7UT635 (housing size ) — example 3.1.3.2 Rack and Cubicle Mounting Depending on the version, the device housing can be .
Page 371 3.1 Mounting and Connections 2 mounting brackets are required for incorporating a device in a rack or cubicle. The order numbers can be found in the Appendix under A.1. • Loosely screw the two mounting brackets in the rack with four screws. •...
Page 372: Panel Surface Mounting
3 Mounting and Commissioning Figure 3-19 Installation of a 7UT633 or 7UT635 in a rack or cubicle (housing size ) — example 3.1.3.3 Panel Surface Mounting Note Note With housing size , the transport protection must not be removed until the device has arrived at its final place of use.
Page 373: Removing The Transport Protection
3.1 Mounting and Connections • Alternatively, there is the possibility to connect the aforementioned earthing to the lateral grounding surface with at least one M4 screw. • Connections according to the circuit diagram via screw terminals, connections for optical fibres and electrical communication modules via the console housing. The SIPROTEC 4 System Description /1/ has pertinent information regarding wire size, lugs, bending radii, etc.
Page 374: Checking Connections
3 Mounting and Commissioning Checking Connections 3.2.1 Checking Data Connections of Serial Interfaces Pin assignments The following tables illustrate the pin assignment of the various serial device interfaces and of the time synchronisation interface and the Ethernet interface. The position of the connections can be seen in the following figure.
Page 375 3.2 Checking Connections With data cables, the connections are designated according to DIN 66020 and ISO 2110: • TxD = Data output • RxD = Data input • RTS = Request to send • CTS = Clear to send • GND = Signal/Chassis Ground The cable shield is to be grounded at both ends.
Page 376 3 Mounting and Commissioning Table 3-22 D-subminiature connector assignment of the time synchronisation interface Pin No. Designation Signal significance P24_TSIG Input 24 V P5_TSIG Input 5 V M_TSIG Return line M_TYNC Return line SCREEN Screen potential – – P12_TSIG Input 12 V P_TSYNC Input 24 V SCREEN...
Page 377: Checking The System Connections
3.2 Checking Connections 3.2.2 Checking the System Connections Before the device is energized for the first time, the device should be in the final oper- ating environment for at least 2 hours to equalize the temperature, to minimize humid- ity and avoid condensation. Connections are checked with the device at its final loca- tion.
Page 378 3 Mounting and Commissioning • Check the functions of all test switches that may be installed for the purposes of secondary testing and isolation of the device. Of particular importance are test switches in current transformer circuits. Be sure these switches short-circuit the current transformers when they are in the „test“...
Page 379: Commissioning
3.3 Commissioning Commissioning WARNING! Warning of dangerous voltages when operating an electrical device Non-observance of the following measures can result in death, personal injury or sub- stantial property damage. Only qualified people shall work on and around this device. They must be thoroughly familiar with all warnings and safety notices in this instruction manual as well as with the applicable safety steps, safety regulations, and precautionary measures.
Page 380: Test Mode / Transmission Block
3 Mounting and Commissioning WARNING! Warning of dangers evolving from improper primary tests Non-observance of the following measure can result in death, personal injury or sub- stantial property damage. Primary tests may only be carried out by qualified persons who are familiar with com- missioning protection systems, with managing power systems and the relevant safety rules and guidelines (switching, earthing etc.).
Page 381: Testing The System Interface
3.3 Commissioning 3.3.3 Testing the System Interface Prefacing Remarks If the device features a system interface and uses it to communicate with the control centre, the DIGSI device operation can be used to test if messages are transmitted correctly. This test option should however definitely „not“ be used while the device is in service on a live system.
Page 382 3 Mounting and Commissioning Figure 3-23 System interface test with dialog box: Generating indications – Example Changing the Oper- On clicking one of the buttons in the column Action you will be prompted for the pass- ating State word No. 6 (for hardware test menus). After correct entry of the password, individual annunciations can be initiated.
Page 383: Checking The Switching States Of The Binary Inputs/Outputs
3.3 Commissioning 3.3.4 Checking the switching states of the binary Inputs/Outputs Prefacing Remarks The binary inputs, outputs, and LEDs of a SIPROTEC 4 device can be individually and precisely controlled in DIGSI. This feature is used to verify control wiring from the device to plant equipment (operational checks) during commissioning.
Page 384 3 Mounting and Commissioning Figure 3-24 Test of the Binary Inputs and Outputs — Example Changing the oper- To change the operating state of a hardware component, click on the associated ating state switching field in the Scheduled column. Before executing the first change of the operating state the password No. 6 will be re- quested (if activated during configuration).
Page 385: Checking The Setting Consistency
3.3 Commissioning Proceed as follows in order to check the binary inputs: • Activate in the system each of the functions which cause the binary inputs. • Check the reaction in the Status column of the dialog box. To do this, the dialog box must be updated.
Page 386 3 Mounting and Commissioning Table 3-24 Indications on inconsistencies Message Meaning Section „Error1A/5Awrong“ Setting of the rated secondary currents on input/output board incon- 2.1.4 sistent, general 3.1.2 („Switch ele- ments on printed circuit boards“) „Err. IN CT M1“ 30097 Setting of the rated secondary currents inconsistent for the indicated 2.1.4 measured current input (3-phase inputs) 3.1.2 („Switch ele-...
Page 387 3.3 Commissioning Message Meaning Section „O/C Ph3 Not av.“ 209.2491 Time overcurrent protection for phase currents 3 is not available for 2.1.42.1.6 the configured protected object „O/C Ph3 err Set“ 209.2493 Settings for time overcurrent protection for phase currents 3 not plau- 2.4.2 sible O/C 3I0 not av.
Page 388 3 Mounting and Commissioning Message Meaning Section „U< err. VT“ 033.2492 Undervoltage protection is not available without voltage connection 2.14 „U< err. Set.“ 033.2493 Undervoltage protection setting not plausible 2.14 „U> err. Obj.“ 034.2491 Overvoltage protection is not available for the configured protected 2.15 object „U>...
Page 389: Secondary Check
3.3 Commissioning Table 3-25 Indications on matching factors Message Description section „Gen CT-M1:“ 30060 General: Magnitude matching factor at the indicated measuring location 2.1.4 „Gen CT-M5:“ 30064 „Gen VT-U1:“ 30065 General: Magnitude matching factor of 3-phase voltage input 2.1.4 „Diff CT-M1:“ 5733 Differential protection: Magnitude matching factor of the indicated mea- 2.1.4...
Page 390 3 Mounting and Commissioning Note The measurement accuracy to be achieved depends on the electrical data of the test sources used. The accuracies specified in the technical specifications can be expect- ed only if the reference conditions in accordance with VDE 0435/Part 303 or IEC 60255 are adhered to, and precision measurement instruments are used.
Page 391 3.3 Commissioning To obtain the actual pickup value, the set value has to be multiplied with the vector group factor k and the following equation: The following table shows these changes as a factor k depending on the vector group and the type of fault, for three-phase transformers. Table 3-26 Correction Factor k depending on vector group and fault type...
Page 392 3 Mounting and Commissioning 3-phase = √3/2 2-phase = √3 1-phase Flexible Functions While the protection, supervision and measuring functions implemented in the device and part of the device firmware are "fixed", the flexible functions are individually con- figured (see Section 2.1.4 under margin heading „Flexible Functions“). Configuration testing is best performed using secondary testing, as the internal connections have to be checked.
Page 393 3.3 Commissioning • If the current function is assigned to a measured location and the pickup values are set primary, the setting value is to be converted to secondary value, so that the pickup value at the secondary test current is maintained. For the conversion the transformation of the current transformer (set for this device measuring input) is im- portant.
Page 394 3 Mounting and Commissioning • Tests for positive and negative sequence system voltages are easiest with three- phase symmetrical testing. The positive sequence system can be obtained by sym- metrical test voltages, the negative sequence system by exchanging two phases. The setting value U and U correspond to the magnitude of every test voltage...
Page 395: Circuit Breaker Failure Protection Tests
3.3 Commissioning Table 3-27 Reactive Power Simulation by means of Phase Exchange Test Quantities I Test values U Active Power Reactive power at input I at input U ≈0 at input I at input U at input I at input U at input I at input U at input I...
Page 396 3 Mounting and Commissioning Circuit Breaker The circuit breaker auxiliary contact(s) form an essential part of the breaker failure pro- Auxiliary Contacts tection system in case they have been connected to the device. Make sure that the correct assignment has been checked. Make sure that the measured currents for breaker failure protection (CTs), the tested circuit breaker, and its auxiliary contact(s) relate to the same measuring location or side of the protected object.
Page 397: Symmetrical, Primary Current Tests On The Protected Object
3.3 Commissioning Termination of the All temporary measures taken for testing must be undone. This is to ensure that all Checks switching devices of the system are in the correct state, that interrupted trigger con- nections are restored and that control voltages are activated. Setting values that may have been changed for the tests, must be corrected and protective functions that were switched, must be set to the intended switching state (ON or OFF).
Page 398 3 Mounting and Commissioning DANGER! Operations in the primary area must be performed only with plant sections voltage-free and earthed! Perilous voltages may occur even on voltage-free plant sections due to capacitive influence caused by other live sections! On network power transformers and asynchronous machines a low-voltage test is preferably used.
Page 399 3.3 Commissioning formed for each possible current path (e.g. feeder 1 against feeder 2, feeder 1 against feeder 3, etc.) Please first read the notes contained in the section „Current Testing for Busbar Protection“. Implementation of Before beginning with the first current test, check the correct polarity setting for mea- suring location 1 on the basis of address 511 STRPNT->OBJ M1and compare it with Symmetrical Current Tests...
Page 400 3 Mounting and Commissioning • Amplitude measurement with switched on test current: Compare the indicated current magnitudes under measurement → secondary → operational measured values secondary with the actually flowing values: This applies for all measuring locations included in the test. Note: The WEB Monitor provides comfortable read-out possibilities for all mea- sured values with visualisation using phasor diagrams (Figure 3-27).
Page 401 3.3 Commissioning • Phase angle measurement for measuring location M1 with test current: Check the phase angle under measurement values → secondary → phase angles of side 1 of the protected object. All angles are referred to I . The follow- L1M1 ing values must result approximately for a clockwise phase rotation: ϕ...
Page 402 3 Mounting and Commissioning If considerable deviations occur, reversed polarity or swapped phases are expected on measuring location M2 or the actually tested measuring location. • Deviation in individual phases indicates reversed polarity in the related phase current connection or acyclically swapped phases. •...
Page 403 3.3 Commissioning – If there are differential currents in the size of the restraint currents (approximately twice the through-flowing test current), you may assume a polarity reversal of the current transformer(s) at one side. Check the polarity again and set it right after short-circuiting all six current transformers.
Page 404: Zero Sequence Current Tests On The Protected Object
3 Mounting and Commissioning Figure 3-28 Differential and Restraint Currents - Example of Plausible Measurements 3.3.9 Zero Sequence Current Tests on the Protected Object The zero sequence current tests are only necessary if the starpoint of a three-phase object or a single-phase transformer is earthed on a side or winding. If more than one starpoint is earthed, then the zero sequence current test has to be performed for each earthed winding.
Page 405 3.3 Commissioning DANGER! Operations in the primary area must be performed only with plant sections voltage-free and earthed! Perilous voltages may occur even on voltage-free plant sections due to capacitive influence caused by other live sections! Figure 3-29 Zero sequence current measurement on a star-delta transformer — without in- clusion of the starpoint current Figure 3-30 Zero sequence current measurement on a star-delta transformer...
Page 406 3 Mounting and Commissioning Figure 3-31 Zero sequence current measurement on a star-star transformer with compen- sation winding Figure 3-32 Zero sequence current measurement on an auto-transformer with compensa- tion winding Figure 3-33 Zero sequence current measurement on a zig-zag-winding 7UT613/63x Manual C53000-G1176-C160-2...
Page 407 3.3 Commissioning Figure 3-34 Zero sequence current measurement on a delta winding with neutral earthing reactor within the protected zone Figure 3-35 Zero sequence current measurement on an earthed series reactor (reactor, generator, motor) Figure 3-36 Zero sequence current measurement on an earthed single-phase transformer 7UT613/63x Manual C53000-G1176-C160-2...
Page 408 3 Mounting and Commissioning Implementation of For these commissioning tests, the zero sequence current must be at least 2 % of the Zero Sequence rated relay current for each phase, i.e. the test current at least 6 %. Current Tests This test cannot replace visual inspection of the correct current transformer connec- tions.
Page 409: Current Tests For Busbar Protection
3.3 Commissioning – If the differential current is in the size of the restraint current (approximately twice the test current), you may assume a polarity reversal of the single-phase current transformer. Check the polarity again and compare it with the setting in address 711 EARTH IX1 AT if the auxiliary single-phase input IX1 is under test (cf.
Page 410 3 Mounting and Commissioning • The checks must be performed on one device per phase for each phase. In the fol- lowing you can find some more information on summation transformers. • However, each check is restricted on one current pair, i.e. on the one traversing testing current.
Page 411: Checking For The Non-Assigned Single-Phase Current Inputs
3.3 Commissioning The phase angles must be 180° in all cases. Check the differential and restraint currents for each phase. If single-phase primary checks cannot be carried out but only symmetrical operational currents are available, polarity or connecting errors in the earth current path with sum- mation transformer connection L1–L3–E will not be detected with the before-men- tioned checks.
Page 412: Checking The Voltage Connections And Polarity Check
3 Mounting and Commissioning been checked as a starpoint current input of the main protected object, an additional check of this 1-phase input must be carried out. The test methods depend widely on the application of the single-phase input. By any means, the matching factors for the magnitude have to be checked (address 712, 713 etc.
Page 413 3.3 Commissioning The voltages can be read on the display at the front, or called up in the PC via the op- erator or service interface, and compared with the actual measured quantities as primary or secondary values. Besides the magnitudes of the phase-to-phase and the phase-to-earth voltages, the phase angles can be read out, thus enabling to verify the correct phase sequence and polarity of individual voltage transformers.
Page 414 3 Mounting and Commissioning • Open the miniature circuit breaker of the feeder voltage transformers. The mea- sured voltages in the operational measured values appear with a circuit close to zero (small measured voltages are of no consequence). – Check in the Event Log and in the spontaneous annunciations that the VT mcb trip was noticed (annunciation ">Fail:Feeder VT ON", No 361).
Page 415 3.3 Commissioning Figure 3-41 Apparent power If all signs are inverted this may be intentional. Check in the setting of address 1107 P,Q sign in the power system data 2 whether the polarity is inverted (see also Sub- section 2.1.6.1 under „Sign of Power“). In that case the signs for active and reactive power are inverse as well.
Page 416 3 Mounting and Commissioning Caution! For a turbine set, the intake of reverse power is only permissible for a short time, since operation of the turbine without a certain throughput of steam (cooling effect) can lead to overheating of the turbine blades! •...
Page 417: Testing User-Defined Functions
3.3 Commissioning The read-out measured values P1 and P2 are now used to carry out CT angle error correction: First calculate a correction angle from the measured value pairs according to the following formula: The power values must be inserted with their correct polarity as read out! Oth- erwise faulty result! This angle ϕ...
Page 418: Stability Check And Triggering Oscillographic Recordings
3 Mounting and Commissioning 3.3.14 Stability Check and Triggering Oscillographic Recordings In order to be able to test the stability of the protection during switchon procedures also, switchon trials can also be carried out at the end. Oscillographic records obtain the maximum information about the behaviour of the protection.
Page 419 3.3 Commissioning Such test records are especially informative on power transformers when they are trig- gered by the switch-on command of the transformer. Since the inrush current may have the same effect as a single-ended infeed, but which may not initiate tripping, the effectiveness of the inrush restraint is checked by energising the power transformer several times.
Page 420: Final Preparation Of The Device
3 Mounting and Commissioning Final Preparation of the Device The used terminal screws must be tightened, including those that are not used. All the plug connectors must be correctly inserted. Caution! Do not use force! The permissible tightening torque must not be exceeded as the threads and terminal chambers may otherwise be damaged! The setting values should be checked again, if they were changed during the tests.
Page 421: Technical Data
Technical Data This chapter provides the technical data of SIPROTEC 4 devices 7UT613, 7UT633, 7UT633 and their individual functions, including the limiting values that must not be exceeded under any circumstances. The electrical and functional data for devices equipped with all options are followed by the mechanical data with dimensional draw- ings.
Page 422: General
4 Technical Data General 4.1.1 Analogue Inputs Voltage Inputs Rated frequency 50 Hz / 60 Hz / 16.7 Hz (adjustable) Nominal current 1 A or 5 A or 0.1 A (changeable) Power consumption per input – at I = 1 A Approx.
Page 423: Binary Inputs And Outputs
4.1 General Admissible AC ripple voltage, ≤15 % of the auxiliary voltage Peak to peak, IEC 60255-11 Power consumption, quiescent Approx. 6 W Power consumption, energized 7UT613 Approx. 12 W 7UT633/7UT635 Approx. 20 W ≥ 50 ms at U ≥ 110 V Bridging time for failure/short-circuit of the = 48 V and U power supply, IEC 60255-11...
Page 424: Frequency Measurement Via The Positive Phase-Sequence Voltage U1
4 Technical Data Switching capability MAKE 1000 W/VA Switching capability BREAK 30 VA 40 W resistive 25 W at L/R ≤ 50 ms Alarm relay 1 with 1 NO contact or 1 NC contact (select- able) Switching capability MAKE 1000 W/VA Switching capability BREAK 30 VA 40 W resistive...
Page 425: Communications Interfaces
4.1 General 4.1.5 Communications Interfaces Operator Interface Connection Front side, non-isolated, RS232, 9-pin D-subminiature female connector for connection of a PC computers Operation With DIGSI Transmission min. 4,800 Baud; max. 115,200 Baud; speed factory setting: 115,200 Baud; parity: 8E1 Maximum bridgeable dis- 15 m tance Service/Modem Interface...
Page 426 4 Technical Data Fibre optic cable (FO) FOC connector type ST connector Connection for flush-mounted rear panel, mounting location housing „C“ Connector for surface mounted in the inclined housing on the housing case bottom λ = 820 nm optical wavelength Using glass fibre 50/125 µm or Laser class 1 according to using glass fibre 62.5/125 µm...
Page 427 4.1 General Optical fibre (FO) FOC connector type ST connector Connection for flush mounted Rear panel, mounting location case „B“ Connection for surface in the inclined housing on the mounted case case bottom λ = 820 nm Optical wavelength Using glass fibre 50/12 µm or Laser class 1 according to EN using glass fibre 62.5/125 µm 60825-1/-2...
Page 428 4 Technical Data DNP3.0 Fibre Optical Link FOC connector type ST–connector transmit- Connection for flush mounted rear panel, mounting location ter/receiver case „B“ Connection for surface- only with external converter; mounted case in the inclined housing on the case bottom Transmission speed up to 19,200 Baud λ...
Page 429 4.1 General Ethernet optical (EN 100) FOC connector type ST–connector transmitter/re- for IEC 61850 and DIGSI ceiver Connection for flush-mounted Rear panel, mounting location housing "B" for surface-mounting case not available λ = 1350 nm optical wavelength Transmission speed 100 MBit/s Laser class 1 according to Using glass fibre 50/125 µm...
Page 430: Electrical Tests
4 Technical Data Rated signal voltages selectable 5 V, 12 V or 24 V Test voltage 500 V; 50 Hz Signal levels and burdens for DCF 77 and IRIG B (format IRIG-B000) Rated signal input voltage 12 V 24 V 6.0 V 15.8 V 31 V...
Page 431 4.1 General Irradiation with HF field, frequency sweep 10 V/m; 80 MHz to 1000 MHz; IEC 60255-22-3; Class III 10 V/m; 800 MHz to 960 MHz; IEC 61000-4-3, Class III 20 V/m; 1.4 GHz to 2.0 GHz; 80 % AM; 1 kHz Irradiation with HF field, single frequencies Class III: 10 V/m IEC 60255-22-3;...
Page 432: Mechanical Tests
4 Technical Data 4.1.7 Mechanical Tests Vibration and shock during operation Standards: IEC 60255-21 and IEC 60068 Oscillation sinusoidal 10 Hz to 60 Hz: ± 0.075 mm amplitude; IEC 60255-21-1, Class 2; IEC 60068-2-6 60 Hz to 150 Hz: 1 g acceleration frequency sweep rate 1 octave/min 20 cycles in 3 orthogonal axes Shock...
Page 433: Service Conditions
4.1 General –20 °C to +70 °C Limiting temporary (transient) operating tem- perature (legibility of display may be restricted from +131 °F (+55 °C)) (tested for 96 h) –5 °C to +55 °C or +23 °F to 131 °F recommended permanent operating tempera- ture (acc.
Page 434: Constructional Details
4 Technical Data 4.1.10 Constructional Details Housing 7XP20 Dimensions see dimensional drawings in the technical data section Weight (maximum number of components ) approx. 7UT613 In surface-mounted housing, size 13.5 kg (29.8 lb) In flush-mounted housing, size 8.7 kg (19.2 lb) 7UT633 In surface-mounted housing, size 22.0 kg (48.5 lb)
Page 435: Differential Protection
4.2 Differential Protection Differential Protection Pickup Values Differential current >/I 0.05 to 2.00 Steps 0.01 Diff NObj High-current stage >>/I 0.5 to 35.0 Steps 0.1 Diff NObj or ∞ (ineffective) Increase of the pickup value when connect- 1.0 to 2.0 Steps 0.1 ing as a factor of I >...
Page 436 4 Technical Data Harmonic Restraint (Transformers) Inrush restraint ratio 10 % to 80 % Steps 1 % (2nd harmonic) I see also Figure 4-24-2 Restraint ratio further (n-th) harmonic 10 % to 80 % Steps 1 % (either 3rd or 5th) I see also Figure 4-3 Crossblock function can be activated / deacti-...
Page 437 4.2 Differential Protection Figure 4-2 Restraining influence of 2nd harmonic in transformer differential protection differential current = |I diff Rated current of protected object NObj Current at rated frequency Current at double frequency 7UT613/63x Manual C53000-G1176-C160-2...
Page 438 4 Technical Data Figure 4-3 Restraining influence of n-th harmonic in transformer differential protection differential current = |I diff Nominal current of protected object NObj Current at nominal frequency Current at n times the frequency (n = 3 or 4) Figure 4-4 Frequency influence in transformer differential protection Differential current = |I...
Page 439 4.2 Differential Protection Operating Times (Generators, Motors, Reactors) Pickup time / dropout time with single-side infeed Pickup time at frequency 50 Hz 60 Hz 16.7 Hz high-speed relays 30 ms 27 ms 78 ms > min Diff high-speed relays 25 ms 22 ms 73 ms high-speed relays...
Page 440 4 Technical Data Delay of blocking of differential current 1 s to 10 s Steps 1 s Monit Feeder Current Guard (Busbars, Short Lines) I> Trip release by feeder current guard 0.20 to 2.00 Steps 0.01 Guard NObj or 0 (always released) Operating Time (Busbars, Short Lines) Pickup time / dropout time with single-side infeed...
Page 441: Restricted Earth Fault Protection
4.3 Restricted earth fault protection Restricted earth fault protection Setting Ranges Differential current >/I 0.05 to 2.00 Steps 0.01 NObj ϕ Limit angle 110° (fixed) Trip characteristic see Figure 4-6 5 % at I < 5 · I Pickup tolerance (with preset characteristic parameters and one 3-phase measuring location) Time delay...
Page 442: Time Overcurrent Protection For Phase And Residual Currents
4 Technical Data Time Overcurrent Protection for Phase and Residual Currents Characteristics >>, I Definite-time stages >>, 3I >, 3I > Inverse time stages , 3I (acc. to IEC or ANSI) one of the tripping curves depicted in figures to 4-12 on the right-hand side may be select- alternatively user specified trip and reset char- acteristic Reset characteristics...
Page 443 4.4 Time Overcurrent Protection for Phase and Residual Currents 5 % ± 15 ms at f = 50/60 Hz times 5 % ± 45 ms at f = 16.7 Hz for 2 ≤ I/I ≤ 20 /s ≥ 1; and T or 2 ≤...
Page 444 4 Technical Data Trip Time Curves acc. to IEC Acc. to IEC 60255-3 or BS 142, Section 3.5.2 (see also Figure and 4-8) ≥ 20 are identical to those for I/I The tripping times for I/I = 20. For residual current read 3I0p instead of I and T instead of T 3I0p...
Page 445 4.4 Time Overcurrent Protection for Phase and Residual Currents Figure 4-7 Dropout time and trip time curves of the inverse time overcurrent protection, as per IEC 7UT613/63x Manual C53000-G1176-C160-2...
Page 446 4 Technical Data Figure 4-8 Dropout time and trip time curves of the inverse time overcurrent protection, acc. to IEC 7UT613/63x Manual C53000-G1176-C160-2...
Page 447 4.4 Time Overcurrent Protection for Phase and Residual Currents Trip Time Curves acc. to ANSI Acc. to ANSI/IEEE (see also Figures 4-9 to 4-12) ≥ 20 are identical to those for I/I The tripping times for I/I = 20. For residual current read 3I0p instead of I and T instead of T 3I0p...
Page 448 4 Technical Data Dropout Time Curves as per ANSI/IEEE Acc. to ANSI/IEEE (see also Figures 4-9 to 4-12) The reset time characteristics apply to (I/Ip) ≤ 0,90 For residual current read 3I0p instead of I and T instead of T 3I0p for earth faults read I instead of I...
Page 449 4.4 Time Overcurrent Protection for Phase and Residual Currents Figure 4-9 Dropout time and trip time curves of the inverse time overcurrent protection, acc. to ANSI/IEEE 7UT613/63x Manual C53000-G1176-C160-2...
Page 450 4 Technical Data Figure 4-10 Dropout time and trip time curves of the inverse time overcurrent protection, acc. to ANSI/IEEE 7UT613/63x Manual C53000-G1176-C160-2...
Page 451 4.4 Time Overcurrent Protection for Phase and Residual Currents Figure 4-11 Dropout time and trip time curves of the inverse time overcurrent protection, acc. to ANSI/IEEE 7UT613/63x Manual C53000-G1176-C160-2...
Page 452 4 Technical Data Figure 4-12 Dropout time and trip time curve of the inverse time overcurrent protection, acc. to ANSI/IEEE 7UT613/63x Manual C53000-G1176-C160-2...
Page 453: Time Overcurrent Protection For Earth Current (Starpoint Current)
4.5 Time Overcurrent Protection for Earth Current (Starpoint Current) Time Overcurrent Protection for Earth Current (Starpoint Current) Characteristics >>, I Definite-time stages > Inverse time stages (acc. to IEC or ANSI) The same characteristics apply as for time overcurrent protection for phase and residual currents in accordance with the preceding section Reset characteristics...
Page 454 4 Technical Data Operating Times of the Definite Time Stages Pickup time / dropout time Pickup time at frequency 50 Hz 60 Hz 16.7 Hz without inrush restraint, min. 11 ms 11 ms 16 ms with inrush restraint, min. 33 ms 29 ms 76 ms Dropout time, approx.
Page 455: Dynamic Cold Load Pickup For Time Overcurrent Protection
4.6 Dynamic Cold Load Pickup for Time Overcurrent Protection Dynamic Cold Load Pickup for Time Overcurrent Protection Time Control Start criterion Binary input from circuit breaker auxiliary contact or current criterion (of the assigned side) CB open time 0 s to 21600 s (= 6 h) Steps 1 s CB open Action time...
Page 456: Single-Phase Time Overcurrent Protection
4 Technical Data Single-Phase Time Overcurrent Protection Current Stages I>> High current stage 0.05 A to 35.00 A Steps 0.01 A 0.003 A to 1.500 A Steps 0.001 A or ∞ (ineffective) 0.00 s to 60.00 s Steps 0.01 s I>>...
Page 457: Unbalanced Load Protection
4.8 Unbalanced Load Protection Unbalanced Load Protection Characteristics >>, I Definite-time stages > Inverse time stages (acc. to IEC or ANSI) One of the characteristics shown in figures 4- 14 to 4-17 can be selected Reset characteristics For illustrations of possible reset time charac- with disk emulation teristics see figures 4-14 to 4-17 on the left- hand side.
Page 458 4 Technical Data Operating Times of the Definite Time Stages Pickup time / dropout time Pickup time at frequency 50 Hz 60 Hz 16.7 Hz minimum 41 ms 34 ms 106 ms Dropout time, approx. 23 ms 20 ms 60 ms ) for high-speed relays, the pick-up times decrease by 4.5 ms Dropout to Pickup Ratios ≥...
Page 459 4.8 Unbalanced Load Protection Trip Time Curves acc. to IEC One of the tripping characteristics displayed on the right-hand side of Figures 4-14 and 4-15 can be selected. ≥ 20 are identical to those for I The trip times for I = 20.
Page 460 4 Technical Data Figure 4-14 Dropout time and trip time characteristics of the inverse time unbalanced load stage, as per IEC 7UT613/63x Manual C53000-G1176-C160-2...
Page 461 4.8 Unbalanced Load Protection Figure 4-15 Dropout time and trip time characteristics of the inverse time unbalanced load stage, as per IEC Trip Time Curves acc. to ANSI One of the tripping curves depicted in the figures 4-16 and 4-17 on the right-hand side may be selected.
Page 462 4 Technical Data Reset Curves with Disk Emulation according to ANSI For illustrations of possible reset time characteristics see figures 4-16 and 4-17 on the left-hand side. ) ≤ 0.90 The dropout times constants apply to (I 7UT613/63x Manual C53000-G1176-C160-2...
Page 463 4.8 Unbalanced Load Protection Figure 4-16 Dropout time and trip time characteristics of the inverse time unbalanced load stage, acc. to ANSI 7UT613/63x Manual C53000-G1176-C160-2...
Page 464 4 Technical Data Figure 4-17 Dropout time and trip time characteristics of the inverse time unbalanced load stage, acc. to ANSI 7UT613/63x Manual C53000-G1176-C160-2...
Page 465: Thermal Overload
4.9 Thermal Overload Thermal Overload Setting Ranges Factor k according to IEC 60255-8 0.10 to 4.00 Steps 0.01 τ Time constant 1.0 min to 999.9 min Increments 0.1 min Cooling down factor at motor -factor 1.0 to 10.0 Steps 0.1 τ...
Page 466 4 Technical Data Frequency Influence referring to k · I Frequency in range 0.9 ≤ f/f ≤ 1 % at f = 50 / 60 Hz 3 % at f = 16.7 Hz Characteristic Figure 4-18 Trip time characteristic of thermal overload protection τ...
Page 467 4.9 Thermal Overload Temperature Detectors Number of measuring points from 1 RTD-box (up to 6 measuring points) or from 2 RTD-boxes (up to 12 measuring points) For hot-spot calculation one temperature detector must be connected. Cooling Cooling method ON (oil natural) OF (oil forced) OD (oil directed) Oil exponent Y...
Page 468: Rtd Boxes For Overload Detection
4 Technical Data 4.10 RTD Boxes for Overload Detection Temperature Detectors Connectable RTD-boxes 1 or 2 Number of temperature detectors per Max. 6 RTD-box Pt 100 Ω or Ni 100 Ω or Ni 120 Ω Type of measurement Selectable: 2 or 3-wire connection Mounting identification „Oil“...
Page 469: Overload Protection
4.11 Overload Protection 4.11 Overload Protection Setting Ranges Pickup threshold 1.00 to 1.20 Steps 0.01 (warning stage) Pickup threshold 1.00 to 1.40 Steps 0.01 (stepped characteristic) Time delay (warning stage T U/f>, T U/f>> 0.00 to 60.00 s Steps 0.01 s or ∞...
Page 470 4 Technical Data Figure 4-19 Resulting tripping characteristic from thermal replica and stepped characteristic of the overexcitation protection (default settings) 7UT613/63x Manual C53000-G1176-C160-2...
Page 471: Reverse Power Protection
4.12 Reverse Power Protection 4.12 Reverse Power Protection Setting Ranges / Increments Reverse power P > -3000.0 W up to -1.7 W Increment 0.1 W reverse -17.00 P/SnS up to - Increment 0.01 P/SnS 0.01 P.SnS Delay Times T 0,00 s to 60.00 s Increments 0.01 s or ∞...
Page 472: Forward Active Power Supervision
4 Technical Data 4.13 Forward active power supervision Setting Ranges / Increments Forward power P < 1.7 W up to 3000.0 W Increment 0.1 W forward 0.01 P/SnS up to Increment 0.1 W 17.00 P/SnS Forward power P > 1.7 W up to 3000.0 W Increment 0.1 W forward 0.01 P/SnS up to...
Page 473 4.13 Forward active power supervision Influencing Variables for Pickup Values ≤ 1 % Power supply direct voltage in range 0.8 ≤ U ≤ 1,15 ≤ 0.5 %/10 K Temperature in range –5 °C ≤ Θ ≤ 55 °C Frequency in range 0.95 ≤ f/f ≤...
Page 474: Undervoltage Protection
4 Technical Data 4.14 Undervoltage Protection Setting Ranges / Increments Measured quantity Positive Sequence phase-to-earth voltages as phase-to-phase Values Pickup Thresholds U<, U<< 10.0 V to 125.0 V Increments 0.1 V Dropout Ratios DR 1.01 to 1.20 Increments 0.01 (only increments U<, U<<) Time Delays T U<, T U<<...
Page 475: Overvoltage Protection (Ansi 59)
4.15 Overvoltage Protection (ANSI 59) 4.15 Overvoltage Protection (ANSI 59) Setting Ranges / Increments Pickup Thresholds U<, U<< 30.0 V to 170.0 V Increments 0.1 V Dropout Ratios DR 0.90 to 0.99 Increments 0.01 (only increments U<, U<<) Time Delays T U<, T U<< 0,00 s to 60.00 s Increments 0.01 s or ∞...
Page 476: Frequency Protection
4 Technical Data 4.16 Frequency Protection Measuring Range of the Frequency Functions Lower frequency limit Rated frequency 50/60.7 Hz approx. 9.25 Hz Upper frequency limit Rated frequency 50/60.7 Hz approx. 70 Hz Nominal frequency 16.7 Hz approx. 23.33 Hz Minimum positive sequence voltage for frequency measure- approx.
Page 477 4.16 Frequency Protection Dropout ratio Dropout Ratio approx. 1.10 for Undervoltage Blocking Tolerances Frequencies f>, f< 10 mHz (at U = U , f = f Undervoltage blocking 1 % of the setting value or 0.5 V Delay times T(f<, f<) 1 % of the setting value or 10 ms Influencing Variables for Pickup Power supply direct voltage in range...
Page 478: Circuit Breaker Failure Protection
4 Technical Data 4.17 Circuit Breaker Failure Protection Circuit Breaker Supervision Current flow monitoring 0.04 A to 1.00 A Steps 0.01 A for the respective side approx. 0.9 for I ≥ 0.25 A Dropout-to-pickup ratio Tolerance 5 % of set value or 0.01 A Breaker status monitoring via circuit breaker auxiliary contacts and binary input...
Page 479: External Trip Commands
4.18 External Trip Commands 4.18 External Trip Commands Binary Inputs for Direct Tripping Number Operating Time approx. 12.5 ms min. approx. 25 ms typical Dropout time approx. 25 ms Delay time 0.00 s to 60.00 s Steps 0.01 s Time tolerance 1 % of set value or 10 ms The set times are pure delay times.
Page 480: Monitoring Functions
4 Technical Data 4.19 Monitoring Functions Measured Quantities Current symmetry |/|I | < BAL. FACT. I M1 provided that I (for each side) > BAL. I LIMIT M1/I BAL.FAC. I 0.10 to 0.90 Steps 0.01 BAL. I LIMIT 0.10 A to 1.00 A Steps 0.01 A Voltage balance |/|U...
Page 481: User-Defined Functions (Cfc)
4.20 User-defined Functions (CFC) 4.20 User-defined Functions (CFC) Function Blocks and their Possible Allocation to the Priority Classes Explanation Task Level Function Module MW_BEARB PLC1_BEARB PLC_BEARB SFS_BEARB ABSVALUE Magnitude Calculation – – – Addition ALARM Alarm clock AND - Gate BLINK Flash block BOOL_TO_CO...
Page 482 4 Technical Data MV_GET_STATUS Information status mea- sured value, decoder MV_SET_STATUS Measured value with status, encoder NAND NAND - Gate Negator NOR - Gate OR - Gate REAL_TO_DINT Real after DoubleInt, adapter REAL_TO_UINT Real after U-Int, adapter RISE_DETECT Rising edge detector RS_FF RS- Flipflop –...
Page 483 4.20 User-defined Functions (CFC) Designation Limit Comments Maximum number of inputs of one Only fault annunciation (record in device chart for each task level (number of fault log); here the number of elements of unequal information items of the left the left border per task level is counted.
Page 484 4 Technical Data Processing Times in TICKS required by the Individual Elements Element Number of TICKS Module, basic requirement Each input from the 3rd additional input for generic blocks Connection to an input signal Connection to an output signal Additional for each chart Switching Sequence CM_CHAIN Status Memory for Restart...
Page 485: Flexible Protection Functions
4.21 Flexible Protection Functions 4.21 Flexible Protection Functions Measured Values / Operating Modes I-measuring point / I-side Measured values I1 .. I12 (for busbar 1-ph.) IZ1 .. IZ4 U, P, Q, cos ϕ, f Measuring procedure for I-measuring Evaluation of only one phase, point / I-sides / U fundamental component, positive sequence system,...
Page 486 4 Technical Data Operating Times = 50/60 Hz = 16.7 Hz Pick-up times Current approx. 35 ms approx. 70 ms Voltage approx. 50 ms approx. 130 ms Power Measuring procedure high-accuracy ca. 200 ms approx. 500 ms Measuring procedure high-speed ca.
Page 487: Additional Functions
4.22 Additional Functions 4.22 Additional Functions Operational Measured Values Note: The tolerances stated in the data below refer to one measuring location or one side with 2 measuring locations. All values are ± digit. Operational measured in A primary and secondary values for currents –...
Page 488 4 Technical Data Operational values for Active power P; reactive power Q; apparent power S in kW; MW; kVA; MVA primary power – Tolerance 1.2 % of measured value, or 0.25 % of S (3-phase, if voltage connected) Operational measured S (apparent power) in kVA;...
Page 489 4.22 Additional Functions Fault Recording Number of stored fault records max. 8 Storage period per fault record Approx. 5 s per fault at 50/60 Hz, approx. 5 s total sum approx. 18 s per fault at 16.7 Hz, approx. 18 s total sum Sampling rate at f = 50 Hz 1.25 ms...
Page 490 4 Technical Data Real Time Clock and Buffer Battery Resolution for operational messages 1 ms Resolution for fault messages 1 ms Back-up Battery Lithium battery 3 V/1 Ah, type CR 1/2 AA self-discharging time approx. 10 years Time Synchronisation Internal Internal using RTC (default) IEC 60870-5-103 External using system interface...
Page 491: Dimensions
4.23 Dimensions 4.23 Dimensions 4.23.1 Panel Surface Mounting (Enclosure Size Figure 4-20 Dimensional drawing of a 7UT613 for panel flush mounting (housing size 4.23.2 Panel Surface Mounting (Enclosure Size Figure 4-21 Dimensional drawing of a 7UT633 or 7UT635 for panel flush mounting (housing size 7UT613/63x Manual C53000-G1176-C160-2...
Page 492: Panel Surface And Cabinet Mounting (Enclosure Size 1 / 2 )
4 Technical Data 4.23.3 Panel Surface and Cabinet Mounting (Enclosure Size Figure 4-22 Dimensions of a 7UT613 for panel flush mounting or cubicle mounting (housing size 7UT613/63x Manual C53000-G1176-C160-2...
Page 493: Panel Surface And Cabinet Mounting (Enclosure Size 1 / 1 )
4.23 Dimensions 4.23.4 Panel Surface and Cabinet Mounting (Enclosure Size Figure 4-23 Dimensions of a 7UT6 (maximum functional scope) for panel flush mounting or cubicle mounting (housing size 7UT613/63x Manual C53000-G1176-C160-2...
Page 494: Rtd Box
4 Technical Data 4.23.5 RTD box Figure 4-24 Dimensions of the Remote Temperature Detection Unit 7XV5662–*AD10–0000 ■ 7UT613/63x Manual C53000-G1176-C160-2...
Page 495: Appendix
Appendix This appendix is primarily a reference for the experienced user. This section provides ordering information for the models of this device. Connection diagrams for indicating the terminal connections of the models of this device are included. Following the general diagrams are diagrams that show the proper connections of the devices to primary equipment in many typical power system configurations.
Page 496: Ordering Information And Accessories
A Appendix Ordering Information and Accessories A.1.1 Ordering Information A.1.1.1 Differential Protection 7UT613 for 3 Measuring Locations 10 11 12 13 14 15 Differential Protec- — — tion Equipment Pos. 7 Nominal current I = 1 A Nominal current I = 5 A Auxiliary voltage (power supply, pickup threshold of binary inputs) Pos.
Page 497 A.1 Ordering Information and Accessories System Interfaces (rear side, port B) Pos. 11 No system interface IEC 60870-5-103 protocol, electrical RS232 IEC 60870-5-103 protocol, electrical RS485 IEC 60870-5-103 protocol, optical 820 nm, ST connector Profibus FMS Slave, electrical RS485 Profibus FMS slave, optical, single ring, ST connector Profibus FMS slave, optical, double ring, ST connector For more interface options see Additional Specification L Not possible with surface mounting housing (position 9 = B).
Page 498 A Appendix Measurement Function Pos. 13 Basic measured values Minimum and Maximum Values: Basic measured values, average values, min/max values, transformer monitoring functions (connection to RTD box/hot-spot, overload factor) Only in connection with position 12 = 2 or 9 and Mxx (supplementary) Differential Protection Pos.
Page 499: Differential Protection 7Ut633 And 7Ut635 For 3 To 5 Measuring Locations
A.1 Ordering Information and Accessories A.1.1.2 Differential Protection 7UT633 and 7UT635 for 3 to 5 measuring locations 10 11 12 13 14 15 Differential Protec- — — tion Inputs and outputs Housing, number of binary inputs and outputs Pos. 6 BI: Binary inputs, BO: Output relays 12 current inputs (3 x 3–phase, + 3 x 1–phase) 4 voltage inputs (1 x 3–phase, +1 x 1–phase)
Page 500 A Appendix System Interfaces (rear side, port B) Pos. 11 IEC 60870-5-103 protocol, electrical RS232 IEC 60870-5-103 protocol, electrical RS485 IEC 60870-5-103 protocol, optical 820 nm, ST connector Profibus FMS Slave, electrical RS485 Profibus FMS slave, optical, single ring, ST connector Profibus FMS slave, optical, double ring, ST connector For more interface options see Additional Specification L Not possible with surface mounting housing (position 9 = B).
Page 501 A.1 Ordering Information and Accessories Measurement Function Pos. 13 Basic measured values Minimum and Maximum Values: Basic measured values, average values, min/max values, transformer monitoring functions (connection to RTD box/hot-spot, overload factor) Only in connection with position 12 = 2 or 9 and Mxx (supplementary) Differential Protection Pos.
Page 502: Accessories
A Appendix A.1.2 Accessories RTD box (tempera- up to 6 temperature measuring points (max. 2 boxes can be connected to the ture detection unit) 7UT613/63x) Name Order Number RTD-box, U = 24 to 60 V AC/DC 7XV5662–2AD10 RTD-box, U = 90 to 240 V AC/DC 7XV5662–5AD10 Matching and Sum- For single-phase busbar protection...
Page 503 A.1 Ordering Information and Accessories Exchangeable In- Name Order Number terface Modules RS232 C53207-A351-D641-1 RS485 C53207-A351-D642-1 Optical 820 nm C53207-A351-D643-1 Profibus FMS RS485 C53207-A351-D603-1 Profibus FMS double ring C53207-A351-D606-1 Profibus FMS single ring C53207-A351-D609-1 Profibus DP RS485 C53207-A351-D611-1 Profibus DP double ring C53207-A351-D613-3 Modbus RS485 C53207-A351-D621-1...
Page 504 A Appendix Interface cable Interface cable between PC and SIPROTEC device Name Order Number Cable with 9-pole male/female connector 7XV5100-4 Operating Software Protection operating and configuration software DIGSI 4 DIGSI 4 Name Order Number DIGSI 4, basic version with license for 10 computers 7XS5400-0AA00 DIGSI 4, complete version with all option packages 7XS5402-0AA00...
Page 505: Terminal Assignments
A.2 Terminal Assignments Terminal Assignments A.2.1 Panel Flush and Cubicle Mounting 7UT613*-*D/E Figure A-1 Overview diagram 7UT613 (panel flush and cubicle mounting) 7UT613/63x Manual C53000-G1176-C160-2...
Page 506 A Appendix 7UT633*-* D/E 7UT613/63x Manual C53000-G1176-C160-2...
Page 507 A.2 Terminal Assignments 7UT633*-* D/E Figure A-2 General diagram 7UT633 (panel flush and cubicle mounting) 7UT613/63x Manual C53000-G1176-C160-2...
Page 508 A Appendix 7UT633*-* P/Q 7UT613/63x Manual C53000-G1176-C160-2...
Page 509 A.2 Terminal Assignments 7UT633*-* P/Q Figure A-3 General diagram 7UT633 (panel flush and cubicle mounting) 7UT613/63x Manual C53000-G1176-C160-2...
Page 510 A Appendix 7UT635*-* D/E 7UT613/63x Manual C53000-G1176-C160-2...
Page 511 A.2 Terminal Assignments 7UT635*-* D/E Figure A-4 General diagram 7UT635 (panel flush and cubicle mounting) 7UT613/63x Manual C53000-G1176-C160-2...
Page 512 A Appendix 7UT635*-* P/Q 7UT613/63x Manual C53000-G1176-C160-2...
Page 513 A.2 Terminal Assignments 7UT635*-* P/Q Figure A-5 General diagram 7UT635 (panel flush and cubicle mounting) 7UT613/63x Manual C53000-G1176-C160-2...
Page 514: Panel Surface Mounting
A Appendix A.2.2 Panel Surface Mounting 7UT613*-* B Figure A-6 General diagram 7UT613 (panel surface mounting) 7UT613/63x Manual C53000-G1176-C160-2...
Page 515 A.2 Terminal Assignments 7UT633*-* B 7UT613/63x Manual C53000-G1176-C160-2...
Page 516 A Appendix 7UT633*-* B Figure A-7 General diagram 7UT633 (panel surface mounting) 7UT613/63x Manual C53000-G1176-C160-2...
Page 517 A.2 Terminal Assignments 7UT633*-* N 7UT613/63x Manual C53000-G1176-C160-2...
Page 518 A Appendix 7UT633*-* N Figure A-8 General diagram 7UT633 (panel surface mounting) 7UT613/63x Manual C53000-G1176-C160-2...
Page 519 A.2 Terminal Assignments 7UT635*-* B 7UT613/63x Manual C53000-G1176-C160-2...
Page 520 A Appendix 7UT635*-* B Figure A-9 General diagram 7UT635 (panel surface mounting) 7UT613/63x Manual C53000-G1176-C160-2...
Page 521 A.2 Terminal Assignments 7UT635*-* N 7UT613/63x Manual C53000-G1176-C160-2...
Page 522 A Appendix 7UT635*-* N Figure A-10 General diagram 7UT635 (panel surface mounting) 7UT613/63x Manual C53000-G1176-C160-2...
Page 523: Connection Examples
A.3 Connection Examples Connection Examples A.3.1 Current Transformer Connection Examples Figure A-11 Connection example 7UT613 for a three-phase power transformer without earthed starpoint Figure A-12 Connection example 7UT613 for a three-phase power transformer with earthed starpoint and current transformer between starpoint and earthing point 7UT613/63x Manual C53000-G1176-C160-2...
Page 524 A Appendix Figure A-13 Connection example 7UT613 for a three-phase power transformer with star- point former and current transformer between starpoint and earthing point 7UT613/63x Manual C53000-G1176-C160-2...
Page 525 A.3 Connection Examples Figure A-14 Connection example 7UT613 for a three-phase power transformer 7UT613/63x Manual C53000-G1176-C160-2...
Page 526 A Appendix Figure A-15 Connection example 7UT613 for an earthed auto-transformer with current transformer between starpoint and earthing point 7UT613/63x Manual C53000-G1176-C160-2...
Page 527 A.3 Connection Examples Figure A-16 Connection example 7UT613 for an earthed auto-transformer with brought-out delta winding capable of car- rying load (tertiary winding) and current transformer between starpoint and earthing point 7UT613/63x Manual C53000-G1176-C160-2...
Page 528 A Appendix Figure A-17 Connection example 7UT613 for an auto-transformer bank with protected object auto-transformer branch- points, with individually accessible earthing electrodes equipped with CTs (M3). The CTs on the earthing side constitute a separate side for current comparison for each transformer of the bank. The starpoint of the CTs at M3 is routed via an auxiliary input (I ), which allows realisation of restricted earth fault protection and/or earth overcurrent protection.
Page 529 A.3 Connection Examples Figure A-18 Connection example 7UT613 for a single-phase power transformer with current transformer between starpoint and earthing point Figure A-19 Connection example 7UT613 for a single-phase power transformer with only one current transformer (right side) 7UT613/63x Manual C53000-G1176-C160-2...
Page 530 A Appendix Figure A-20 Connection example 7UT613 for a generator or motor Figure A-21 Connection example 7UT613 as transversal differential protection for a generator with two windings per phase 7UT613/63x Manual C53000-G1176-C160-2...
Page 531 A.3 Connection Examples Figure A-22 Connection example 7UT613 for an earthed shunt reactor with current trans- former between starpoint and earthing point 7UT613/63x Manual C53000-G1176-C160-2...
Page 532 A Appendix Figure A-23 Connection example 7UT613 as high-impedance protection on a transformer winding with earthed starpoint (the illustration shows the partial connection of the high-impedance protection); I is connected to the high-sensitivity input 7UT613/63x Manual C53000-G1176-C160-2...
Page 533 A.3 Connection Examples Figure A-24 Connection example 7UT613 for a three-phase power transformer with current transformers between star- point and earthing point, additional connection for high-impedance protection; I connected to the high- sensitivity input 7UT613/63x Manual C53000-G1176-C160-2...
Page 534 A Appendix Figure A-25 Connection example 7UT613 as single-phase busbar protection for 7 feeders, illustrated for phase L1 7UT613/63x Manual C53000-G1176-C160-2...
Page 535 A.3 Connection Examples Figure A-26 Connection example 7UT613 as busbar protection for 6 feeders, connected via external summation trans- formers (SCT) — partial illustration for feeders 1, 2 and 6 7UT613/63x Manual C53000-G1176-C160-2...
Page 536: Voltage Transformer Connection Examples
A Appendix A.3.2 Voltage Transformer Connection Examples Figure A-27 Voltage connections to three wye-connected voltage transformers (only in 7UT613 and 7UT633) 7UT613/63x Manual C53000-G1176-C160-2...
Page 537 A.3 Connection Examples Figure A-28 Voltage connections to three wye-connected voltage transformers with addition- al open-delta windings (e-n–windings; only in 7UT613 and 7UT633) 7UT613/63x Manual C53000-G1176-C160-2...
Page 538: Assignment Of Protection Functions To Protected Objects
A Appendix A.3.3 Assignment of Protection Functions to Protected Objects Not every protection function implemented in the 7UT613/63x is useful or even possi- ble for every conceivable protected object. The following table shows which protection functions are possible for which protected objects. Once a protected object has been configured (as described in subsection 2.1.3), only those protection functions are allowed and settable that are valid according to the table below.
Page 539: Current Transformer Requirements
A.4 Current Transformer Requirements Current Transformer Requirements Formula symbols/terms used (in accordance with IEC 60044-6, as defined) = rated symmetrical short-circuit current factor (example: CT 5P20 → K = 20) = effective symmetrical short-circuit current factor = rated transient dimensioning factor = maximum symmetrical through flowing fault current scc max (ext.
Page 540: Current Transformer In Accordance With Bs 3938/Iec 60044-1 (2000)
The calculations listed above are simplified in order to facilitate a quick and safe CT calculation/verification. An accurate calculation/verification can be carried out with the Siemens CTDIM program as from V3.21. The results of the CTDIM program have been released by the device manufacturer.
Page 541 A.4 Current Transformer Requirements Mismatching factor for 7UT613/63x, (limited resolution of the measurement) where: = rated current of the protected object (in relation to the parameterised rated current) = parameterised rated current of the protected object = nominal device current Nrelay = maximum (rated) power of the protected object Nmax...
Page 542 A Appendix with: = voltage factor (for generators: 1,1) = nominal power of the transformer in kVA = nominal voltage of the transformer in kV = nominal power of the generator in kVA = nominal voltage of the generator in kV 7UT613/63x Manual C53000-G1176-C160-2...
Page 543: Default Settings
A.5 Default Settings Default Settings When the device leaves the factory, a large number of LED indicators, binary inputs and outputs as well as function keys are already preset. They are summarized in the following tables. A.5.1 LEDs Table A-1 LED Indication Presettings LEDs Allocated Func-...
Page 544: Function Keys
A Appendix A.5.4 Function Keys Table A-4 Applies to all devices and ordered variants Function Keys Allocated Func- Function No. Description tion Display of opera- tional instructions Display of primary operational mea- sured values An overview of the last 8 network faults >QuitG-TRP >Quitt Lock Out: General Trip Resetting the reclo-...
Page 545: Default Display
A.5 Default Settings A.5.5 Default Display For devices with a four-line display, you can scroll among the basic displays shown below. The numerical values shown are examples. The device will display only those values that make sense for the current application. For instance, voltages will only be shown if the device is provided with voltage inputs and these inputs have been config- ured;...
Page 546 A Appendix For devices with a graphic display, the basic displays shown below may appear: The device will display only those values that make sense for the current application. For instance, voltages and powers will only be shown if the device is provided with voltage inputs and these inputs have been configured;...
Page 547: Pre-Defined Cfc Charts
A.5 Default Settings A.5.6 Pre-defined CFC Charts On delivery of the SIPROTEC 4 device provides worksheets with preset CFC-charts. Figure A-33 CFC Charts for Transmission Block and Reclosure Interlocking The first chart converts the binary input „>DataStop“ from a single-point indication (SP) into an internal single-point indication (IM).
Page 548: Protocol-Dependent Functions
A Appendix Protocol-dependent Functions Protocol → IEC 61850 Eth- PROFIBUS PROFIBUS DNP3.0 Modbus Additional Function ↓ 60870-5-103 ernet (EN100) ASCII/RTU Service inter- face (optional) Operational Yes (fixed Measured values) values Metered Values Yes Fault Recording Yes Only via Only via Only via additional additional...
Page 549: Functional Scope
A.7 Functional Scope Functional Scope Addr. Parameter Setting Options Default Setting Comments Grp Chge OPTION Disabled Disabled Setting Group Change Option Enabled PROT. OBJECT 3 phase transf. 3 phase transf. Protection Object 1 phase transf. Autotransf. Autotr. node Generator/Motor 3ph Busbar 1ph Busbar DIFF.
Page 550 A Appendix Addr. Parameter Setting Options Default Setting Comments DMT/IDMT 3I0 2 Disabled Disabled DMT / IDMT 3I0 2 Definite Time TOC IEC TOC ANSI User Defined PU User def. Reset DMT/IDMT 3I0 3 Disabled Disabled DMT / IDMT 3I0 3 Definite Time TOC IEC TOC ANSI...
Page 551 A.7 Functional Scope Addr. Parameter Setting Options Default Setting Comments EXT. TRIP 1 Disabled Disabled External Trip Function 1 Enabled EXT. TRIP 2 Disabled Disabled External Trip Function 2 Enabled RTD-BOX INPUT Disabled Disabled External Temperature Input Port C Port D RTD CONNECTION 6 RTD simplex 6 RTD simplex...
Page 552: Settings
A Appendix Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings. The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter Function Setting Options Default Setting Comments...
Page 553 A.8 Settings Addr. Parameter Function Setting Options Default Setting Comments Pick-up thresh. 0.05 .. 35.00 A 2.00 A Pick-up threshold I meas. loca- 0.25 .. 175.00 A 10.00 A tion 1 Pick-up thresh. 0.05 .. 35.00 A 2.00 A Pick-up threshold I meas. loca- 0.25 ..
Page 554 A Appendix Addr. Parameter Function Setting Options Default Setting Comments Pick-up thresh. 0.01 .. 17.00 Q/SnS 1.10 Q/SnS Pick-up threshold Q-side P.U. THRESHOLD -0.99 .. 0.99 0.50 Pickup Threshold T TRIP DELAY 0.00 .. 3600.00 sec 1.00 sec Trip Time Delay T PICKUP DELAY 0.00 ..
Page 555 A.8 Settings Addr. Parameter Function Setting Options Default Setting Comments ASSIGNM. 5M,2S P.System Data 1 M1+M2+M3,M4+M5 M1+M2+M3,M4+M5 Assignment at 5 as- M1+M2,M3+M4+M5 sig.Meas.Loc./ 2 Sides M1+M2+M3+M4,M5 M1,M2+M3+M4+M5 ASSIGNM. 5M,3S P.System Data 1 M1+M2,M3+M4,M5 M1+M2,M3+M4,M5 Assignment at 5 as- M1+M2,M3,M4+M5 sig.Meas.Loc./ 3 Sides M1,M2+M3,M4+M5 M1+M2+M3,M4,M5 M1,M2+M3+M4,M5...
Page 556 A Appendix Addr. Parameter Function Setting Options Default Setting Comments VT SET P.System Data 1 Not connected Measuring loc.1 VT set UL1, UL2, UL3 is as- Side 1 signed Side 2 Side 3 Measuring loc.1 Measuring loc.2 Measuring loc.3 Busbar VT U4 P.System Data 1 Not connected...
Page 557 A.8 Settings Addr. Parameter Function Setting Options Default Setting Comments CONNECTION S3 P.System Data 1 Transf. Winding Connection Side VECTOR GRP S3 P.System Data 1 Vector Group Numeral of Side 3 UN-PRI SIDE 4 P.System Data 1 0.4 .. 800.0 kV 11.0 kV Rated Primary Voltage Side 4 SN SIDE 4...
Page 558 A Appendix Addr. Parameter Function Setting Options Default Setting Comments I PRIMARY OP S5 P.System Data 1 1 .. 100000 A 200 A Primary Operating Current Side I PRIMARY OP 1 P.System Data 1 1 .. 100000 A 200 A Primary Operating Current End 1 I PRIMARY OP 2 P.System Data 1...
Page 559 A.8 Settings Addr. Parameter Function Setting Options Default Setting Comments DMT/IDMT E AT P.System Data 1 no assig. poss. AuxiliaryCT IX1 DMT / IDMT Earth assigned to AuxiliaryCT IX1 AuxiliaryCT IX2 AuxiliaryCT IX3 AuxiliaryCT IX4 DMT 1PHASE AT P.System Data 1 no assig.
Page 560 A Appendix Addr. Parameter Function Setting Options Default Setting Comments BREAKER FAIL.AT P.System Data 1 Side 1 Side 1 Breaker Failure Protection as- Side 2 signed to Side 3 Side 4 Side 5 Measuring loc.1 Measuring loc.2 Measuring loc.3 Measuring loc.4 Measuring loc.5 Ext.
Page 561 A.8 Settings Addr. Parameter Function Setting Options Default Setting Comments IN-SEC CT I3 P.System Data 1 CT Rated Secondary Current I3 0.1A STRPNT->BUS I4 P.System Data 1 CT-Starpoint I4 in Direction of Busbar IN-PRI CT I4 P.System Data 1 1 .. 100000 A 200 A CT Rated Primary Current I4 IN-SEC CT I4...
Page 562 A Appendix Addr. Parameter Function Setting Options Default Setting Comments IN-SEC CT IX2 P.System Data 1 CT rated secondary current IX2 EARTH IX3 AT P.System Data 1 Terminal R7 Terminal R7 Earthing electrod IX3 connected Terminal R8 IN-PRI CT IX3 P.System Data 1 1 ..
Page 563 A.8 Settings Addr. Parameter Function Setting Options Default Setting Comments 1111 PoleOpenCurr.S1 P.System Data 2 0.04 .. 1.00 I/InS 0.10 I/InS Pole Open Current Threshold Side 1 1112 PoleOpenCurr.S2 P.System Data 2 0.04 .. 1.00 I/InS 0.10 I/InS Pole Open Current Threshold Side 2 1113 PoleOpenCurr.S3...
Page 564 A Appendix Addr. Parameter Function Setting Options Default Setting Comments 1151 PoleOpenCurrIX1 P.System Data 2 0.04 .. 1.00 A 0.04 A Pole Open Current Threshold AuxiliaryCT1 0.20 .. 5.00 A 0.20 A 1152 PoleOpenCurrIX2 P.System Data 2 0.04 .. 1.00 A 0.04 A Pole Open Current Threshold AuxiliaryCT2...
Page 565 A.8 Settings Addr. Parameter Function Setting Options Default Setting Comments 1301 REF PROT. Restricted Earth Fault Protection Block relay 1311 I-REF> 0.05 .. 2.00 I/InS 0.15 I/InS Pick up value I REF> 0.00 .. 60.00 sec; ∞ 1312A T I-REF> 0.00 sec T I-REF>...
Page 566 A Appendix Addr. Parameter Function Setting Options Default Setting Comments 2027 ANSI CURVE Phase O/C Very Inverse Very Inverse ANSI Curve Inverse Short Inverse Long Inverse Moderately Inv. Extremely Inv. Definite Inv. 1.00 .. 20.00 I/Ip; ∞ 2031 I/Ip PU T/Tp Phase O/C Pickup Curve I/Ip - TI/TIp 0.01 ..
Page 567 A.8 Settings Addr. Parameter Function Setting Options Default Setting Comments 2227 ANSI CURVE 3I0 O/C Very Inverse Very Inverse ANSI Curve Inverse Short Inverse Long Inverse Moderately Inv. Extremely Inv. Definite Inv. 1.00 .. 20.00 I/Ip; ∞ 2231 I/I0p PU T/TI0p 3I0 O/C Pickup Curve 3I0/3I0p - 0.01 ..
Page 568 A Appendix Addr. Parameter Function Setting Options Default Setting Comments 1.00 .. 20.00 I/Ip; ∞ 2431 I/IEp PU T/TEp Earth O/C Pickup Curve IE/IEp - TIE/TIEp 0.01 .. 999.00 TD 0.05 .. 0.95 I/Ip; ∞ 2432 MofPU Res T/TEp Earth O/C Multiple of Pickup <->...
Page 569 A.8 Settings Addr. Parameter Function Setting Options Default Setting Comments 3027 ANSI CURVE Phase O/C 2 Very Inverse Very Inverse ANSI Curve Inverse Short Inverse Long Inverse Moderately Inv. Extremely Inv. Definite Inv. 1.00 .. 20.00 I/Ip; ∞ 3031 I/Ip PU T/Tp Phase O/C 2 Pickup Curve I/Ip - TI/TIp 0.01 ..
Page 570 A Appendix Addr. Parameter Function Setting Options Default Setting Comments 3227 ANSI CURVE Phase O/C 3 Very Inverse Very Inverse ANSI Curve Inverse Short Inverse Long Inverse Moderately Inv. Extremely Inv. Definite Inv. 1.00 .. 20.00 I/Ip; ∞ 3231 I/Ip PU T/Tp Phase O/C 3 Pickup Curve I/Ip - TI/TIp 0.01 ..
Page 571 A.8 Settings Addr. Parameter Function Setting Options Default Setting Comments 3427 ANSI CURVE 3I0 O/C 2 Very Inverse Very Inverse ANSI Curve Inverse Short Inverse Long Inverse Moderately Inv. Extremely Inv. Definite Inv. 1.00 .. 20.00 I/Ip; ∞ 3431 I/I0p PU T/TI0p 3I0 O/C 2 Pickup Curve 3I0/3I0p - 0.01 ..
Page 572 A Appendix Addr. Parameter Function Setting Options Default Setting Comments 3627 ANSI CURVE 3I0 O/C 3 Very Inverse Very Inverse ANSI Curve Inverse Short Inverse Long Inverse Moderately Inv. Extremely Inv. Definite Inv. 1.00 .. 20.00 I/Ip; ∞ 3631 I/I0p PU T/TI0p 3I0 O/C 3 Pickup Curve 3I0/3I0p - 0.01 ..
Page 573 A.8 Settings Addr. Parameter Function Setting Options Default Setting Comments 1.00 .. 20.00 I/Ip; ∞ 3831 I/IEp PU T/TEp Earth O/C 2 Pickup Curve IE/IEp - TIE/TIEp 0.01 .. 999.00 TD 0.05 .. 0.95 I/Ip; ∞ 3832 MofPU Res T/TEp Earth O/C 2 Multiple of Pickup <->...
Page 574 A Appendix Addr. Parameter Function Setting Options Default Setting Comments 4208A T EMERGENCY Therm. Overload 10 .. 15000 sec 100 sec Emergency Time 0.60 .. 10.00 I/InS; ∞ ∞ I/InS 4209A I MOTOR START Therm. Overload Current Pickup Value of Motor Starting 4210 TEMPSENSOR RTD...
Page 575 A.8 Settings Addr. Parameter Function Setting Options Default Setting Comments 40 .. 200 °C 100 °C 4412 TEMP. RISE I Therm.Overload2 Temperature Rise at Rated Sec. Curr. 104 .. 392 °F 212 °F 4413 TEMP. RISE I Therm.Overload2 Temperature Rise at Rated Sec. Curr.
Page 576 A Appendix Addr. Parameter Function Setting Options Default Setting Comments 5312 U> Overvoltage 0.30 .. 1.70 U/UnS 1.15 U/UnS Pick-up voltage U> 0.00 .. 60.00 sec; ∞ 5313 T U> Overvoltage 3.00 sec T U> Time Delay 5314 U>> Overvoltage 30.0 ..
Page 577 A.8 Settings Addr. Parameter Function Setting Options Default Setting Comments 7622 MiMa RESET TIME Min/Max meter 0 .. 1439 min 0 min MinMax Reset Timer 7623 MiMa RESETCYCLE Min/Max meter 1 .. 365 Days 7 Days MinMax Reset Cycle Period 7624 MinMaxRES.START Min/Max meter...
Page 578 A Appendix Addr. Parameter Function Setting Options Default Setting Comments 0.00 .. 60.00 sec; ∞ 8602 T DELAY External Trips 1.00 sec Ext. Trip 1 Time Delay 8701 EXTERN TRIP 2 External Trips External Trip Function 2 Block relay 0.00 .. 60.00 sec; ∞ 8702 T DELAY External Trips...
Page 579 A.8 Settings Addr. Parameter Function Setting Options Default Setting Comments -50 .. 250 °C; ∞ 120 °C 9045 RTD 4 STAGE 2 RTD-Box RTD 4: Temperature Stage 2 Pickup -58 .. 482 °F; ∞ 248 °F 9046 RTD 4 STAGE 2 RTD-Box RTD 4: Temperature Stage 2 Pickup...
Page 580 A Appendix Addr. Parameter Function Setting Options Default Setting Comments -50 .. 250 °C; ∞ 120 °C 9085 RTD 8 STAGE 2 RTD-Box RTD 8: Temperature Stage 2 Pickup -58 .. 482 °F; ∞ 248 °F 9086 RTD 8 STAGE 2 RTD-Box RTD 8: Temperature Stage 2 Pickup...
Page 581 A.8 Settings Addr. Parameter Function Setting Options Default Setting Comments -50 .. 250 °C; ∞ 120 °C 9125 RTD12 STAGE 2 RTD-Box RTD12: Temperature Stage 2 Pickup -58 .. 482 °F; ∞ 248 °F 9126 RTD12 STAGE 2 RTD-Box RTD12: Temperature Stage 2 Pickup 7UT613/63x Manual C53000-G1176-C160-2...
Page 582: Information List
A Appendix Information List Indications for IEC 60 870-5-103 are always reported ON / OFF if they are subject to general interrogation for IEC 60 870-5-103. If not, they are reported only as ON. New user-defined indications or such newly allocated to IEC 60 870-5-103 are set to ON / OFF and subjected to general interrogation if the information type is not a spon- taneous event („.._Ev“).
Page 583 A.9 Information List Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 Lock Out: General TRIP (G-TRP P.System Data 2 IntSP Quit) Error Systeminterface (SysIn- Supervision IntSP tErr.) Error FMS FO 1 (Error FMS1) Supervision Error FMS FO 2 (Error FMS2) Supervision Disturbance CFC (Distur.CFC) Supervision...
Page 584 A Appendix Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 023.2404 >BLOCK Phase time overcurrent Phase O/C LED BI (>BLK Phase O/C) 023.2411 Time Overcurrent Phase is OFF Phase O/C (O/C Phase OFF) 023.2412 Time Overcurrent Phase is Phase O/C BLOCKED (O/C Phase BLK) 023.2413 Time Overcurrent Phase is...
Page 585 A.9 Information List Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 023.2552 I> TRIP (I> TRIP) Phase O/C 023.2553 Ip TRIP (Ip TRIP) Phase O/C 024.2404 >BLOCK Earth time overcurrent Earth O/C LED BI (>BLK Earth O/C) 024.2411 Time Overcurrent Earth is OFF Earth O/C (O/C Earth OFF) 024.2412...
Page 586 A Appendix Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 033.2413 Undervoltage protection is Undervoltage ACTIVE (Undervolt. ACT) 033.2491 Undervoltage: Not avail. for this Undervoltage obj. (U< err. Obj.) 033.2492 Undervoltage: error assigned VT Undervoltage (U< err. VT) 033.2502 >BLOCK undervoltage protection Undervoltage LED BI...
Page 587 A.9 Information List Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 044.2601 >Emergency start Th. Overload Therm. Overload LED BI Protection (>Emer.Start O/L) 044.2602 Th. Overload Current Alarm (I Therm. Overload alarm) (O/L I Alarm) Thermal Overload Alarm (O/L Θ 044.2603 Therm.
Page 588 A Appendix Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 Daylight Saving Time (DayLight- Device SavTime) Setting calculation is running Device (Settings Calc.) Settings Check (Settings Check) Device Level-2 change (Level-2 change) Device Local setting change (Local Device change) Frequency out of range (Frequ.
Page 589 A.9 Information List Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 Error Board 6 (Error Board 6) Supervision Error Board 7 (Error Board 7) Supervision Error Board 0 (Error Board 0) Supervision Error: Offset (Error Offset) Supervision 191.2404 >BLOCK 3I0 time overcurrent 3I0 O/C LED BI (>BLK 3I0 O/C)
Page 590 A Appendix Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 192.2413 Dynamic settings O/C 3I0 are ColdLoadPickup ACTIVE (3I0 Dyn.set.ACT) Alarm: Analog input adjustment Supervision invalid (Alarm adjustm.) Fuse Fail Monitor is switched Supervision OFF (Fuse Fail M.OFF) Error: Communication Module B Supervision (Err.
Page 591 A.9 Information List Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 200.2421 Time Overcurrent 1Phase picked 1Phase O/C up (O/C 1Ph PU) 200.2451 Time Overcurrent 1Phase TRIP 1Phase O/C (O/C 1Ph TRIP) 200.2492 O/C 1Phase err.:No auxiliary CT 1Phase O/C assigned (O/C 1Ph Err CT) 200.2502 >BLOCK Time Overcurrent 1Ph.
Page 592 A Appendix Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 205.2404 >BLOCK restricted earth fault REF 2 LED BI prot. 2 (>BLOCK REF2) 205.2411 Restricted earth fault 2 is REF 2 switched OFF (REF2 OFF) 205.2412 Restricted earth fault 2 is REF 2 BLOCKED (REF2 BLOCKED) 205.2413...
Page 593 A.9 Information List Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 207.2404 >BLOCK Phase time overcurrent Phase O/C 2 LED BI 2 (>BLK Phase O/C2) 207.2411 Time Overcurrent Phase-2 is Phase O/C 2 OFF (O/C Phase-2 OFF) 207.2412 Time Overcurrent Phase-2 is Phase O/C 2 BLOCKED (O/C Phase-2 BLK) 207.2413...
Page 594 A Appendix Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 207.2541 Time Overcurrent Phase-2 I>> Phase O/C 2 Time Out (O/C Ph2 I>>TOut) 207.2542 Time Overcurrent Phase-2 I> Phase O/C 2 Time Out (O/C Ph2 I> TOut) 207.2543 Time Overcurrent Phase-2 Ip Phase O/C 2 Time Out (O/C Ph2 Ip TOut) 207.2551...
Page 595 A.9 Information List Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 209.2526 Time Overcurrent Ph3 L1 InRush Phase O/C 3 picked up (Ph3L1 InRush PU) 209.2527 Time Overcurrent Ph3 L2 InRush Phase O/C 3 picked up (Ph3L2 InRush PU) 209.2528 Time Overcurrent Ph3 L3 InRush Phase O/C 3...
Page 596 A Appendix Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 235.2125 Function $00 TRIP Delay Time Out ($00 Time Out) 235.2126 Function $00 TRIP ($00 TRIP) 235.2128 Function $00 has invalid settings ($00 inval.set) 235.2701 >Function $00 block TRIP L12 on off LED BI (>$00 Blk Trip12)
Page 597 A.9 Information List Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 321.2501 >BLOCK time overcurrent 3I0-2 3I0 O/C 2 LED BI InRush (>BLK 3I0O/C2Inr) 321.2502 >BLOCK 3I0>> time overcurrent 3I0 O/C 2 LED BI 2 (>BLOCK 3I0-2>>) 321.2503 >BLOCK 3I0> time overcurrent 2 3I0 O/C 2 LED BI (>BLOCK 3I0-2>)
Page 598 A Appendix Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 323.2501 >BLOCK time overcurrent 3I0-3 3I0 O/C 3 LED BI InRush (>BLK 3I0O/C3Inr) 323.2502 >BLOCK 3I0>> time overcurrent 3I0 O/C 3 LED BI 3 (>BLOCK 3I0-3>>) 323.2503 >BLOCK 3I0> time overcurrent 3 3I0 O/C 3 LED BI (>BLOCK 3I0-3>)
Page 599 A.9 Information List Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 325.2503 >BLOCK IE> time overcurrent 2 Earth O/C 2 LED BI (>BLOCK IE-2>) 325.2504 >BLOCK IEp time overcurrent 2 Earth O/C 2 LED BI (>BLOCK IE-2p) 325.2514 Time Overcurrent Earth 2 IE>> Earth O/C 2 BLOCKED (IE-2>>...
Page 600 A Appendix Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 Primary fault current IL1 side1 P.System Data 2 (IL1S1:) Primary fault current IL2 side1 P.System Data 2 (IL2S1:) Primary fault current IL3 side1 P.System Data 2 (IL3S1:) Primary fault current IL1 side2 P.System Data 2 (IL1S2:) Primary fault current IL2 side2...
Page 601 A.9 Information List Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 5010 >BLOCK fuse failure monitor Supervision LED BI (>FFM BLOCK) 5083 >BLOCK reverse power protec- Reverse Power LED BI tion (>Pr BLOCK) 5086 >Stop valve tripped (>SV tripped) Reverse Power LED BI 5091 Reverse power prot.
Page 602 A Appendix Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 5147 Phase Rotation L1L2L3 (Rotation P.System Data 1 L1L2L3) 5148 Phase Rotation L1L3L2 (Rotation P.System Data 1 L1L3L2) 5151 I2 switched OFF (I2 OFF) Unbalance Load 5152 I2 is BLOCKED (I2 BLOCKED) Unbalance Load 5153 I2 is ACTIVE (I2 ACTIVE)
Page 603 A.9 Information List Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 5363 Overexcitation protection is Overexcit. ACTIVE (U/f> ACTIVE) 5367 Overexc. prot.: U/f warning stage Overexcit. (U/f> warn) 5369 Reset memory of thermal replica Overexcit. U/f (RM th.rep. U/f) 5370 Overexc.
Page 604 A Appendix Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 5663 Diff. prot.: Blocked by CT fault L2 Diff. Prot (Block Iflt.L2) 5664 Diff. prot.: Blocked by CT fault L3 Diff. Prot (Block Iflt.L3) 5666 Diff: Increase of char. phase Diff.
Page 605 A.9 Information List Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 5725 Diff. prot: Adaption factor CT I5 Diff. Prot (Diff CT-I5:) 5726 Diff. prot: Adaption factor CT I6 Diff. Prot (Diff CT-I6:) 5727 Diff. prot: Adaption factor CT I7 Diff.
Page 606 A Appendix Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 6865 Failure Trip Circuit (FAIL: Trip cir.) TripCirc.Superv 11001 >Reset MinMaxValues (>Reset Min/Max meter LED BI MinMax) 12006 >Frequency prot.: Block Stage f< Frequency Prot. LED BI (>Freq. f< blk) 12007 >Frequency prot.: Block Stage Frequency Prot.
Page 607 A.9 Information List Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 14152 RTD 5 Temperature stage 1 RTD-Box picked up (RTD 5 St.1 p.up) 14153 RTD 5 Temperature stage 2 RTD-Box picked up (RTD 5 St.2 p.up) 14161 Fail: RTD 6 (broken wire/shorted) RTD-Box (Fail: RTD 6) 14162...
Page 608 A Appendix Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 30063 General: Adaption factor CT M4 P.System Data 2 (Gen CT-M4:) 30064 General: Adaption factor CT M5 P.System Data 2 (Gen CT-M5:) 30065 General: Adaption factor VT P.System Data 2 UL123 (Gen VT-U1:) 30067 parameter too low: (par too low:)
Page 609 A.9 Information List Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 30092 End 8 is disconnected (I8 discon- Discon.MeasLoc nected) 30093 End 9 is disconnected (I9 discon- Discon.MeasLoc nected) 30094 End 10 is disconnected Discon.MeasLoc (I10disconnected) 30095 End 11 is disconnected Discon.MeasLoc (I11disconnected) 30096...
Page 610 A Appendix Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 30120 Broken wire IL1 measurement lo- Supervision cation 1 (brk. wire IL1M1) 30121 Broken wire IL2 measurement lo- Supervision cation 1 (brk. wire IL2M1) 30122 Broken wire IL3 measurement lo- Supervision cation 1 (brk.
Page 611 A.9 Information List Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 30253 Primary fault current IL3 meas. P.System Data 2 loc. 1 (IL3M1:) 30254 Primary fault current IL1 meas. P.System Data 2 loc. 2 (IL1M2:) 30255 Primary fault current IL2 meas. P.System Data 2 loc.
Page 612 A Appendix Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 30354 >Manual close signal measure- P.System Data 2 LED BI ment loc. 4 (>ManualClose M4) 30355 >Manual close signal measure- P.System Data 2 LED BI ment loc. 5 (>ManualClose M5) 30356 >Manual close signal side 1 P.System Data 2...
Page 613 A.9 Information List Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 30610 Accumulation of interrupted curr. Statistics L1 S2 (ΣIL1S2:) 30611 Accumulation of interrupted curr. Statistics L2 S2 (ΣIL2S2:) 30612 Accumulation of interrupted curr. Statistics L3 S2 (ΣIL3S2:) 30620 Accumulation of interrupted curr.
Page 614 A Appendix Description Function Log Buffers Configurable in Matrix IEC 60870-5-103 30781 Accumulation of interrupted curr. Statistics L1 S4 (ΣIL1S4:) 30782 Accumulation of interrupted curr. Statistics L2 S4 (ΣIL2S4:) 30783 Accumulation of interrupted curr. Statistics L3 S4 (ΣIL3S4:) 30784 Accumulation of interrupted curr. Statistics L1 S5 (ΣIL1S5:) 30785...
Page 615: Group Alarms
A.10 Group Alarms A.10 Group Alarms Description Function No. Description Error Sum Alarm Error MeasurSys Fail: RTD-Box 1 Fail: RTD-Box 2 Broken wire 30145 Fail.Disconnect Alarm Sum Event Fail I Superv. Fail U Superv. Fail Ph. Seq. Alarm adjustm. Fail Battery Err.
Page 616 A Appendix Description Function No. Description Error MeasurSys Error Board 0 Error Board 1 Error Board 2 Error Board 3 Error Board 4 Error Board 5 Error Board 6 Error Board 7 Error1A/5Awrong Error Offset Error1A/5Awrong 30097 Err. IN CT M1 30098 Err.
Page 617: Measured Values
A.11 Measured Values A.11 Measured Values Description Function IEC 60870-5-103 Configurable in Matrix Control DIGSI (CntrlDIGSI) Cntrl Authority Operating hours greater than (OpHour>) SetPoint(Stat) 044.2611 Temperat. rise for warning and trip (Θ/Θtrip Meas. Thermal 044.2612 Temperature rise for phase L1 (Θ/ΘtripL1=) Meas.
Page 618 A Appendix Description Function IEC 60870-5-103 Configurable in Matrix 328.2714 Min. of average value $00 ($00amin=) addMV 328.2715 Max. of average value $00 ($00amax=) addMV U L1-E (UL1E=) Measurement U L2-E (UL2E=) Measurement U L3-E (UL3E=) Measurement U L12 (UL12=) Measurement U L23 (UL23=) Measurement...
Page 619 A.11 Measured Values Description Function IEC 60870-5-103 Configurable in Matrix 7744 IDiffL3(I/Inominal object [%]) (IDiffL3=) Meas. Dif/Rest. 7745 IRestL1(I/Inominal object [%]) (IRestL1=) Meas. Dif/Rest. 7746 IRestL2(I/Inominal object [%]) (IRestL2=) Meas. Dif/Rest. 7747 IRestL3(I/Inominal object [%]) (IRestL3=) Meas. Dif/Rest. 30633 Phase angle of current I1 (ϕI1=) Measurement 30634 Phase angle of current I2 (ϕI2=)
Page 620 A Appendix Description Function IEC 60870-5-103 Configurable in Matrix 30675 Operat. meas. current IL3 meas. loc. 3 Measurement (IL3M3=) 30676 3I0 (zero sequence) of meas. loc. 3 (3I0M3=) Measurement 30677 I1 (positive sequence) of meas. loc. 3 Measurement (I1M3=) 30678 I2 (negative sequence) of meas.
Page 621 A.11 Measured Values Description Function IEC 60870-5-103 Configurable in Matrix 30736 Phase angle in phase IL1 meas. loc. 1 Measurement (ϕIL1M1=) 30737 Phase angle in phase IL2 meas. loc. 1 Measurement (ϕIL2M1=) 30738 Phase angle in phase IL3 meas. loc. 1 Measurement (ϕIL3M1=) 30739...
Page 622 A Appendix 7UT613/63x Manual C53000-G1176-C160-2...
Page 623: Glossary
Glossary Battery The buffer battery ensures that specified data areas, flags, timers and counters are re- tained retentively. Bay controllers Bay controllers are devices with control and monitoring functions without protective functions. Bit pattern indica- Bit pattern indication is a processing function by means of which items of digital tion process information applying across several inputs can be detected together in paral- lel and processed further.
Page 624 Glossary Component view In addition to a topological view, SIMATIC Manager offers you a component view. The component view does not offer any overview of the hierarchy of a project. It does, how- ever, provide an overview of all the SIPROTEC 4 devices within a project. COMTRADE Common Format for Transient Data Exchange, format for fault records.
Page 625 Glossary This term means that a conductive part is connected via an earthing system to the → Earth (verb) earth. Earthing Earthing is the total of all means and measures used for earthing. Electromagnetic Electromagnetic compatibility (EMC) is the ability of an electrical apparatus to function compatibility fault-free in a specified environment without influencing the environment unduly.
Page 626 Glossary image. The current process state can also be sampled after a data loss by means of a GI. GOOSE message GOOSE messages (Generic Object Oriented Substation Event) are data pakets which are transferred event-controlled via the Ethernet communication system. They serve for direct information exchange among the relays.
Page 627 Glossary → IRC combination Inter relay commu- nication IRC combination Inter Relay Communication, IRC, is used for directly exchanging process information between SIPROTEC 4 devices. You require an object of type IRC combination to con- figure an inter relay communication. Each user of the combination and all the neces- sary communication parameters are defined in this object.
Page 628 Glossary Modems Modem profiles for a modem connection are stored in this object type. Measured value MVMV Metered value which is formed from the measured value Measured value with time Measured value, user-defined Navigation pane The left pane of the project window displays the names and symbols of all containers of a project in the form of a folder tree.
Page 629 Glossary Project Content-wise, a project is the image of a real power supply system. Graphically, a project is represented as a number of objects which are integrated in a hierarchical structure. Physically, a project consists of a number of directories and files containing project data.
Page 630 Glossary SIPROTEC 4 device This object type represents a real SIPROTEC 4 device with all the setting values and process data it contains. SIPROTEC 4 This object type represents a variant of an object of type SIPROTEC 4 device. The variant device data of this variant may well differ from the device data of the original object.
Page 631: Literature
Literature SIPROTEC 4 System Manual; E50417-H1176-C151-A2 SIPROTEC DIGSI, Start UP; E50417-G1176-C152-A2 DIGSI CFC, Manual; E50417-H1176-C098-A4 SIPROTEC SIGRA 4, Manual; E50417-H1176-C070-A2 7UT613/63x Manual C53000-G1176-C160-2...
Page 632 Literature 7UT613/63x Manual C53000-G1176-C160-2...
Page 633: Index
Index Index Acknowledgement of Commands 337 CFC 481 Add-on Restraint 111 Change of Operating Stage 384 Add-on Stabilisation 107 Changing Setting Groups 37, 341 Additional Functions 300, 487 Check: Time Synchronisation Interface 375 Additional Interface 429 Circuit Breaker Data 83 Ageing Rate 225, 229 Circuit Breaker Failure Protection 27, 478 Alternating Voltage 423...
Page 634 Index Delay Times 175 Earth Fault 127, 142, 173, 198, 199, 204 Dialogue Box 383 CT Saturation 145 Differential Current 129 Restraint 144 Monitoring 131 Restraint Quantity 145 Differential Current Monitor 439 Sensitivity 144 Differential Currents 108 Starpoint Current 144 Differential Protection Through-Fault Current 144 Additional Stabilisation 133...
Page 635 Index Forward Power Monitoring 26 Input/Output Module Forward Power Protection C-I/O-1 353 Delay Times 253 Inrush Current 108, 159, 180, 187 Measuring Procedure 253 Inrush Currents 108 Pickup Values 251 Inrush Restraint 108, 162, 163, 173, 175, 185, 185, Fourier Analysis 108 Frequency Increase 263 Instantaneous Tripping 109, 111 Frequency Protection 27, 476...
Page 636 Index MI System 19 Single-phase 200 Mini-busbar 123 single-phase 196 Mini-busbars 38 Startup Current 164 Mini-busbars; Busbars 68 Time Delay 163, 185, 201, 204 Minimum Command Duration 113 Time Multiplier 165, 165, 186, 187 Minimum Trip Command Duration 295 Trip Characteristic 164, 165, 167, 174 Minimum Values 489, 489 Tripping 150, 155 Minimum, Maximum Values 329...
Page 637 Index Start Test Measurement Recording 418 Startup 109 Rack Mounting 370 Statistic Values 489 Rated Frequency 65 Summation Transformer 125 Reactor 122 Connection 126 Reclosure Interlocking 295 Symmetrical Fault 127 Reference Voltages 279 Winding Arrangement 128 Regulations 430 Winding Factors 128 Restraining Values 312 Switching (interlocked/non-interlocked) 334 Restraint Current 106, 109, 111...
Page 638 Index Time Grading Schedule of the Network 164 Time Overcurrent Protection Unbalanced Load Protection 25, 457 Characteristics 174 Characteristics 207, 457 Cold Load Pickup 158, 175, 187 Current Stages 457 Earth Current 25, 453 Delay Times 213 Inrush Restraint 159 Dropout to Pickup Ratios 458 Phase Currents 24, 442 Operating Times 458...

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Siprotec 7ut63 series Siprotec 7ut635*-* d/e series Siprotec 7ut635*-* p/q series Siprotec 7ut613*-* b series Siprotec 7ut613*-*d/e series Siprotec 7ut633*-* b series ... Show all

Siemens SIPROTEC 7UT613 series Manual

1 Introduction

2 Functions

3 Mounting and Commissioning

4 Technical Data

Appendix

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Summary of Contents for Siemens SIPROTEC 7UT613 series