Page 1 Preface Contents Introduction SIPROTEC Functions Differential Protection Mounting and Commissioning 7SD610 Technical Data V4.70 Appendix Literature Manual Glossary Index C53000-G1176-C145-6...
Page 2 SIPROTEC, SINAUT, SICAM and DIGSI are registered trademarks Document Version V04.40.01 of Siemens AG. Other designations in this manual might be trade- marks whose use by third parties for their own purposes would in- Release date 02.2011 fringe the rights of the owner.
Page 3: Functions
Council Directive 2004/108/EC) and concerning electrical equipment for use within specified voltage limits (Low-voltage directive 2006/95 EC). This conformity is proved by tests conducted by Siemens AG in accordance with the Council Directives in agreement with the generic standards EN61000-6-2 and EN 61000-6-4 for the EMC directive, and with the standard EN 60255-27 for the low-voltage directive.
Page 4: Technical Data
Additional Support Should further information on the System SIPROTEC 4 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 rep- resentative. Our Customer Support Center provides a 24-hour service.
Page 5 Preface Safety Information This manual does not constitute a complete index of all required safety measures for operation of the equip- ment (module, device), as special operational conditions may require additional measures. However, it com- prises important information that should be noted for purposes of personal safety as well as avoiding material damage.
Page 6: C53000-G1176-C145
The operational equipment (device, module) may only be used for such applications as set out in the catalogue and the technical description, and only in combination with third-party equipment recommended or approved by Siemens. The successful and safe operation of the device is dependent on proper handling, storage, installation, opera- tion, and maintenance.
Page 7 Preface Typographic and Symbol Conventions The following text formats are used when literal information from the device or to the device appear in the text flow: Parameter Names Designators of configuration or function parameters which may appear word-for-word in the display of the device or on the screen of a personal computer (with operation software DIGSI), are marked in bold letters in monospace type style.
Page 8 Preface Besides these, graphical symbols are used in accordance with IEC 60617-12 and IEC 60617-13 or similar. Some of the most frequently used are listed below: Analog input values AND-gate operation of input values OR-gate operation of input values Exclusive OR gate (antivalence): output is active, if only one of the inputs is active Coincidence gate: output is active, if both inputs are active or inactive at the same time...
Page 9: Table Of Contents
Contents Introduction................17 Overall Operation.
Page 10 Contents Differential Protection ............. . 65 2.3.1 Function Description .
Page 11 Contents 2.11 Undervoltage and Overvoltage Protection (optional) ........153 2.11.1 Overvoltage Protection.
Page 12 Contents 2.16 Function Control and Circuit Breaker Test ..........222 2.16.1 Function Control .
Page 13 Contents 2.18 Command Processing ............260 2.18.1 Control Authorization .
Page 14 Contents Technical Data ................321 General .
Page 15 Contents Default Settings ..............382 A.4.1 LEDs .
Page 16 Contents SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 17: Introduction
Introduction The SIPROTEC 4 7SD610 is introduced in this chapter. The device is presented in its application, characteris- tics, and functional scope. Overall Operation Application Scope Characteristics SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 18: Overall Operation
Introduction 1.1 Overall Operation Overall Operation The SIPROTEC 4 7SD610 line protection is equipped with a powerful microprocessor system. This provides fully digital processing of all functions in the device, from the acquisition of the measured values up to the output of commands to the circuit breakers, as well as the exchange of measured data with the other ends of the pro- tected area.
Page 19 Introduction 1.1 Overall Operation A voltage measuring input is provided for each phase-earth voltage. In principle, the differential protection does not require any measured voltage, however, for the directed overcurrent time protection, the connection of the phase earth voltages U und U is definitely required.
Page 20 Introduction 1.1 Overall Operation Serial Interfaces Communication with a personal computer using the DIGSI software program is possible via the serial operator interface. This allows all device functions to be handled conveniently. The serial service interface can also be used for communication with a personal computer using DIGSI. This port is especially well suited for a permanent connection of the devices to the PC or for operation via a modem.
Page 21: Application Scope
Introduction 1.2 Application Scope Application Scope The digital Differential Protection SIPROTEC 4 7SD610 is a selective short-circuit protection for overhead lines and cables with single- and multi-ended infeeds in radial, ring or any type of meshed systems of any voltage level.
Page 22 Introduction 1.2 Application Scope Control Functions The device is equipped with control functions which operate, close and open, switchgear devices via control keys, the system interface, binary inputs and a PC with DIGSI software. The status of the primary equipment can be transmitted to the device via auxiliary contacts connected to binary inputs.
Page 23 Introduction 1.2 Application Scope Communication Serial interfaces are available for the communication with operating, control and memory systems. A 9-pin DSUB socket on the front panel is used for local communication with a personal computer. By means of the SIPROTEC 4 operating software DIGSI, all operational and evaluation tasks can be executed via this operator interface, such as specifying and modifying configuration parameters and settings, configuring user- specific logic functions, retrieving operational and fault messages and measured values, reading out and dis- playing fault recordings, inquiring device conditions and measured values, issuing control commands.
Page 24: Characteristics
Introduction 1.3 Characteristics Characteristics General Features • Powerful 32-bit microprocessor system • Complete digital processing of measured values and control, from the sampling of the analog input values, the processing and organization of the communication between devices up to the closing and tripping com- mands to the circuit breakers •...
Page 25 Introduction 1.3 Characteristics Restricted Earth Fault Protection • Earth fault protection for earthed transformer windings • Short tripping time • High sensitivity for earth faults • High stability against external earth faults using the magnitude and phase relationship of through-flowing earth current External Direct and Remote Tripping •...
Page 26 Introduction 1.3 Characteristics Voltage Protection (optional) • Overvoltage and undervoltage detection with different stages • Two overvoltage stages for the phase-earth voltages • Two overvoltage stages for the phase-phase voltages • Two overvoltage stages for the positive sequence voltage, optionally with compounding •...
Page 27 Introduction 1.3 Characteristics Commissioning; Operation; Maintenance • Display of magnitude and phase angle of local and remote measured values • Indication of the calculated differential and restraint currents • Display of measured values of the communication link, such as transmission delay and availability Command Processing •...
Page 28 Introduction 1.3 Characteristics Additional Functions • Battery buffered real-time clock, which may be synchronized via a synchronization signal (e.g. DCF77, IRIG B, GPS via satellite receiver), binary input or system interface • Automatic time synchronization between the devices at the ends of the protected object via the protection data transmission •...
Page 29: Functions
Functions This chapter describes the individual functions of the SIPROTEC 4 device 7SD610. It shows the setting pos- sibilities for each function in maximum configuration. Guidelines for establishing setting values and, where re- quired, formulae are given. Based on the following information, it can also be determined which of the provided functions should be used. General Protection Data Interfaces and Protection Data Topology Differential Protection...
Page 30: General
Functions 2.1 General General A few seconds after the device is switched on, the default display appears on the LCD. In the 7SD610 the mea- sured values are displayed. Configuration settings can be entered by using a PC and the DIGSI operating software and transferred via the operator interface on the front panel of the device or via the service interface.
Page 31: Setting Notes
Functions 2.1 General Note The functions and default settings available depend on the device version ordered. 2.1.1.2 Setting Notes Configuring the functional scope The scope of functions with the available options is set in the Functional Scope dialog box to match plant re- quirements.
Page 32 Functions 2.1 General Otherwise, set the number of desired reclosing attempts there. You can select 1 AR-cycle to 8 AR-cycles. You can also set ASP (adaptive dead times); in this case the behaviour of the automatic reclosure function is determined by the cycles of the remote end. However, at one end of the line the number of cycles must be con- figured.
Page 33: Settings
Functions 2.1 General 2.1.1.3 Settings Addr. Parameter Setting Options Default Setting Comments Grp Chge OPTION Disabled Disabled Setting Group Change Option Enabled Trip mode 3pole only 3pole only Trip mode 1-/3pole DIFF.PROTECTION Enabled Enabled Differential protection Disabled DTT Direct Trip Disabled Disabled DTT Direct Transfer Trip...
Page 34: General Power System Data (Power System Data 1)
Functions 2.1 General 2.1.2 General Power System Data (Power System Data 1) The device requires some plant and power system data in order to be able to adapt its functions accordingly, depending on the actual application. The data required include for instance rated data of the substation and the measuring transformers, polarity and connection of the measured quantities, if necessary features of the circuit breakers, and others.
Page 35 Functions 2.1 General Voltage Connection The device features four voltage measuring inputs, three of which are connected to the set of voltage trans- formers. Various possibilities exist for the fourth voltage input U • Connection of the U input to the open delta winding Ue–n of the voltage transformer set: Address 210 is then set to: U4 transformer = Udelta transf..
Page 36 Functions 2.1 General Rated frequency The rated frequency of the power system is set under address 230 Rated Frequency. The factory presetting according to the ordering code (MLFB) only needs to be changed if the device is applied in a region different from the one indicated when ordering.
Page 37 Functions 2.1 General Current transformer 10P10; 30 VA → n = 10; P = 30 VA Current transformer 10P20; 20 VA → n = 20; P = 20 VA The operational accuracy limit factor n' is derived from these rated data and the actual secondary burden P': With n' = operational accuracy limit factor (effective overcurrent factor)
Page 38 Functions 2.1 General With this data the device establishes an approximate CT error characteristic and calculates the restraint quan- tity (see also Section 2.3). Calculation example: Current transformer 5P10; 20 VA Transformation 600 A / 5 A Internal burden 2 VA Secondary lines 4 mm Length 20 m Device 7SD610 , I...
Page 39: Settings
Functions 2.1 General Calculation example: Transformer YNd5 35 MV 110 kV / 25 kV Y-winding with tap changer ±10 % This results in the following: Rated current at rated voltage = 184 A Rated current at U + 10 % = 167 A Rated current at U –...
Page 40: Change Group
Functions 2.1 General Addr. Parameter Setting Options Default Setting Comments I4 transformer Not connected In prot. line I4 current transformer is In prot. line IY starpoint I4/Iph CT 0.010 .. 5.000 1.000 Matching ratio I4/Iph for CT's Rated Frequency 50 Hz 50 Hz Rated Frequency 60 Hz...
Page 41: Setting Notes
Functions 2.1 General 2.1.3.2 Setting Notes General If multiple setting groups are not required. Group A is the default selection. Then, the rest of this section is not applicable. If multiple setting groups are desired, the setting group change option must be set to Grp Chge OPTION = Enabled in the relay configuration of the functional scope (Section 2.1.1.2, address 103).
Page 42: General Protection Data (Power System Data 2)
Functions 2.1 General 2.1.4 General Protection Data (Power System Data 2) The general protection data (P.System Data 2) include settings associated with all functions rather than a specific protection, monitoring or control function. In contrast to the P.System Data 1 as discussed before, these can be changed over with the setting groups and can be configured via the operator panel of the device.
Page 43 Functions 2.1 General Topological Data for Transformers (optional) The statements under this margin heading refer to protected lines (cables or overhead lines) if a power trans- former is situated within the protected zone, i.e. to models with transformer option and if address 143 TRANSFORMER has been set to YES (see Section 2.1.1.2).
Page 44 Functions 2.1 General Example: Transformer Yy6d5 For the Y end set: VECTOR GROUP I = 0, For the y end set: VECTOR GROUP I = 6, For the d end set: VECTOR GROUP I = 5. If a different winding is selected as reference winding, e.g. the d winding, this has to be considered accordingly: For the Y end set: VECTOR GROUP I = 7 (12 - 5), For the y end set: VECTOR GROUP I = 6, For the d end set: VECTOR GROUP I = 0 (5 - 5 = 0 = reference side).
Page 45 Functions 2.1 General Before each line energization detection, the breaker must be recognized as open for the settable time1133 T DELAY SOTF. Address 1135 Reset Trip CMD determines under which conditions a trip command is reset. If CurrentOpenPole is set, the trip command is reset as soon as the current disappears. It is important that the value set in address 1130 PoleOpenCurrent (see above) is undershot.
Page 46 Functions 2.1 General For commands via the integrated control (on site, DIGSI, serial interface) address 1152 Man.Clos. Imp. determines whether a close command via the integrated control regarding the MANUAL CLOSE handling for the protection functions (like instantaneous re-opening when switching onto a fault) is to act like a MANUAL CLOSE command via binary input.
Page 47: Settings
Functions 2.1 General Figure 2-3 Multiple fault on a double-circuit line next to a generator Address 1156 Trip2phFlt determines that the short-circuit protection functions perform only a single-pole trip in case of isolated two-phase faults (clear of ground), provided that single-pole tripping is possible and per- mitted.
Page 48: Information List
Functions 2.1 General Addr. Parameter Setting Options Default Setting Comments 1130A PoleOpenCurrent 0.05 .. 1.00 A 0.10 A Pole Open Current Threshold 0.25 .. 5.00 A 0.50 A 1131A PoleOpenVoltage 2 .. 70 V 30 V Pole Open Voltage Threshold 1132A SI Time all Cl.
Page 49 Functions 2.1 General Information Type of In- Comments formation >Blk Man. Close >Block manual close cmd. from external >FAIL:Feeder VT >Failure: Feeder VT (MCB tripped) >CB1 Pole L1 >CB1 Pole L1 (for AR,CB-Test) >CB1 Pole L2 >CB1 Pole L2 (for AR,CB-Test) >CB1 Pole L3 >CB1 Pole L3 (for AR,CB-Test) >CB1 Ready...
Page 50: Protection Data Interfaces And Protection Data Topology
Functions 2.2 Protection Data Interfaces and Protection Data Topology Protection Data Interfaces and Protection Data Topology Devices protecting an object protected by current transformer sets, must exchange data of the protected object. This applies not only to the measured quantities relevant to the actual differential protection, but also to all data which are to be available at the ends.
Page 51 Functions 2.2 Protection Data Interfaces and Protection Data Topology Note If the protection data interfaces of the devices are connected via a communication network, a circuit switched network, e.g. a SDH and/or PDH-network is required. Packet switched networks, e.g. IP-Networks, are not suit- able for protection data interface communication.
Page 52 Functions 2.2 Protection Data Interfaces and Protection Data Topology Monitoring the communication The communication is permanently monitored by the devices. Single faulty data telegrams are not a direct risk if they occur only occasionally. They are recognized and counted in the device which detects the disturbance and can be read out per unit of time as statistical informa- tion (Annunciation →...
Page 53: Operating Modes Of The Differential Protection
Functions 2.2 Protection Data Interfaces and Protection Data Topology 2.2.2 Operating Modes of the Differential Protection 2.2.2.1 Mode: Log Out Device General The „Log out device“ mode (also: Log out device functionally) is used to log the device out of the line protection system with the local circuit breaker being switched off.
Page 54 Functions 2.2 Protection Data Interfaces and Protection Data Topology If a command (from DIGSI or keypad) or a binary input requests the change of the current mode, this request is checked. If „Logout“ ON or „>Logout ON“ is requested, the following is checked: •...
Page 55: Differential Protection Test Mode
Functions 2.2 Protection Data Interfaces and Protection Data Topology 2.2.2.2 Differential Protection Test Mode General If differential protection test mode (test mode in the following) is activated, the differential protection is blocked in the entire system. Depending on the configuration, the overcurrent protection becomes effective as an emer- gency function.
Page 56 Functions 2.2 Protection Data Interfaces and Protection Data Topology Figure 2-9 Principle for external button wiring for controlling the differential protection test mode Button „Deactivating differential protection test mode“ Button „Activating differential protection test mode“ Figure 2-10 Principle for external switch wiring for controlling the differential protection test mode Switch „Activating/deactivating differential protection test mode“...
Page 57: Differential Protection Commissioning Mode
Functions 2.2 Protection Data Interfaces and Protection Data Topology 2.2.2.3 Differential Protection Commissioning Mode General In differential protection commissioning mode (commissioning mode in the following), the differential protection does not generate TRIP commands. The commissioning mode is intended to support the commissioning of the differential protection.
Page 58 Functions 2.2 Protection Data Interfaces and Protection Data Topology Figure 2-12 External button wiring for controlling the differential protection commissioning mode Button „Deactivating differential protection commissioning mode“ Button „Activating differential protection commissioning mode“ Figure 2-13 External switch wiring for controlling the differential protection commissioning mode Switch „Activating/deactivating differential protection commissioning mode“...
Page 59: Protection Data Interfaces
Functions 2.2 Protection Data Interfaces and Protection Data Topology 2.2.3 Protection Data Interfaces 2.2.3.1 Setting Notes General Information about Interfaces The protection data interfaces connect the devices with the communication media. The communication is per- manently monitored by the devices. Address 4509 T-DATA DISTURB defines after which delay time the user is informed about a faulty or missing telegram.
Page 60 Functions 2.2 Protection Data Interfaces and Protection Data Topology If transmission time jumps exceeding the parameterized value of the maximum transmission time difference (address 4506) occur in the communication networks, a proper function of the differential protection for high- current faults outside the zone to be protected is not guaranteed. The device is able to record transmission time jumps.
Page 61: Settings
Functions 2.2 Protection Data Interfaces and Protection Data Topology PI1 SYNCMODE = TEL or GPS means that the differential protection will be enabled immediately once the connection has been re-established (data telegrams are received). The differential protection works with the value paramterized at address 4506 PROT 1 UNSYM.
Page 62: Information List
Functions 2.2 Protection Data Interfaces and Protection Data Topology Addr. Parameter Setting Options Default Setting Comments 4509 T-DATA DISTURB 0.05 .. 2.00 sec 0.10 sec Time delay for data disturbance alarm 4510 T-DATAFAIL 0.0 .. 60.0 sec 6.0 sec Time del for transmission failure alarm 4511 PI1 SYNCMODE...
Page 63: Differential Protection Topology
Functions 2.2 Protection Data Interfaces and Protection Data Topology 2.2.4 Differential Protection Topology 2.2.4.1 Setting Notes Protection data topology First of all, define your protection data communication topology: Number the devices consecutively. This num- bering is a serial device index that serves for your own overview. It starts for each distance differential protection system (i.e.
Page 64: Settings
Functions 2.2 Protection Data Interfaces and Protection Data Topology The device then issues one of the following error messages • „DT inconsistent“ (Device Table contains two or more identical device ident numbers) • „DT unequal“ (Different settings of parameters 4701 to 4702) •...
Page 65: Differential Protection
Functions 2.3 Differential Protection Differential Protection The differential protection is the main function of the device. It is based on current comparison. For this, one device must be installed at each end of the zone to be protected. The devices exchange their measured quan- tities via communications links and compare the received currents with their own.
Page 66 Functions 2.3 Differential Protection protection devices is called protection data interface. As a result, the currents can be added up and processed in each device. Figure 2-16 Differential protection for a line with two ends You will find detailed information on the topology of device communication in Section 2.2.1. Restraint The precondition for the basic principle of the differential protection is that the total sum of all currents flowing into the protected object is zero in healthy operation.
Page 67 Functions 2.3 Differential Protection Figure 2-17 Approximation of the current transformer errors Further influences Further measuring errors which may arise in the actual device by hardware tolerances, calculation tolerances, deviations in time or due to the „quality“ of the measured quantities such as harmonics and deviations in fre- quency are also estimated by the device and automatically increase the local self-restraining quantity.
Page 68 Functions 2.3 Differential Protection Figure 2-18 shows a simplified logic diagram. The condition for the inrush restraint is examined in each device in which this function has been activated. The blocking condition is also effective at the other device. Figure 2-18 Logic diagram of the inrush restraint for one phase Since the inrush restraint operates individually for each phase, the protection is fully operative when the trans- former is switched onto a single-phase fault, where an inrush current may be flowing through one of the undis-...
Page 69 Functions 2.3 Differential Protection The restraining current counteracts the differential current. It is the total of the maximum measuring errors at the ends of the protected object and is calculated adaptively from the current measured quantities and power system parameters that were set. For this purpose, the maximum error of the current transformers within the nominal range and/or the short-circuit current range is multiplied with the current flowing through each end of the protected object.
Page 70 Functions 2.3 Differential Protection The charges of both ends of the protected object are added in the same way as done with the current phasors of the differential protection. Thus the total of the charges is available at both ends of the protected zone. Immediately after a fault has occurred in the protected zone, a charge difference emerges.
Page 71 Functions 2.3 Differential Protection Pickup of the differential protection Figure 2-21 illustrates the logic diagram of the differential protection. The phase-selective indications of the stages are summarised to form general phase indications. Additionally, the device indicates which stage has picked up. Figure 2-21 Pickup logic for the differential protection function As soon as the differential protection function registers a fault within its tripping zone, the signal „Diff.
Page 72: Setting Notes
Functions 2.3 Differential Protection Tripping logic of the differential protection The tripping logic of the differential protection combines all decisions of the differential stages and forms output signals which are also influenced by the central tripping logic of the entire device (Figure 2-22). The pickup signals that identify the concerned stages of the differential protection stages can be delayed via the time stage T-DELAY I-DIFF>.
Page 73 Functions 2.3 Differential Protection Pickup Value of the Differential Current The current sensitivity is set with address 1210 I-DIFF>. It is determined by the entire current flowing into a protected zone in case of a short-circuit. This is the total fault current regardless of how it is distributed between the ends of the protected object.
Page 74 Functions 2.3 Differential Protection Pickup value during switch-on When switching on long, unloaded cables, overhead lines and arc-compensated lines, pronounced higher-fre- quency transient reactions may take place. These peaks are considerably damped by means of a digital filter in the differential protection. A pickup value I-DIF>SWITCH ON (address 1213) can be set to reliably prevent single-sided pickup of the protection.
Page 75: Settings
Functions 2.3 Differential Protection Pickup value when switching on the charge comparison If bushing transformers are used for a transformer in the protected line section, stray fluxes through the bushing transformers may occur when reclosing after an external fault. These stray fluxes may cause a distortion of the secondary current and an overfunction of the charge comparison.
Page 76: Information List
Functions 2.3 Differential Protection Addr. Parameter Setting Options Default Setting Comments 1233 I-DIFF>> 0.8 .. 100.0 A; ∞ 1.2 A I-DIFF>>: Pickup value 4.0 .. 500.0 A; ∞ 6.0 A 1235 I-DIF>>SWITCHON 0.8 .. 100.0 A; ∞ 1.2 A I-DIFF>>: Value under switch on cond.
Page 77 Functions 2.3 Differential Protection Information Type of In- Comments formation 3181 Diff Flt. L12E Diff: Fault detection L12E 3182 Diff Flt. 1p.L3 Diff: Fault detection L3 (only) 3183 Diff Flt. L3E Diff: Fault detection L3E 3184 Diff Flt. L31 Diff: Fault detection L31 3185 Diff Flt.
Page 78: Breaker Intertrip And Remote Tripping
Functions 2.4 Breaker Intertrip and Remote Tripping Breaker Intertrip and Remote Tripping 7SD610 allows to transmit a tripping command created by the local differential protection to the other end of the protected object (intertripping). Likewise, any desired command of another internal protection function or of an external protection, monitoring or control equipment can be transmitted for remote tripping.
Page 79 Functions 2.4 Breaker Intertrip and Remote Tripping Receiving circuit On the receiving end the signal can lead to a trip. Alternatively it can also cause an alarm only. Figure 2-24 shows the logic diagram. If the received signal is to cause the trip, it will be forwarded to the tripping logic.
Page 80: Setting Notes
Functions 2.4 Breaker Intertrip and Remote Tripping 2.4.2 Setting Notes General The intertrip function for tripping caused by the differential protection can be activated (YES) or deactivated (NO) with address 1301 I-TRIP SEND. Since the differential protection devices theoretically operate with the same measured values at all ends of the protected object, a tripping in the event of an internal fault normally is also carried out at all ends, regardless of the infeed conditions at the ends.
Page 81: Information List
Functions 2.4 Breaker Intertrip and Remote Tripping 2.4.4 Information List Information Type of In- Comments formation 3501 >Intertrip L1 I.Trip: >Intertrip L1 signal input 3502 >Intertrip L2 I.Trip: >Intertrip L2 signal input 3503 >Intertrip L3 I.Trip: >Intertrip L3 signal input 3504 >Intertrip 3pol I.Trip: >Intertrip 3 pole signal input...
Page 82: Restricted Earth Fault Protection (Optional)
Functions 2.5 Restricted Earth Fault Protection (optional) Restricted Earth Fault Protection (optional) The restricted earth fault protection detects earth faults in power transformers, the starpoint of which is earthed. It is also suitable when a starpoint former is installed within a protected zone of a non-earthed power transform- er.
Page 83: Functional Description
Functions 2.5 Restricted Earth Fault Protection (optional) 2.5.2 Functional Description Measuring principle During normal operation, no starpoint current I flows through the starpoint lead. The sum of the phase cur- rents 3I approximates zero. When an earth fault occurs in the protected zone, a starpoint current I will flow;...
Page 84 Functions 2.5 Restricted Earth Fault Protection (optional) Evaluation of Measurement Quantities The earth fault differential protection compares the fundamental component of the current flowing in the star- point connection, which is designated as 3I ' in the following, with the fundamental component of the sum of the phase currents designated in the following as 3I ”.
Page 85 Functions 2.5 Restricted Earth Fault Protection (optional) Through current on an external earth fault: " is in phase opposition with 3I ', and of equal magnitude, i.e. 3I " = –3I = |3I = |3I ' + 3I '| – |3I ' –...
Page 86 Functions 2.5 Restricted Earth Fault Protection (optional) It was assumed in the above examples that the currents 3I " and 3I ' are in counter-phase for external earth faults which is, is in fact, true for the primary measured quantities. Current transformer saturation may, however, feign a phase displacement between the starpoint current and the sum of the phase currents which reduces the restaint quantity.
Page 87 Functions 2.5 Restricted Earth Fault Protection (optional) Figure 2-32 Tripping characteristic of the restricted earth fault protection in dependence on the phase dis- placement between 3I ” and 3I ' at 3I ” = 3I ' (180 = external fault) It is also possible to increase the tripping value proportional to the current sum.
Page 88: Setting Notes
Functions 2.5 Restricted Earth Fault Protection (optional) Figure 2-34 Logic diagram of the restricted earth fault protection (simplified) 2.5.3 Setting Notes General The restricted earth fault protection can only operate if this function has been set during configuration of the functional scope (Section 2.1.1.2) under address 141 REF PROT.
Page 89: Settings
Functions 2.5 Restricted Earth Fault Protection (optional) The value message 5826 „REF D:“ is the tripping value stabilized via the tripping characteristic. The reported values „REF S:“ and „REF D:“ refer to the time when the output message 5816 „REF T start“ is report- ed, i.e.
Page 90: Direct Local Trip
Functions 2.6 Direct Local Trip Direct Local Trip Any signal from an external protection or monitoring device can be coupled into the signal processing of the 7SD610 by means of a binary input. This signal can be delayed, alarmed and routed to one or several output relays.
Page 91: Settings
Functions 2.6 Direct Local Trip 2.6.3 Settings Addr. Parameter Setting Options Default Setting Comments 2201 FCT Direct Trip Direct Transfer Trip (DTT) 2202 Trip Time DELAY 0.00 .. 30.00 sec; ∞ 0.01 sec Trip Time Delay 2.6.4 Information List Information Type of In- Comments formation...
Page 92: Transmission Of Binary Commands And Messages
Functions 2.7 Transmission of Binary Commands and Messages Transmission of Binary Commands and Messages 2.7.1 Function Description Provided that the devices work with protection data transmission via digital communication links at the ends, the transmission of up to 28 items of binary information of any type from one device to the other is possible in the 7SD610.
Page 93: Information List
Functions 2.7 Transmission of Binary Commands and Messages 2.7.2 Information List Information Type of In- Comments formation 3541 >Remote CMD 1 >Remote Command 1 signal input 3542 >Remote CMD 2 >Remote Command 2 signal input 3543 >Remote CMD 3 >Remote Command 3 signal input 3544 >Remote CMD 4 >Remote Command 4 signal input...
Page 94 Functions 2.7 Transmission of Binary Commands and Messages Information Type of In- Comments formation 3585 Rem.Sig13recv Remote signal 13 received 3586 Rem.Sig14recv Remote signal 14 received 3587 Rem.Sig15recv Remote signal 15 received 3588 Rem.Sig16recv Remote signal 16 received 3589 Rem.Sig17recv Remote signal 17 received 3590 Rem.Sig18recv...
Page 95: Instantaneous High-Current Switch-Onto-Fault Protection (Sotf)
Functions 2.8 Instantaneous High-Current Switch-onto-Fault Protection (SOTF) Instantaneous High-Current Switch-onto-Fault Protection (SOTF) 2.8.1 Function Description General The high-speed overcurrent protection function is provided to disconnect immediately and without delay feeders that are switched onto a high-current fault. It serves, e.g. as a rapid protection for connecting a feeder with closed grounding disconnector.
Page 96 Functions 2.8 Instantaneous High-Current Switch-onto-Fault Protection (SOTF) Figure 2-36 Activation of the I>>> stage I>>>> stage The I>>>> stage trips regardless of the position of the circuit breakers. Here, the currents are also numerically filtered and the peak value of the currents is measured from the double setting value onwards. Figure 2-37 shows the logic diagram in the upper part.
Page 97: Setting Notes
Functions 2.8 Instantaneous High-Current Switch-onto-Fault Protection (SOTF) Figure 2-37 Logic diagram of the high current switch on to fault protection 2.8.2 Setting Notes General A precondition for using the fast tripping function is that the configuration of the device functions (Section 2.1.1) has been set at address 124 HS/SOTF-O/C = Enabled.
Page 98 Functions 2.8 Instantaneous High-Current Switch-onto-Fault Protection (SOTF) I>>>> Stage The I>>>> stage (address 2405) works regardless of the circuit breaker position. Since it trips extremely fast it must be set high enough not to pickup on a load current flowing through the protected object. This means that it can be used only if the protected object allows current grading, as is the case with transformers, series reactors or long lines with small source impedance.
Page 99: Settings
Functions 2.8 Instantaneous High-Current Switch-onto-Fault Protection (SOTF) 2.8.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Additional Settings. The table indicates region-specific presettings. Column C (configuration) indicates the corresponding second- ary nominal current of the current transformer. Addr.
Page 100: Backup Time Overcurrent Protection
Functions 2.9 Backup Time Overcurrent Protection Backup Time Overcurrent Protection The 7SD610 features a time overcurrent protection function which can be used as either a back-up or an emer- gency overcurrent protection. All stages may be configured independently of each other and combined accord- ing to the user's requirements.
Page 101 Functions 2.9 Backup Time Overcurrent Protection The current phase earth voltage is used • for single-pole or three-pole faults, • if phase-earth voltage > 4V • not within the first 50 ms after short-circuit, as the current voltage is then disturbed by transients. The saved phase-earth voltage is used •...
Page 102 Functions 2.9 Backup Time Overcurrent Protection Directional Characteristic The directional characteristic of the directional overcurrent stages is preset. From the voltage and current vectors used for direction determination, the angle difference ϕ(U) - ϕ(I) is calculated via the impedance Z = U/I and the direction determined based on the directional characteristic displayed. Figure 2-38 Directional characteristic of the time overcurrent protection Definite Time High-set Current Stage I>>...
Page 103 Functions 2.9 Backup Time Overcurrent Protection Figure 2-39 Logic diagram of the I>> stage Output indications associated with the pickup signals are listed in Table 2-3 Output indications associated with the trip signals are listed in Table 2-4 Definite time overcurrent stage I> The logic of the overcurrent stages I>...
Page 104 Functions 2.9 Backup Time Overcurrent Protection Additional Stage I>>> An additional overcurrent stage I>>> has an extra enable input (Figure 2-40) It is therefore also suitable e.g. as an emergency stage if the remaining stages are used as backup stages. The enable input „>I-STUB ENABLE“...
Page 105 Functions 2.9 Backup Time Overcurrent Protection Directional, Definite Time Overcurrent Stage I> The directional overcurrent stages follow the same principle as the non-directional stages. However, triggering is not dependent on the result of the direction determination. Direction determination occurs via the measuring values and the respective directional characteristics.
Page 106 Functions 2.9 Backup Time Overcurrent Protection Figure 2-41 Logic diagram of the I> stage Output indications associated with the pickup signals are listed in Table 2-3 Output indications associated with the trip signals are listed in Table 2-4 The indications „O/C L2 forward“, „O/C L3 forward“, „O/C L2 reverse“, „O/C L3 reverse“ have not been represented in the Figure, however, they are reported if necessary.
Page 107 Functions 2.9 Backup Time Overcurrent Protection Inverse time overcurrent stage I The logic of the inverse overcurrent stage also operates chiefly in the same way as the remaining stages. How- ever, the time delay is calculated here based on the type of the set characteristic, the intensity of the current and a time multiplier (following figure).
Page 108 Functions 2.9 Backup Time Overcurrent Protection Figure 2-42 Logic diagram of the I stage (inverse time overcurrent protection) - example of IEC curve Output indications associated with the pickup signals are listed in Table 2-3 Output indications associated with the trip signals are listed in Table 2-4 SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 109 Functions 2.9 Backup Time Overcurrent Protection Directional inverse time overcurrent stage I The logic of the inverse overcurrent stage also operates chiefly in the same way as that of the non-directional stage. However, pickup is dependent on the result of the direction determination. Direction determination occurs via the measuring values and the respective directional characteristics.
Page 110 Functions 2.9 Backup Time Overcurrent Protection Figure 2-43 Logic diagram of the I stage (directional, inverse time overcurrent protection), for example IEC character- istics Output indications associated with the pickup signals are listed in Table 2-3 Output indications associated with the trip signals are listed in Table 2-4 The indications „O/C L2 forward“, „O/C L3 forward“, „O/C L2 reverse“, „O/C L3 reverse“...
Page 111 Functions 2.9 Backup Time Overcurrent Protection Instantaneous tripping before automatic reclosure If automatic reclosure is to be carried out, quick fault clearance before reclosure is usually desirable. A release signal from an external automatic reclosure device can be injected via binary input „>O/C InstTRIP“. The interconnection of the internal automatic reclose function is performed via an additional CFC logic, which typi- cally connects the output signal 2889 „AR 1.CycZoneRel“...
Page 112 Functions 2.9 Backup Time Overcurrent Protection Internal indication Display Output indication I>>> PU L1 2-40 I>>> PU L2 2-40 „I-STUB PICKUP“ 7201 I>>> PU L3 2-40 I>>> PU E 2-40 I> ger PU L1 2-41 I> ger PU L2 2-41 „O/C PICK.
Page 113 Functions 2.9 Backup Time Overcurrent Protection Table 2-4 Trip signals of the single phases Internal indication Display Output indication I>> TRIP L1 2-39 I> TRIP L1 I>>> TRIP L1 2-40 7212 or „O/C TRIP 1p.L1“ or „O/C TRIP L123“ I>TRIP Dir L1 2-41 7215 Ip TRIP L1...
Page 114: Setting Notes
Functions 2.9 Backup Time Overcurrent Protection 2.9.3 Setting Notes General During configuration of the scope of functions for the device (address 126) the available characteristics were determined. Depending on the configuration and the order variant, only those parameters that apply to the se- lected characteristics are accessible in the procedures described below.
Page 115 Functions 2.9 Backup Time Overcurrent Protection High Current Stages I >>, 3I >> The I>> stages Iph>> (address2610) and 3I0>> PICKUP (address2612) together with the I> stages or the stages form a two-stage characteristic curve. Of course, all three stages can be combined as well. If one stage is not required, the pickup value has to be set to ∞.
Page 116 Functions 2.9 Backup Time Overcurrent Protection Note: the calculation was carried out with absolute values, which is sufficiently precise for overhead lines. If the angles of the source impedance and the line impedance vary considerably, a complex calculation must be carried out.
Page 117 Functions 2.9 Backup Time Overcurrent Protection The settable delay time T Iph> (address 2621) or T Iph> Dir. (address 2682), results from the grading coordination chart defined for the network. If implemented as emergency overcurrent protection, shorter delay times are advisable (one grading time step above instantaneous tripping).. The time T 3I0>...
Page 118 Functions 2.9 Backup Time Overcurrent Protection The set time multiplier T Ip Time Dial (address 2642) or T Ip Dir. (address 2690), results from the grading coordination chart defined for the network. For the use as emergency overcurrent protection, shorter delay times make sense (one grading time step above instantaneous tripping), since this function is to work only in case of an interruption of the data communication for the differential protection.
Page 119 Functions 2.9 Backup Time Overcurrent Protection The above example shows that the maximum expected operating current may directly be applied as setting here. Primary: Set value IP = 630 A, Secondary: Setting value IP = 5.25 A, i.e. (630 A/600 A) X 5 A. The set time multiplier Time Dial TD Ip (address 2643) or D Ip Dir.
Page 120: Settings
Functions 2.9 Backup Time Overcurrent Protection Accordingly, the earth current stage 3I0> STUB (address 2632) should pick up on the smallest earth current to be expected during an earth fault and the delay T 3I0 STUB (address 2633) should exceed the base time of the differential protection by one grading time.
Page 121 Functions 2.9 Backup Time Overcurrent Protection Addr. Parameter Setting Options Default Setting Comments 2624 I> Telep/BI Instantaneous trip via Tele- prot./BI 2625 I> SOTF Instantaneous trip after SwitchOnToFault 2630 Iph> STUB 0.05 .. 50.00 A; ∞ 1.50 A Iph> STUB Pickup 0.25 ..
Page 122 Functions 2.9 Backup Time Overcurrent Protection Addr. Parameter Setting Options Default Setting Comments 2681 Iph> Dir. 0.05 .. 50.00 A; ∞ 1.50 A Iph> directional Pickup 0.25 .. 250.00 A; ∞ 7.50 A 2682 T Iph> Dir. 0.00 .. 30.00 sec; ∞ 0.50 sec T Iph>...
Page 123: Information List
Functions 2.9 Backup Time Overcurrent Protection 2.9.5 Information List Information Type of In- Comments formation 7104 >BLOCK O/C I>> >BLOCK Backup OverCurrent I>> 7105 >BLOCK O/C I> >BLOCK Backup OverCurrent I> 7106 >BLOCK O/C Ip >BLOCK Backup OverCurrent Ip 7107 >BLOCK O/C Ie>>...
Page 124 Functions 2.9 Backup Time Overcurrent Protection Information Type of In- Comments formation 7212 O/C TRIP 1p.L1 Backup O/C TRIP - Only L1 7213 O/C TRIP 1p.L2 Backup O/C TRIP - Only L2 7214 O/C TRIP 1p.L3 Backup O/C TRIP - Only L3 7215 O/C TRIP L123 Backup O/C TRIP Phases L123...
Page 125: Automatic Reclosure Function (Optional)
Functions 2.10 Automatic Reclosure Function (optional) 2.10 Automatic Reclosure Function (optional) Experience shows that about 85% of the arc faults on overhead lines are extinguished automatically after being tripped by the protection. The line can therefore be re-energised. Reclosure is performed by an automatic reclose function (AR).
Page 126 Functions 2.10 Automatic Reclosure Function (optional) The integrated automatic reclosing function allows up to 8 reclosing attempts. The first four reclose cycles may operate with different parameters (action and dead times, 1-/3-pole). The parameters of the fourth cycle apply to the fifth cycle and onwards. Activation and deactivation The automatic reclosure function can be switched on and off by means of the parameter 3401 AUTO RECLOSE via the system interface (if available) and via binary inputs (if allocated).
Page 127 Functions 2.10 Automatic Reclosure Function (optional) Automatic reclosure function is not started if the circuit breaker has not been ready for at least one OPEN- CLOSE-OPEN–cycle at the instant of the first trip command. This can be achieved by setting parameters. For further information, please refer to „Interrogation of Circuit Breaker Ready State“.
Page 128 Functions 2.10 Automatic Reclosure Function (optional) Operating modes of the automatic reclosure function The dead times — these are the times from elimination of the fault (drop off of the trip command or signalling via auxiliary contacts) to the initiation of the automatic close command — may vary depending on the automatic reclosure function operating mode selected when determining the function scope and the resulting signals of the starting protection functions.
Page 129 Functions 2.10 Automatic Reclosure Function (optional) In the event of a single cycle reclosure this interrogation is usually sufficient. Since, for example, the air pres- sure or the spring tension for the circuit breaker mechanism drops after the trip, no further interrogation should take place.
Page 130 Functions 2.10 Automatic Reclosure Function (optional) If the fault is cleared (successful reclosure), the reclaim time expires and all functions return to their quiescent state. The fault is cleared. If the fault has not been eliminated (unsuccessful reclosure), the short-circuit protection initiates a final trip fol- lowing a protection stage active without reclosure.
Page 131 Functions 2.10 Automatic Reclosure Function (optional) (adjustable) reclaim time is started. If the reclosure is blocked during the dead time following a 1-pole trip, im- mediate 3-pole tripping can take place as an option (forced 3-pole trip). If the fault is cleared (successful reclosure), the reclaim time expires and all functions return to their quiescent state.
Page 132 Functions 2.10 Automatic Reclosure Function (optional) There are also various selectable possibilities for the response of the internal auto- reclose function to a de- tected evolving fault. • EV. FLT. MODE Stops AutoRecl: The reclosure is blocked as soon as a sequential fault is detected. The tripping by the sequential fault is always 3-pole.
Page 133 Functions 2.10 Automatic Reclosure Function (optional) Adaptive Dead Time (ADT) In all the previous alternatives it was assumed that defined and equal dead times were set at both line ends, if necessary for different fault types and/or reclose cycles. It is also possible to set the dead times (if necessary different for various fault types and/or reclose cycles) at one line end only and to configure the adaptive dead time at the other end.
Page 134 Functions 2.10 Automatic Reclosure Function (optional) CLOSE Command Transmission (Remote-CLOSE) With close command transmission via the digital connection path the dead times are only set at one line end. The other end is set to "Adaptive Dead Time (ADT)". The latter only react to the received close commands from the transmitting end.
Page 135 Functions 2.10 Automatic Reclosure Function (optional) Depending on the external reclosure device requirements, the three 1-pole indications (No. 512, 513, 514) can be combined to one „1-pole tripping“ output; No. 515 sends the „3-pole tripping“ signal to the external device. In case of exclusively 3-pole reclose cycles, the general pickup signal (No.
Page 136 Functions 2.10 Automatic Reclosure Function (optional) If the automatic reclosure function is controlled by the trip command, the following inputs and outputs are rec- ommended: The automatic reclosure function is started via the Binary inputs: 2711 „>AR Start“ General fault detection for the automatic reclosure circuit (only required for action time), 2712 „>Trip L1 AR“...
Page 137 Functions 2.10 Automatic Reclosure Function (optional) Figure 2-50 Connection example with external protection device for 1-/3-pole reclosure; AR control mode = with TRIP Figure 2-51 Connection example with external protection device for 3-pole reclosure; AR control mode = with TRIP But if the internal automatic reclose function is controlled by the pickup (only possible for 3-pole tripping: 110 Trip mode = 3pole only), the phase-selective pickup signals of the external protection must be connected if distinction shall be made between different types of fault.
Page 138 Functions 2.10 Automatic Reclosure Function (optional) Figure 2-52 Connection example with external protection device for fault detection dependent dead time — dead time control by pickup signals of the protection device; AR control mode = with PICKUP 2 Protection Relays with 2 Automatic Reclosure Circuits If redundant protection is provided for a line and each protection operates with its own automatic reclosure func- tion, a certain signal exchange between the two combinations is necessary.
Page 139 Functions 2.10 Automatic Reclosure Function (optional) Figure 2-53 Connection example for 2 protection devices with 2 automatic reclosure functions Binary inputs Signal output Command for all protection functions operating with AR. SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 140 Functions 2.10 Automatic Reclosure Function (optional) Figure 2-54 Connection example for 2 protection devices with internal automatic reclosure function and minimum cross connection Figure 2-55 Setting of the software filter time SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 141: Setting Notes
Functions 2.10 Automatic Reclosure Function (optional) 2.10.2 Setting Notes General If no reclosure is required on the feeder to which the 7SD610 differential protection is applied (e.g. for cables, transformers) the auto reclose function must be removed during configuration of the device (address 133, see Section 2.1.1.2).
Page 142 Functions 2.10 Automatic Reclosure Function (optional) The blocking duration following manual-close detection T-BLOCK MC (address 3404) must ensure the circuit breaker to open and close reliably (0.5 s to 1 s). If a fault is detected by a protection function within this time after closing of the circuit breaker was detected, no reclosure takes place and a final 3-pole trip command is issued.
Page 143 Functions 2.10 Automatic Reclosure Function (optional) Configuration of auto-reclosure This configuration concerns the interaction between the protection and supplementary functions of the device and the automatic reclosure function. Here, you can determine which functions of the device should start the automatic reclosure and which not.
Page 144 Functions 2.10 Automatic Reclosure Function (optional) The adaptive dead time may be voltage-controlled or Remote–CLOSE–controlled. Both are possible at the same time. In the first case, reclosure takes place as soon as the returning voltage, after reclosure at the remote end, is detected.
Page 145 Functions 2.10 Automatic Reclosure Function (optional) 1st Reclose Cycle If working on a line with adaptive dead time, no further parameters are needed for the individual reclose cycles in this case. All the following parameters assigned to the individual cycles are then superfluous and inaccessi- ble.
Page 146 Functions 2.10 Automatic Reclosure Function (optional) If, when setting the reaction to sequential faults (see above at „General“), you have set address 3407 EV. FLT. MODE starts 3p AR, you can set a separate dead time for the 3-pole dead time after clearance of the sequential fault 1.AR: Tdead EV.
Page 147 Functions 2.10 Automatic Reclosure Function (optional) For the 4th cycle: 3483 4.AR: START Start in 4th cycle generally allowed 3484 4.AR: T-ACTION Action time for the 4th cycle 3486 4.AR Tdead 1Flt Dead time after 1-phase pickup 3487 4.AR Tdead 2Flt Dead time after 2-phase pickup 3488 4.AR Tdead 3Flt Dead time after 3-phase pickup...
Page 148 Functions 2.10 Automatic Reclosure Function (optional) Notes on the Information Overview The most important information about automatic reclosure is briefly explained insofar as it was not mentioned in the following lists or described in detail in the preceding text. „>BLK 1.AR-cycle“ (No. 2742) to „>BLK 4.-n. AR“ (No. 2745) The respective auto-reclose cycle is blocked.
Page 149: Settings
Functions 2.10 Automatic Reclosure Function (optional) 2.10.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Additional Settings. Addr. Parameter Setting Options Default Setting Comments 3401 AUTO RECLOSE Auto-Reclose Function 3402 CB? 1.TRIP CB ready interrogation at 1st trip 3403 T-RECLAIM 0.50 ..
Page 150 Functions 2.10 Automatic Reclosure Function (optional) Addr. Parameter Setting Options Default Setting Comments 3438 T U-stable 0.10 .. 30.00 sec 0.10 sec Supervision time for dead/live voltage 3440 U-live> 30 .. 90 V 48 V Voltage threshold for live line or 3441 U-dead<...
Page 151: Information List
Functions 2.10 Automatic Reclosure Function (optional) Addr. Parameter Setting Options Default Setting Comments 3481 3.AR: CB? CLOSE CB ready interrogation before re- closing 3482 3.AR SynRequest Request for synchro-check after 3pole AR 3483 4.AR: START AR start allowed in this cycle 3484 4.AR: T-ACTION 0.01 ..
Page 152 Functions 2.10 Automatic Reclosure Function (optional) Information Type of In- Comments formation 2747 >Pickup L1 AR >AR: External pickup L1 for AR start 2748 >Pickup L2 AR >AR: External pickup L2 for AR start 2749 >Pickup L3 AR >AR: External pickup L3 for AR start 2750 >Pickup 1ph AR >AR: External pickup 1phase for AR start...
Page 153: Undervoltage And Overvoltage Protection (Optional)
Functions 2.11 Undervoltage and Overvoltage Protection (optional) 2.11 Undervoltage and Overvoltage Protection (optional) Voltage protection has the function of protecting electrical equipment against undervoltage and overvoltage. Both operational states are unfavourable as overvoltage may cause, for example, insulation problems or und- ervoltage may cause stability problems.
Page 154 Functions 2.11 Undervoltage and Overvoltage Protection (optional) Figure 2-56 Logic diagram of the overvoltage protection for phase voltage Phase-to-phase overvoltage The phase-to-phase overvoltage protection operates just like the phase-to-earth protection except that it detects phase-to-phase voltages. Accordingly, phase-to-phase voltages which have exceeded one of the stage thresholds Uph-ph>...
Page 155 Functions 2.11 Undervoltage and Overvoltage Protection (optional) Overvoltage positive sequence system U The device calculates the positive sequence system according to its defining equation ·(U + a·U ·U j120° where a = e The resulting positive sequence voltage is fed to the two threshold stages U1> (address 3732) and U1>> (ad- dress 3734) (see Figure 2-57).
Page 156 Functions 2.11 Undervoltage and Overvoltage Protection (optional) Overvoltage protection U with configurable compounding The overvoltage protection for the positive sequence system may optionally operate with compounding. The compounding calculates the positive sequence system of the voltage at the remote line end. This option is thus particularly well suited for detecting a steady-state voltage increase caused by long transmission lines operat- ing at weak load or no load due to the capacitance per unit length (Ferranti effect).
Page 157 Functions 2.11 Undervoltage and Overvoltage Protection (optional) Overvoltage negative sequence system U The device calculates the negative sequence system voltages according to its defining equation: ·(U ·U + a·U j120° where a = e The resulting negative sequence voltage is fed to the two threshold stages U2> (address 3742) and U2>> (ad- dress 3744).
Page 158 Functions 2.11 Undervoltage and Overvoltage Protection (optional) Overvoltage zero-sequence system 3U Figure 2-60 depicts the logic diagram of the zero-sequence voltage stage. The fundamental component is nu- merically filtered from the measuring voltage so that the harmonics or transient voltage peaks remain largely eliminated.
Page 159 Functions 2.11 Undervoltage and Overvoltage Protection (optional) Figure 2-60 Logic diagram of the overvoltage protection for zero sequence voltage Freely selectable single-phase voltage As the zero-sequence voltage stages operate separately and independently of the other protection overvoltage functions, they can be used for any other single-phase voltage. Therefore the fourth voltage input U of the device must be assigned accordingly (also see Section 2.1.2, „Voltage Transformer Connection“).
Page 160: Undervoltage Protection
Functions 2.11 Undervoltage and Overvoltage Protection (optional) 2.11.2 Undervoltage Protection Undervoltage Phase-to-earth Figure 2-61 depicts the logic diagram of the phase voltage stages. The fundamental component is numerically filtered from each of the three measuring voltages so that harmonics or transient voltage peaks are largely elim- inated.
Page 161 Functions 2.11 Undervoltage and Overvoltage Protection (optional) Figure 2-61 Logic diagram of the undervoltage protection for phase voltages SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 162 Functions 2.11 Undervoltage and Overvoltage Protection (optional) Phase-to-phase undervoltage Basically, the phase-to-phase undervoltage protection operates like the phase-to-earth protection except that it detects phase-to-phase voltages. Accordingly, both phases are indicated during pickup of an undervoltage stage the value fell below one of the stage thresholds Uph-ph< (address 3762) or Uph-ph<< (address 3764). Beyond this, Figure 2-61 applies in principle.
Page 163: Setting Notes
Functions 2.11 Undervoltage and Overvoltage Protection (optional) Figure 2-62 Logic diagram of the undervoltage protection for positive sequence voltage system During single-pole dead time for automatic reclosure, the stages of positive sequence undervoltage protection are automatically blocked. In this way, the stages do not respond to the reduced positive sequence voltage caused by the disconnected phase in case the voltage transformers are located on the outgoing side.
Page 164 Functions 2.11 Undervoltage and Overvoltage Protection (optional) Note For overvoltage protection it is particularly important to observe the setting notes: NEVER set an overvoltage stage (U ) lower than an undervoltage stage. This would put the device immediately into a state of permanent pickup which cannot be reset by any measured value operation.
Page 165 Functions 2.11 Undervoltage and Overvoltage Protection (optional) In addition, the compounding feature needs the line data which have been set in the General Protection Data (Power System Data 2) (Section 2.1.4.1): Address 1111 x', address 1112 c' and address 1113 Line Length, as well as address 1105 Line Angle.
Page 166 Functions 2.11 Undervoltage and Overvoltage Protection (optional) When setting the voltage values please observe the following: • If the U voltage of the set of voltage transformers is connected to U and if this was already set in the Power System Data 1 (refer also to Section 2.1.2.1 under margin heading „Voltage Connection“, address 210 U4 transformer = Udelta transf.), the device multiplies this voltage by the matching ratio Uph / Udelta (address 211), usually with 1.73.
Page 167: Settings
Functions 2.11 Undervoltage and Overvoltage Protection (optional) If the voltage transformers are located on the line side, the measuring voltages will be missing when the line is disconnected. To avoid that the undervoltage levels in these cases are or remain picked up, the current criterion CURR.SUP.Uphph<...
Page 168 Functions 2.11 Undervoltage and Overvoltage Protection (optional) Addr. Parameter Setting Options Default Setting Comments 3715 T Uph-ph>> 0.00 .. 100.00 sec; ∞ 1.00 sec T Uph-ph>> Time Delay 3719A Uphph>(>) RESET 0.30 .. 0.99 0.98 Uph-ph>(>) Reset ratio 3721 3U0>(>) (or Ux) Operating mode 3U0 (or Ux) over- Alarm Only voltage...
Page 169: Information List
Functions 2.11 Undervoltage and Overvoltage Protection (optional) Addr. Parameter Setting Options Default Setting Comments 3758 CURR.SUP. Uphe< Current supervision (Uph-e) 3759A Uph-e<(<) RESET 1.01 .. 1.20 1.05 Uph-e<(<) Reset ratio 3761 Uph-ph<(<) Operating mode Uph-ph under- Alarm Only voltage prot. U<Alarm U<<Trip 3762 Uph-ph<...
Page 170 Functions 2.11 Undervoltage and Overvoltage Protection (optional) Information Type of In- Comments formation 10220 3U0>(>) BLK 3U0>(>) Overvolt. is BLOCKED 10221 U1>(>) OFF U1>(>) Overvolt. is switched OFF 10222 U1>(>) BLK U1>(>) Overvolt. is BLOCKED 10223 U2>(>) OFF U2>(>) Overvolt. is switched OFF 10224 U2>(>) BLK U2>(>) Overvolt.
Page 171 Functions 2.11 Undervoltage and Overvoltage Protection (optional) Information Type of In- Comments formation 10281 U1>> Pickup U1>> Pickup 10282 U1> TimeOut U1> TimeOut 10283 U1>> TimeOut U1>> TimeOut 10284 U1>(>) TRIP U1>(>) TRIP command 10290 U2> Pickup U2> Pickup 10291 U2>>...
Page 172: Frequency Protection (Optional)
Functions 2.12 Frequency Protection (optional) 2.12 Frequency Protection (optional) The frequency protection function detects overfrequencies or underfrequencies in the system or in electrical machines. If the frequency is outside the permissible range, appropriate actions are initiated such as load shed- ding or separating the generator from the system.
Page 173 Functions 2.12 Frequency Protection (optional) The frequency protection automatically selects the largest of the phase-to-phase voltages. If all three voltages are below the operating range of 65 % · U (secondary), the frequency cannot be determined. In that case the indication 5215 „Freq UnderV Blk“...
Page 174 Functions 2.12 Frequency Protection (optional) Figure 2-63 Logic diagram of the frequency protection SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 175: Setting Notes
Functions 2.12 Frequency Protection (optional) 2.12.2 Setting Notes General Frequency protection is only in effect and accessible if address 136 FREQUENCY Prot. is set to Enabled during configuration of protection functions. If the function is not required, Disabled is to be set. The frequency protection function features 4 frequency stages f1 to f4 each of which can function as overfre- quency stage or underfrequency stage.
Page 176: Settings
Functions 2.12 Frequency Protection (optional) The set times are additional delay times not including the operating times (measuring time, dropout time) of the protection function. If underfrequency protection is used for load shedding purposes, then the frequency settings relative to other feeder relays are generally based on the priority of the customers served by the protection relay.
Page 177: Information List
Functions 2.12 Frequency Protection (optional) Addr. Parameter Setting Options Default Setting Comments 3632 f4 PICKUP 45.50 .. 54.50 Hz 51.00 Hz f4 Pickup 3633 f4 PICKUP 55.50 .. 64.50 Hz 62.00 Hz f4 Pickup 3634 T f4 0.00 .. 600.00 sec 30.00 sec T f4 Time Delay 2.12.4...
Page 178: Circuit Breaker Failure Protection
Functions 2.13 Circuit Breaker Failure Protection 2.13 Circuit Breaker Failure Protection The circuit breaker failure protection provides rapid back-up fault clearance in the event that the circuit breaker fails to respond to a trip command from a protection function of the local circuit breaker. 2.13.1 Function Description General...
Page 179 Functions 2.13 Circuit Breaker Failure Protection Figure 2-65 Simplified function diagram of circuit breaker failure protection controlled by circuit breaker aux- iliary contact Current flow monitoring Each of the phase currents and an additional plausibility current (see below) are filtered by numerical filter al- gorithms so that only the fundamental component is used for further evaluation.
Page 180 Functions 2.13 Circuit Breaker Failure Protection Figure 2-66 Current flow monitoring with plausibility currents 3·I and 3·I only available/visible if 139 is set to enabled w/ 3I0> Monitoring the circuit breaker auxiliary contacts It is the central function control of the device that informs the circuit breaker failure protection on the position of the circuit breaker (refer also to Section 2.16.1).
Page 181 Functions 2.13 Circuit Breaker Failure Protection Figure 2-67 Interlock of the auxiliary contact criterion - example for phase L1 if phase-segregated auxiliary contacts are available if series-connected NC contacts are available On the other hand, current flow is not a reliable criterion for proper operation of the circuit breaker for faults which do not cause detectable current flow (e.g.
Page 182 Functions 2.13 Circuit Breaker Failure Protection Figure 2-68 Creation of signal "CB ≥ any pole closed" If an internal protection function or an external protection device trips without current flow, the circuit breaker failure protection is initiated by the internal input „Start internal w/o I“, if the trip signal comes from the internal voltage protection or frequency protection, or by the external input „>BF Start w/o I“.
Page 183 Functions 2.13 Circuit Breaker Failure Protection Phase-segregated initiation Phase segregated initiation of the circuit breaker failure protection is necessary if the circuit breaker poles are operated individually, e.g. if 1-pole automatic reclosure is used. This is possible if the device is able to trip 1- pole.
Page 184 Functions 2.13 Circuit Breaker Failure Protection In principle, the starting condition logic for the delay time(s) is designed similar to that for the common phase initiation, however, individually for each of the three phases (as shown in Figure 2-72). Thus, current and initi- ation conditions are processed for each CB pole.
Page 185 Functions 2.13 Circuit Breaker Failure Protection Figure 2-72 Initiation conditions for single-pole trip commands SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 186 Functions 2.13 Circuit Breaker Failure Protection Delay times When the initiatiation conditions are fulfilled, the associated timers are started. The circuit breaker pole(s) must open before the associated time has elapsed. Different delay times are possible for 1-pole and 3-pole initiation. An additional delay time can be used for two- stage circuit breaker failure protection.
Page 187 Functions 2.13 Circuit Breaker Failure Protection Address 3913 T2StartCriteria is used to set whether the delay time T2 will be started after expiry of T1 (T2StartCriteria = With exp. of T1) or simultaneously with it (T2StartCriteria = Parallel withT1). The time T2 can also be initiated via a separate binary input 1424 „>BF STARTonlyT2“. Figure 2-75 Logic diagram of the two-stage breaker failure protection Circuit breaker not operational...
Page 188 Functions 2.13 Circuit Breaker Failure Protection started (Figure 2-76). Thus, the adjacent circuit breakers (bus-bar) are tripped immediately in case the feeder circuit breaker is not operational. Figure 2-76 Circuit breaker not operational Transfer trip to the remote end circuit breaker When the local feeder circuit breaker fails, tripping of the circuit breaker at the remote line end is often also desired.
Page 189 Functions 2.13 Circuit Breaker Failure Protection The end fault is recognized when the current continues flowing although the circuit breaker auxiliary contacts indicate that the circuit breaker is open. An additional criterion is the presence of any circuit breaker failure pro- tection initiate signal.
Page 190: Setting Notes
Functions 2.13 Circuit Breaker Failure Protection 2.13.2 Setting Notes General The circuit breaker failure protection and its ancillary functions (end fault protection, pole discrepancy supervi- sion) can only operate if they were set during configuration of the scope of functions (address 139 BREAKER FAILURE, setting Enabled or enabled w/ 3I0>).
Page 191 Functions 2.13 Circuit Breaker Failure Protection Note If the circuit breaker failure protection shall perform a 1-pole TRIP repetition, the time set at the AR, address 3408 T-Start MONITOR, must be longer than the time parameterized for address 3903 1p-RETRIP (T1) to prevent a 3-pole coupling by the AR before expiry of T1.
Page 192 Functions 2.13 Circuit Breaker Failure Protection Figure 2-81 Time sequence example for normal clearance of a fault, and with circuit breaker failure, using single-stage breaker failure protection Circuit breaker not operational These delays are not necessary if the control circuit of the local circuit breaker is faulted (e.g. control voltage failure or air pressure failure) since it is apparent that the circuit breaker is not capable of clearning the fault.
Page 193: Settings
Functions 2.13 Circuit Breaker Failure Protection The delay time T-PoleDiscrep. (address 3932) indicates how long a circuit breaker pole discrepancy con- dition of the feeder circuit breaker, i.e. only one or two poles open, may be present before the pole discrepancy supervision issues a 3-pole trip command.
Page 194: Information List
Functions 2.13 Circuit Breaker Failure Protection 2.13.4 Information List Information Type of In- Comments formation 1401 >BF on >BF: Switch on breaker fail protection 1402 >BF off >BF: Switch off breaker fail protection 1403 >BLOCK BkrFail >BLOCK Breaker failure 1404 >BFactivate3I0>...
Page 195: Thermal Overload Protection
Functions 2.14 Thermal Overload Protection 2.14 Thermal Overload Protection The thermal overload protection prevents damage to the protected object caused by thermal overloading, par- ticularly in case of transformers, rotating machines, power reactors and cables. It is in general not necessary for overhead lines, since no meaningful overtemperature can be calculated because of the great variations in the environmental conditions (temperature, wind).
Page 196: Setting Notes
Functions 2.14 Thermal Overload Protection Figure 2-82 Logic diagram of the thermal overload protection 2.14.2 Setting Notes General A prerequisite for using the thermal overload protection is that during the configuration of the scope of functions at address 142 Therm.Overload = Enabled was applied. At address 4201 Ther. OVERLOAD the function can be turned ON or OFF.
Page 197 Functions 2.14 Thermal Overload Protection Example: Belted cable 10 kV 150 mm Permissible continuous current I = 322 A Current transformers 400 A / 5 A Setting value K-FACTOR = 0.80 Time constant τ is set at address 4203 TIME CONSTANT. This is also provided by the manufac- The thermal time constant τ...
Page 198: Settings
Functions 2.14 Thermal Overload Protection Calculating the overtemperature The thermal replica is calculated individually for each phase. Address 4206 CALC. METHOD decides whether the highest of the three calculated temperatures (Θ max) or their arithmetic average (Average Θ) or the tem- perature calculated from the phase with maximum current (Θ...
Page 199: Monitoring Functions
Functions 2.15 Monitoring Functions 2.15 Monitoring Functions The device is equipped with extensive monitoring capabilities - concerning both, hardware and software. In ad- dition, the measured values are also constantly checked for plausibility, so that the current and voltage trans- former circuits are largely integrated into the monitoring.
Page 200 Functions 2.15 Monitoring Functions Sampling Frequency The sampling frequency and the synchronism between the ADCs (analog-to-digital converters) is continuously monitored. If deviations that may occur cannot be corrected by another synchronisation, the device sets itself out of operation and the red LED „ERROR“ lights up; The device-ready relay relay drops off and signals the malfunction by its „life contact“.
Page 201: Software Monitoring
Functions 2.15 Monitoring Functions Measured Value Acquisition Voltages Four measuring inputs are available in the voltage path: three for phase-to-earth voltages and one input for the displacement voltage (e-n voltage of open delta winding) or a busbar voltage. If the displacement voltage is connected to the device, the sum of the three digitized phase voltages must equal three times the zero se- quence voltage.
Page 202 Functions 2.15 Monitoring Functions After a settable time (5 s-100 s), this malfunction is signalled as „Fail I balance“ (no. 163). Figure 2-84 Current symmetry monitoring Voltage Symmetry During normal system operation the voltages are assumed to be largely symmetrical. The symmetry is moni- tored in the device by magnitude comparison.
Page 203 Functions 2.15 Monitoring Functions Broken wire monitoring During steady-state operation the broken wire monitoring detects interruptions in the secondary circuit of the current transformers. In addition to the hazard potential caused by high voltages in the secondary circuit, this kind of interruption causes differential currents to the differential protection, such as those evoked by faults in the protected object.
Page 204 Functions 2.15 Monitoring Functions A wire break is signalled under the following conditions: • A suspected local wire break has been detected. • The logic for detecting the circuit breaker position (see Section 2.16.1, Detection of the Circuit Breaker Po- sition) does not signal an open circuit breaker pole.
Page 205 Functions 2.15 Monitoring Functions Figure 2-87 Broken-wire monitoring Voltage Phase Sequence The phase rotation of the measured voltages is checked by monitoring of the voltage phase sequence. before U before U This check takes place if each measured voltage has a minimum magnitude of |, |U |, |U | >...
Page 206 Functions 2.15 Monitoring Functions Fast Asymmetrical Measuring Voltage Failure "Fuse Failure Monitor". In the event of a measured voltage failure due to a short circuit fault or a broken conductor in the voltage trans- former secondary circuit certain measuring loops may mistakenly see a voltage of zero. Simultaneously existing load currents may then cause a spurious pickup.
Page 207 Functions 2.15 Monitoring Functions uated in these systems but only the negative sequence voltage and the ratio between negative sequence and positive sequence voltage. As soon as such an error has been detected, all functions that work on the basis of undervoltage are blocked. The immediate blocking requires that current flows in at least one of the phases.
Page 208 Functions 2.15 Monitoring Functions A 3-phase failure of the secondary measured voltages can be distinguished from an actual system fault by the fact that the currents have no significant change in the event of a failure in the secondary measured voltage. For this reason, the current values are routed to a buffer so that the difference between present and stored current values can be analysed to recognise the magnitude of the current differential (current differential crite- rion), see Figure 2-89.
Page 209 Functions 2.15 Monitoring Functions Logic diagram of the additional measured voltage failure monitoring „Fail U absent“ Figure 2-90 Effect of the Measuring Voltage Failure In the event of a measuring voltage failure due to a short-circuit or broken conductor in the voltage transformer secondary circuit, some or all measuring loops may mistakenly see a voltage of zero.
Page 210: Monitoring The Phase Angle Of The Positive Sequence Power
Functions 2.15 Monitoring Functions 2.15.1.4 Monitoring the Phase Angle of the Positive Sequence Power This monitoring function allows determining the direction of power flow. You can monitor the phase angle of the complex power, and generate an indication when the power phasor is inside a settable segment. One example of this application is the indication of capacitive reactive power.
Page 211 Functions 2.15 Monitoring Functions Figure 2-93 Phase Angle Monitoring for Negative Active Power The two angles must be at least 3° apart; if they are not, monitoring is blocked, and the indication „ϕ Set wrong“ (No. 132) is output. The following conditions must be fulfilled for measurement to be enabled: is higher than the value set in parameter 2943 I1>.
Page 212: Fault Reactions
Functions 2.15 Monitoring Functions Figure 2-94 Logic of the Positive Sequence System Phase Angle Monitoring 2.15.1.5 Fault Reactions Depending on the kind of fault detected, an alarm is given, the processor is restarted or the device is taken out of operation. After three unsuccessful restart attempts, the device is taken out of service. The device ready relay drops out and indicates the device failure with its NC contact („life contact“).
Page 213 Functions 2.15 Monitoring Functions Table 2-7 Summary of malfunction responses of the device Supervision Possible Causes Malfunction Response Indication (No.) Device Auxiliary Supply Voltage External (aux. voltage) inter- Device out of operation or All LEDs dark drops Loss nal (converter) alarm „Error 5V“...
Page 214: Setting Notes
Functions 2.15 Monitoring Functions Supervision Possible Causes Malfunction Response Indication (No.) Device Voltage failure, 1-/2- External (voltage transform- Indication „VT FuseFail>10s“ As allocated phase „Fuse Failure ers) Undervoltage protection (169), Monitor“ blocked, „VT FuseFail“ (170) Frequency protection blocked Voltage failure, 3-phase External (power system or Indication „Fail U absent“...
Page 215 Functions 2.15 Monitoring Functions Broken wire monitoring The broken wire monitoring is enabled or disabled via the parameter 2931 BROKEN WIRE. The differential pro- tection function is only blocked with the setting ON. By means of the setting Alarm only, a broken wire can be signalled;...
Page 216: Settings
Functions 2.15 Monitoring Functions 2.15.1.7 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Additional Settings. The table indicates region-specific presettings. Column C (configuration) indicates the corresponding second- ary nominal current of the current transformer. Addr.
Page 217: Information List
Functions 2.15 Monitoring Functions Addr. Parameter Setting Options Default Setting Comments 2935A ΔI min 0.05 .. 1.00 A 0.10 A Min. current diff. for wire break det. 0.25 .. 5.00 A 0.50 A 2941 0 .. 359 ° 200 ° Limit setting PhiA ϕA 2942...
Page 218: Trip Circuit Supervision
Functions 2.15 Monitoring Functions 2.15.2 Trip Circuit Supervision The line protection 7SD610 is equipped with an integrated trip circuit supervision function. Depending on the number of available binary inputs (not connected to a common potential), supervision with one or two binary inputs can be selected.
Page 219 Functions 2.15 Monitoring Functions Supervision with two binary inputs not only detects interruptions in the trip circuit and loss of control voltage, it also supervises the response of the circuit breaker using the position of the circuit breaker auxiliary contacts. Depending on the conditions of the trip contact and the circuit breaker, the binary inputs are activated (logical condition „H“...
Page 220 Functions 2.15 Monitoring Functions Figure 2-97 Principle of the trip circuit supervision with one binary input Trip relay contact Circuit breaker Circuit breaker trip coil Aux1 Circuit breaker auxiliary contact (NO contact) Aux2 Circuit breaker auxiliary contact (NC contact) U-CTR Control voltage for trip circuit U-BI Input voltage of binary input...
Page 221: Setting Notes
Functions 2.15 Monitoring Functions 2.15.2.2 Setting Notes General The number of circuits to be supervised was set during the configuration in address 140 Trip Cir. Sup. (Section 2.1.1.2). If the trip circuit supervision is not used at all, the setting Disabled must be applied there. The trip circuit supervision can be switched ON or OFF in address 4001 FCT TripSuperv..
Page 222: Function Control And Circuit Breaker Test
Functions 2.16 Function Control and Circuit Breaker Test 2.16 Function Control and Circuit Breaker Test 2.16.1 Function Control The function control is the control centre of the device. It coordinates the sequence of the protection and ancil- lary functions, processes their decisions and the information coming from the power system. Applications •...
Page 223 Functions 2.16 Function Control and Circuit Breaker Test Figure 2-99 Logic diagram of the manual closing procedure Reclosure via the integrated control functions - on-site control, control via DIGSI, control via serial interface - can have the same effect as manual closure, see parameter 1152 Chapter 2.1.4.1 at margin heading „Circuit Breaker Status“.
Page 224 Functions 2.16 Function Control and Circuit Breaker Test Figure 2-100 Manual closure with internal automatic reclosure Circuit breaker Circuit breaker close coil CBaux Circuit breaker auxiliary contact If, however, external close commands which should not activate the manual close function are possible (e.g. external reclosure device), the binary input „>Manual Close“...
Page 225 Functions 2.16 Function Control and Circuit Breaker Test The phase currents and the phase-to-earth voltages are available as measuring quantities. A flowing current excludes that the circuit breaker is open (exception: a fault between current transformer and circuit breaker). If the circuit breaker is closed, it may, however, still occur that no current is flowing.
Page 226: Detection Of The Circuit Breaker Position
Functions 2.16 Function Control and Circuit Breaker Test 2.16.1.2 Detection of the Circuit Breaker Position For Protection Purposes Information regarding the circuit breaker position is required by various protection and supplementary functions to ensure their optimal functionality. This is, for example, of assistance for •...
Page 227 Functions 2.16 Function Control and Circuit Breaker Test Figure 2-103 Circuit breaker position logic SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 228: Open Pole Detector
Functions 2.16 Function Control and Circuit Breaker Test For automatic reclosure and circuit breaker test Separate binary inputs comprising information on the position of the circuit breaker are available for the auto- matic reclosure and the circuit breaker test. This is important for •...
Page 229 Functions 2.16 Function Control and Circuit Breaker Test Figure 2-104 Open pole detector logic SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 230: Pickup Logic Of The Entire Device
Functions 2.16 Function Control and Circuit Breaker Test 1-pole Dead Time During a 1-pole dead time, the load current flowing in the two healthy phases forces a current flow via earth which may cause undesired pickup. The raising zero-sequence voltage can also produce undesired responses of the functions.
Page 231: Tripping Logic Of The Entire Device
Functions 2.16 Function Control and Circuit Breaker Test Spontaneous Indications Spontaneous indications are fault indications which appear in the display automatically following a general fault detection or trip command of the device. For the 7SD610, these indications include: „Relay PICKUP“: Protection function that picked up;...
Page 232 Functions 2.16 Function Control and Circuit Breaker Test Single-pole tripping for two-phase faults Single-pole tripping for two-phase faults is a special feature. If a phase-to-phase fault without earth occurs in an earthed system, this fault can be cleared by single-pole trip and automatic reclosure in one of the faulted phases as the short-circuit path is interrupted in this manner.
Page 233 Functions 2.16 Function Control and Circuit Breaker Test ed when the circuit breaker pole is open, is set. Address 1135 Reset Trip CMD determines under which conditions a trip command is reset. If CurrentOpenPole is set, the trip command is reset as soon as the current disappears.
Page 234 Functions 2.16 Function Control and Circuit Breaker Test Conditions which cause reclosure interlocking and control commands which have to be interlocked can be set individually. The two inputs and the output can be wired via the correspondingly allocated binary inputs and outputs or be linked via user-defined logic functions (CFC).
Page 235 Functions 2.16 Function Control and Circuit Breaker Test Figure 2-107 Breaker tripping alarm suppression If the device issues a final trip command, the contact remains closed. This is the case, during the reclaim time of the automatic reclosure cycle, when the automatic reclosure is blocked or switched off or, due to other reasons is not ready for automatic reclosure (e.g.
Page 236: Circuit Breaker Test
Functions 2.16 Function Control and Circuit Breaker Test 2.16.2 Circuit Breaker Test The 7SD610 line protection relay allows for convenient testing of the trip circuits and the circuit breakers. 2.16.2.1 Functional Description The test programs shown in Table 2-10 are available. The single-pole tests are of course only possible if the device you are using is capable of single-pole tripping.
Page 237: Information List
Functions 2.16 Function Control and Circuit Breaker Test 2.16.2.2 Information List Information Type of In- Comments formation CB1tst L1 CB1-TEST trip/close - Only L1 CB1tst L2 CB1-TEST trip/close - Only L2 CB1tst L3 CB1-TEST trip/close - Only L3 CB1tst 123 CB1-TEST trip/close Phases L123 7325 CB1-TESTtrip L1...
Page 238: Switching Statistics
Functions 2.16 Function Control and Circuit Breaker Test Reset of Stored LED / Relays Pickup of a new protection function generally deletes all stored LED / relays so that only the information of the latest fault is displayed at a time. The deletion of the stored LED and relays can be inhibited for a settable time under address 625 T MIN LED HOLD.
Page 239: Setting Notes
Functions 2.16 Function Control and Circuit Breaker Test 2.16.3.3 Setting Notes Fault Messages Pickup of a new protection function generally turns off any previously set displays, so that only the latest fault is displayed at any one time. It can be selected whether the stored LED displays and the spontaneous indica- tions on the display appear upon renewed pickup, or only after a renewed trip signal is issued.
Page 240 Functions 2.16 Function Control and Circuit Breaker Test Information Type of In- Comments formation >Annunc. 3 >User defined annunciation 3 >Annunc. 4 >User defined annunciation 4 >Test mode >Test mode >DataStop >Stop data transmission Device OK Device is Operational and Protecting ProtActive IntSP At Least 1 Protection Funct.
Page 241: En100-Modul 1
Functions 2.16 Function Control and Circuit Breaker Test 2.16.4 EN100-Module 2.16.4.1 Function Description An EN100-Module allows to integrate the 7SD610 into 100 Mbit communication networks used by process control and automation systems in accordance with IEC 61850. This standard provides consistent inter-relay communication without gateways or protocol converters.
Page 242: Function Description
Functions 2.17 Additional Functions 2.17 Additional Functions The additional functions of the 7SD610 differential protection relay include: • Commissioning tool, • Processing of messages, • Processing of operational measured values, • Storage of fault record data. 2.17.1 Commissioning aid 2.17.1.1 Function Description There is a comprehensive commissioning and monitoring tool that checks the communication and the whole differential protection function.
Page 243: Additional Functions
Functions 2.17 Additional Functions Figure 2-112 WEB-Monitor – Example of voltages and currents Furthermore, the browser enables a clear display of the most important measured data. The measured values list can be selected from the navigation toolbar separately for the local and the remote device. In each case a list with the desired information is displayed (see Figures 2-112 and 2-114).
Page 244: Setting Notes
Functions 2.17 Additional Functions Figure 2-114 List of measured percentage values with given angle differences – Example The following types of indications can be retrieved and displayed with the WEB-Monitor • Operational indications (buffer: event log) • Fault indications (buffer: trip log) •...
Page 245: Processing Of Messages
Functions 2.17 Additional Functions 2.17.2 Processing of Messages After the occurrence of a system fault, data regarding the response of the protection relay and the measured quantities should be saved for future analysis. For this reason message processing is done in three ways: 2.17.2.1 Function Description Indicators and Binary Outputs (Output Relays) Important events and states are displayed by LEDs on the front cover.
Page 246 Functions 2.17 Additional Functions Figure 2-115 Operational measured values in the default display Default display 3 shows the measured power values and the measured values U and I L1-L2 Figure 2-116 Operational measured values in the default display Moreover, the device has several event buffers for operational indications, fault indications, switching statistics, etc., which are protected against loss of auxiliary supply by means of a backup battery.
Page 247 Functions 2.17 Additional Functions Classification of Indications Indications are classified as follows: • Operational indications: messages generated while the device is in operation: They include information about the status of device functions, measurement data, system data, and similar information. • Fault indications: messages from the last eight system faults that were processed by the device.. •...
Page 248: Statistics
Functions 2.17 Additional Functions Retrievable Indications The indications of the last eight system faults can be retrieved and read out. A total of 600 indications can be stored. The oldest indications are erased for the newest fault indications when the buffer is full. Spontaneous Indications Spontaneous indications contain information that new indications have arrived.
Page 249: Information List
Functions 2.17 Additional Functions Transmission Statistics In 7SD610 the protection communication is registered in statistics. The transmission times of the information between the devices via interfaces (send and receive) are measured continuously. The values are kept stored in the statistics folder. The availability of the transmission media is also reported. The availability is indicated in % min and % h.
Page 250: Measurement During Operation
Functions 2.17 Additional Functions 2.17.4 Measurement During Operation 2.17.4.1 Function Description A series of measured values and the values derived from them are available for on-site retrieval or for data transfer. A precondition for the correct display of primary and percentage values is the complete and correct entry of the nominal values of the instrument transformers and the power system as well as the transformation ratio of the current and voltage transformers in the earth paths.
Page 251 Functions 2.17 Additional Functions Table 2-11 Operational measured values of the local device Measured Values Primary Second- % Referred to Phase currents Nominal operational current Earth current Nominal operational current ), ϕ(I Phase angle of the phase currents ° – –...
Page 252 Functions 2.17 Additional Functions 2.17.4.2 Information List Information Type of In- Comments formation IL1 = I L1 IL2 = I L2 IL3 = I L3 3I0 = 3I0 (zero sequence) IY = IY (star point of transformer) I1 (positive sequence) I2 (negative sequence) UL1E= U L1-E...
Page 253: Information List
Functions 2.17 Additional Functions 2.17.5 Differential Protection Values 2.17.5.1 Measured values of differential protection The differential and restraint current values of the differential protection which are listed in the following table can be called up at the front of the device, read out via the operating interface using a PC with DIGSI or trans- ferred to a control centre via the system interface.
Page 254: Differential Protection Values
Functions 2.17 Additional Functions 2.17.6 Remote Measured Values 2.17.6.1 Function Description During communication via the protection data interface, the data from the other end of the protected object can also be read out. For both devices, the currents and voltages involved as well as phase shifts between the local and remote measured quantities can be displayed.
Page 255: Remote Measured Values
Functions 2.17 Additional Functions Table 2-14 Constellation measured values for device 1 Information Info type Explanation 7761 „Relay ID“ Device address of the first devcie 7762 „IL1_opN=“ IL1 (% of operational rated current) 7763 „ΦI L1=“ Angle IL1_remote <-> IL1_local 7764 „IL2_opN=“...
Page 256: Oscillographic Fault Records
Functions 2.17 Additional Functions 2.17.8.2 Setting Notes General Other settings pertaining to fault recording (waveform capture) are found in the submenu Oscillographic Fault Records submenu of the Settings menu. Waveform capture makes a distinction between the trigger instant for an oscillographic record and the criterion to save the record (address 402 WAVEFORMTRIGGER). This pa- rameter can only be altered using DIGSI at Additional Settings.
Page 257: Setting Notes
Functions 2.17 Additional Functions 2.17.8.4 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 2.17.9 Energy 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 trans- ferred to a central master station via the system interface.
Page 258: Information List
Functions 2.17 Additional Functions 2.17.9.3 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) WpΔ= Increment of active energy WqΔ= Increment of reactive energy Wp+= MVMV Wp Forward Wq+= MVMV...
Page 259: Control Authorization
Functions 2.18 Command Processing 2.18 Command Processing The SIPROTEC 4 7SD610 includes a command processing for initiating switching operations in the system. Control can originate from four command sources: • Local operation using the keypad on the local user interface of the device, •...
Page 260: Command Processing
Functions 2.18 Command Processing 2.18.1.2 Sequence in the Command Path Safety mechanisms in the command sequence ensure that a switch command can only be released after a thorough check of preset criteria has been successfully concluded. Additionally, user-defined interlocking con- ditions can be configured separately for each device.
Page 261: Interlocking
Functions 2.18 Command Processing 2.18.1.3 Interlocking Interlocking can be executed by the user-defined logic (CFC). Switchgear interlocking checks in a SI- CAM/SIPROTEC 4 system are normally divided in the following groups: • System interlocking checked by a central control system (for interbay interlocking), •...
Page 262 Functions 2.18 Command Processing Figure 2-118 Example of an operational indication for switching circuit breaker (Q0) Standard Interlocking The standard interlocking includes the checks for each switchgear which were set during the configuration of inputs and outputs, see SIPROTEC 4 System Description. An overview for processing the interlocking conditions in the relay is shown in Figure 2-119.
Page 263 Functions 2.18 Command Processing The display shows the configured interlocking reasons. The are marked by letters as explained in Table 2-17. Table 2-17 Interlocking Commands Interlocking Commands Command Display Switching Authority System Interlocking Bay Interlocking SET = ACTUAL (switch direction check) Protection Blockage Figure 2-120 shows all interlocking conditions (which usually appear in the display of the device) for three switchgear items with the relevant abbreviations explained in Table 2-17.
Page 264: Information List
Functions 2.18 Command Processing 2.18.2 Control Device 2.18.2.1 Information List Information Type of In- Comments formation Breaker CF_D12 Breaker Breaker Breaker Disc.Swit. CF_D2 Disconnect Switch Disc.Swit. Disconnect Switch EarthSwit CF_D2 Earth Switch EarthSwit Earth Switch Brk Open IntSP Interlocking: Breaker Open Brk Close IntSP Interlocking: Breaker Close...
Page 265: Process Data
Functions 2.18 Command Processing 2.18.3 Process Data During the processing of commands, independently of the further allocation and processing of indications, command and process feedbacks are sent to the indication processing. These indications contain information on the cause. With the corresponding allocation (configuration) these indications are entered in the event log, thus serving as a report.
Page 266: Information List
Functions 2.18 Command Processing 2.18.3.2 Information List Information Type of In- Comments formation >Door open >Cabinet door open >CB wait >CB waiting for Spring charged >Err Mot U >Error Motor Voltage >ErrCntrlU >Error Control Voltage >SF6-Loss >SF6-Loss >Err Meter >Error Meter >Tx Temp.
Page 267 Functions 2.18 Command Processing SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 268 Functions 2.18 Command Processing SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 269: 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 270: Mounting And Connections
Mounting and Commissioning 3.1 Mounting and Connections 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, installation, and application of the device according to the warnings in this instruction manual.
Page 271 Mounting and Commissioning 3.1 Mounting and Connections Binary Inputs and Outputs The connections to the power plant depend on the possible allocation of the binary inputs and outputs, i.e. how they are assigned to the power equipment. The preset allocation can be found in the tables in Section A.4 of the Appendix.
Page 272 Mounting and Commissioning 3.1 Mounting and Connections Trip Circuit Supervision Please note that two binary inputs or one binary input and one bypass resistor R must be connected in series. The pick-up threshold of the binary inputs must therefore be substantially below half the rated control DC volt- age.
Page 273 Mounting and Commissioning 3.1 Mounting and Connections To keep the circuit breaker trip coil not energized in the above case, R is derived as: Constant current with activated BI ( = 1.8 mA) BI (HIGH) Minimum control voltage for BI BI min 17 V for delivery setting for nominal voltages of 24/48/60 V;...
Page 274: Hardware Modifications
Mounting and Commissioning 3.1 Mounting and Connections 3.1.2 Hardware Modifications 3.1.2.1 General A subsequent adaptation of hardware to the power system conditions can be necessary for example with regard to the control voltage for binary inputs or termination of bus-capable interfaces. Follow the procedure described in this section, whenever hardware modifications are carried out.
Page 275: Disassembly
Mounting and Commissioning 3.1 Mounting and Connections Replacing Interfaces The serial interfaces can be exchanged in the versions for panel flush mounting and cubicle mounting. The fol- lowing section under margin heading „Rreplacing Interface Modules“ describes which interfaces can be ex- changed, and how this is done.
Page 276 Mounting and Commissioning 3.1 Mounting and Connections • If the device features additional interfaces besides those at location „A“ and „C“, the screws located diago- nally to the interfaces must be removed. This activity does not apply if the device is for surface mounting. •...
Page 277: Switching Elements On Printed Circuit Boards
Mounting and Commissioning 3.1 Mounting and Connections 3.1.2.3 Switching Elements on Printed Circuit Boards C-CPU-2 processor board The PCB layout of the processor board C–CPU-2 is illustrated in the following figure. The set nominal voltage of the integrated power supply is checked according to Table 3-2, the quiescent state of the life contact accord- ing to Table 3-3, the selected control voltages of the binary inputs BI1 to BI5 according to Table 3-4 and the integrated RS232 / RS485 interface according to Table 3-5 to 3-7.
Page 278 Mounting and Commissioning 3.1 Mounting and Connections Table 3-2 Jumper setting of the rated voltage of the integrated Power Supply on the C-CPU-2 processor board Jumper Nominal voltage DC 24 V to 48 V DC 60 V to 125 V DC 110 V to 250 V, AC 115 V/230 V Not used Not used...
Page 279 Mounting and Commissioning 3.1 Mounting and Connections With interface RS232 jumper X111 is needed to activate CTS which enables the communication with the modem. Table 3-6 Jumper setting for CTS (Clear To Send, flow control) on the C-CPU-2 processor board Jumper /CTS from Interface RS232 /CTS Controlled by /RTS...
Page 280 Mounting and Commissioning 3.1 Mounting and Connections Input/Output Board C-I/O-11 Figure 3-6 C-I/O-11 input/output board with representation of jumper settings required for checking con- figuration settings Table 3-8 Jumper settings for Control Voltages of the binary inputs BI6 and BI7 on the input/output board C-I/O-11 Binary input Jumper...
Page 281 Mounting and Commissioning 3.1 Mounting and Connections The set nominal current of the current input transformers are checked on the input/output board C-I/O-11. The jumpers X60 to X64 must all be set to the same rated current, i.e. one jumper (X61 to X64) for each input trans- former of the phase currents and in addition the common jumper X60.
Page 282: Interface Modules
Mounting and Commissioning 3.1 Mounting and Connections 3.1.2.4 Interface Modules Exchanging Interface Modules The interface modules are located on the processor board C-CPU-2 (No. 1 in Figure 3-3). Figure 3-7 C-CPU-2 board with interface modules SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 283 Mounting and Commissioning 3.1 Mounting and Connections Please observe the following: • The interface modules can only be exchanged in devices in flush-mounted housing. Interface modules for devices with surface mounting housing must be retrofitted in our manufacturing centre. • Use only interface modules that can be ordered ex-factory via the ordering code (see also Appendix, Section A.1).
Page 284 Mounting and Commissioning 3.1 Mounting and Connections Jumper X11 is used to activate the flow control which is important for the modem communication. Table 3-11 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 con-...
Page 285 Mounting and Commissioning 3.1 Mounting and Connections Profibus/DNP/MODBUS Interface Figure 3-10 Location of the jumpers for configuring the terminating resistors (PROFIBUS, DNP and MODBUS interface) EN100 Ethernet Module (IEC 61850) The Ethernet interface module has no jumpers. No hardware modifications are required to use it. Termination Bus-capable interfaces always require a termination at the last device on the bus, i.e.
Page 286: Reassembly
Mounting and Commissioning 3.1 Mounting and Connections 3.1.2.5 Reassembly The device is assembled in the following steps: • Insert the modules carefully in the housing. The mounting locations are shown in figure 3-3. For the model of the device designed for surface mounting, use the metal lever to insert the C-CPU-2 board. The installa- tion is easier with the lever.
Page 287: Rack And Cubicle Mounting
Mounting and Commissioning 3.1 Mounting and Connections Figure 3-12 Panel flush mounting of a device (housing size 3.1.3.2 Rack and Cubicle Mounting To install the device in a rack or cubicle, a pair of mounting rails; one for top, one for bottom are required. The ordering codes are stated in Appendix, Section A.1 For 7SD610 (Picture 3-13) 4 covers and 4 holes exist.
Page 288: Panel Mounting
Mounting and Commissioning 3.1 Mounting and Connections Figure 3-13 Installing a device in a rack or cubicle (housing size 3.1.3.3 Panel Mounting For mounting proceed as follows: • Secure the device to the panel with four screws. For dimensions see the Technical Data in Section 4.17. •...
Page 289: Checking Connections
Mounting and Commissioning 3.2 Checking Connections Checking Connections 3.2.1 Checking Data Connections of Serial Interfaces The tables in the following sections list the pin assignments for the different serial interfaces, the time synchro- nization interface and the Ethernet interface of the device. The position of the connectors is depicted in the fol- lowing figures.
Page 290 Mounting and Commissioning 3.2 Checking Connections System interface For versions equipped with a serial interface to a control center, the user must check the data connection. The visual check of the assignment of the transmission and reception channels is of particular importance. With RS232 and fibre optic interfaces, each connection is dedicated to one transmission direction.
Page 291 Mounting and Commissioning 3.2 Checking Connections Time Synchronisation Interface It is optionally possible to process 5 V, 12 V or 24 V time synchronization signals, provided that these are con- nected to the inputs named in the following table. Table 3-13 D-subminiature connector assignment of the time synchronization interface Pin No.
Page 292: Checking The Protection Data Communication
Mounting and Commissioning 3.2 Checking Connections 3.2.2 Checking the Protection Data Communication The protection data communication is conducted either directly from device to device via optical fibres or via communication converters and a communication network or a dedicated transmission medium. Optical Fibres, Directly WARNING! Warning of Laser rays...
Page 293: Checking The System Connections
Mounting and Commissioning 3.2 Checking Connections 3.2.3 Checking the System Connections WARNING! Warning of dangerous voltages Non-observance of the following measures can result in death, personal injury or substantial property damage. Therefore, only qualified people who are familiar with and adhere to the safety procedures and precautionary measures shall perform the inspection steps.
Page 294 Mounting and Commissioning 3.2 Checking Connections • The short circuit links of the connectors for the current circuits have to be checked. This can be done using secondary test equipment or other test equipment for checking continuity. Make sure that terminal continuity is not wrongly simulated in reverse direction via current transformers or their short-circuiters.
Page 295: Commissioning
Mounting and 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 substantial 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 296: Test Mode / Transmission Block
Mounting and Commissioning 3.3 Commissioning 3.3.1 Test Mode / Transmission Block Activation and Deactivation If the device is connected to a central control system or a server via the SCADA interface, then the information that is transmitted can be modified with some of the protocols available (see Table „Protocol-dependent func- tions“...
Page 297: Testing The System Interface
Mounting and Commissioning 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“...
Page 298 Mounting and Commissioning 3.3 Commissioning Figure 3-16 System interface test with dialog box: Generating indications – Example Changing the Operating State On clicking one of the buttons in the column Action you will be prompted for the password No. 6 (for hardware test menus).
Page 299: Checking The Switching States Of The Binary Inputs/Outputs
Mounting and Commissioning 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 300 Mounting and Commissioning 3.3 Commissioning Figure 3-17 Test of the Binary Inputs and Outputs — Example Changing the operating state To change the operating state of a hardware component, click on the associated switching field in the Sched- uled column. Before executing the first change of the operating state the password No.
Page 301 Mounting and Commissioning 3.3 Commissioning Proceed as follows in order to check the binary inputs: • Each state in the system which causes a binary input to pick up must be generated. • Check the reaction in the Status column of the dialog box. To do this, the dialog box must be updated. The options may be found below under the margin heading „Updating the Display“.
Page 302: Checking The Protection Data Topology
Mounting and Commissioning 3.3 Commissioning 3.3.5 Checking the Protection Data Topology General The communication topology can either be checked from the PC using DIGSI or with a „ WEB-Monitor“. If you choose to work with the „WEB-Monitor“, please note the Help files referring to the „WEB-Monitor“. You can either connect the PC to the device locally using the operator interface at the front, or the service in- terface at the back of the PC (Figure 3-18).
Page 303 Mounting and Commissioning 3.3 Commissioning Checking a Connection using Direct Link For two devices linked with fibre optical cables (as in Figure 3–18 or 3–19), this connection is checked as fol- lows. • Both devices at the link ends have to be switched on. •...
Page 304 Mounting and Commissioning 3.3 Commissioning • Both devices at the link ends have to be switched on. • First configure the communication converter CC-1: – Disconnect the auxiliary supply voltage from both poles. – Open the communication converter. – Set the jumpers to the matching position for the correct interface type and transmission rate; they must be identical with the parameterization of the 7SD610 (address 4502 CONNEC.
Page 305 Mounting and Commissioning 3.3 Commissioning Consistency of Topology and Parameterisation Having performed the above checks, the linking of a device pair, including their communication converters, has been completely tested and connected to the auxiliary supply voltage. Now the devices communicate by them- selves.
Page 306 Mounting and Commissioning 3.3 Commissioning WEB-Monitor Topology and statistics of the protection data interfaces can be graphically displayed on the screen using the WEB Monitor. This requires a personal computer with web browser. Figure 3-21 shows the general information of the communication topology. Figure 3-21 Communication topology –...
Page 307 Mounting and Commissioning 3.3 Commissioning Table 3-16 Connection status Status Colour of the Remark connection display green The connection is OK. failed is not displayed asynchronous The connection cannot be used for protective functions. unknown grey The following figure shows a topology example with additional information. Figure 3-22 Communication topology –...
Page 308: Checking For Breaker Failure Protection
Mounting and Commissioning 3.3 Commissioning Figure 3-23 Example of viewing the transmission times and availability of the protection data interface 3.3.6 Checking for Breaker Failure Protection General If the device is equipped with the breaker failure protection and this function is used, the integration of this pro- tection function into the system must be tested under practical conditions.
Page 309 Mounting and Commissioning 3.3 Commissioning External Initiation Conditions If the breaker failure protection can also be started by external protection devices, the external start conditions are checked. Depending on the device version and the setting of the breaker failure protection, 1-pole or 3-pole trip are possible.
Page 310: Checking The Instrument Transformer Connections Of One Line End
Mounting and Commissioning 3.3 Commissioning Tripping of the Remote End If the trip command of the circuit breaker failure protection must also trip the circuit breaker at the remote end of the feeder under observation, the transmission channel for this remote trip must also be checked. This is done together with transmission of other signals according to Sections „Testing of the Teleprotection Scheme with ...“...
Page 311: Checking The Instrument Transformer Connections With Two Line Ends
Mounting and Commissioning 3.3 Commissioning • Having closed the circuit breaker, none of the measurement monitoring functions in the device must re- spond. – If there was a fault indication, however, the Event Log or spontaneous indications could be checked to investigate the reason for it.
Page 312 Mounting and Commissioning 3.3 Commissioning • The current transformer connections are tested at each end of the protected object with current flowing through the protected object. • After closing the circuit breakers, none of the measured value monitoring functions in the 7SD610 must re- spond.
Page 313 Mounting and Commissioning 3.3 Commissioning Figure 3-25 Remote measured values in the WEB-Monitor - Examples of plausible measured values Polarity check If the device is connected to voltage transformers, the local measured values already allow a polarity check. A load current of at least 5% of the rated operational current is still required. Any direction is possible but must be known.
Page 314 Mounting and Commissioning 3.3 Commissioning Figure 3-26 Apparent load power • The power measurement provides an initial indication as to whether the measured values of one end have the correct polarity. – If the direction of the reactive power is correct but the sign of the active power is incorrect, cyclic phase swapping of the currents (right) or of the voltages (left) might be the cause;...
Page 315 Mounting and Commissioning 3.3 Commissioning DANGER! Hazardous voltages during interruptions in secondary circuits of current transformers Non-observance of the following measure will result in death, severe personal injury or substantial property damage. Short-circuit the current transformer secondary circuits before current connections to the device are opened. from Own Line To generate a displacement voltage, the e-n winding of one phase in the voltage transformer set (e.g.
Page 316 Mounting and Commissioning 3.3 Commissioning If the current flows towards the protected object according to the circuit in Figure 3-27, the currents I and I are virtually zero. An earth current 3I of the approximately same level as I occurs. Accordingly, the voltage is missing and a zero sequence voltage 3U appears.
Page 317: Check Of The Signal Transmission For Internal And External Remote Tripping
Mounting and Commissioning 3.3 Commissioning • If there is a differential current in the size of twice the through-flowing current, you may assume a polarity reversal of the current transformer(s) at one line end. Again check the polarity and set it right after short- circuiting all the three current transformers.
Page 318: Testing User-Defined Functions
Mounting and Commissioning 3.3 Commissioning 3.3.10 Testing User-defined Functions The device has a vast capability for allowing functions to be defined by the user, especially with the CFC logic. Any special function or logic added to the device must be checked. A general procedure cannot in the nature of things be specified.
Page 319: Triggering Oscillographic Recording For Test
Mounting and Commissioning 3.3 Commissioning 3.3.13 Triggering Oscillographic Recording for Test In order to verify the reliability of the protection relay even during inrush processes, closing tests can be carried out to conclude the commissioning process. Oscillograhpic records provide the maximum information about the behaviour of the protection relay.
Page 320: Final Preparation Of The Device
Mounting and Commissioning 3.4 Final Preparation of the Device 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 apply force! The tightening torques must not be exceeded as the threads and terminal chambers may otherwise be dam- aged! The setting values should be checked again if they were changed during the tests.
Page 321: Technical Data
Technical Data This chapter presents the technical data of SIPROTEC 4 7SD610 device and its individual functions, including the limit values that must not be exceeded under any circumstances. The electrical and functional data of fully equipped devices are followed by the mechanical data, with dimensional drawings. General Protection Data Interfaces and differential protection topology Differential Protection...
Page 322: General
Technical Data 4.1 General General 4.1.1 Analog Inputs Nominal Frequency 50 Hz or 60 Hz (adjustable) Current inputs Nominal current 1 A or 5 A Power consumption per phase and earth path - at I = 1 A Approx. 0.05 VA - at I = 5 A Approx.
Page 323: Auxiliary Voltage
Technical Data 4.1 General 4.1.2 Auxiliary voltage Direct Voltage Voltage supply via integrated AC/DC converter Nominal auxiliary voltage U – DC 24 V/48 V DC 60 V/110 V/125 V DC 110 V/125 V/220 V/250 V Admissible voltage ranges DC 19 V to 58 V DC 48 V to 150 V DC 88 V to 300 V Superimposed AC ripple voltage,...
Page 324: Binary Inputs And Outputs
Technical Data 4.1 General 4.1.3 Binary Inputs and Outputs Binary inputs Number 7 (configurable) Rated Voltage Range DC 24 V to 250 V, in 3 ranges, bipolar Pick-up threshold Changeable via jumpers - For nominal voltages DC 24 V/48 V and ≥...
Page 325 Technical Data 4.1 General Binary Outputs Signalling/Trip Relays (see also terminal assignments in Appendix A.2)) Number and information (allocatable) UL Listed NO Contact NO Contact NO/NC (normal) (fast) (switch selectable) Switching capability MAKE 1000 W/VA Switching capability OFF 30 VA 40 W ohmic 25 W/VA for L/R ≤...
Page 326: Communication Interfaces
Technical Data 4.1 General 4.1.4 Communication Interfaces Protection data interfaces See Section 4.2 „Protection Data Interfaces and Communication Topology“ Operator Interface Connection Front side, non-isolated, RS232, 9-pin D-subminiature female connector for connection of a PC Operation With DIGSI Transmission rate Min.
Page 327 Technical Data 4.1 General System Interface (optional) RS232/RS485/FO Isolated interface for data transfer to a master terminal Profibus DP RS485/ Profibus DP FO DNP3.0/MODBUS RS485 DNP3.0/MODBUS FO Ethernet EN100 Acc. to ordered variant RS232 Connection for flush mounting housing Rear panel, slot „B“, 9-pole D-subminiature female connector For Panel Surface-Mounted Case in console housing at case bottom...
Page 328 Technical Data 4.1 General Profibus DP Fibre Optical Link FOC connector type ST connector; double ring Connection for flush mounting housing Rear panel, mounting location „B“ Connection for surface mounting housing please use version with Profibus RS485 in the console housing as well as separate electri- cal/optical converter.
Page 329 Technical Data 4.1 General Ethernet electrical (EN 100) for IEC 61850 and DIGSI FOC connector type ST connector receiver/transmitter Connection for flush mounting housing Rear panel, mounting location „B“ Connection for surface mounting housing Not deliverable Optical Wavelength λ = 1350 nm Transmission rate 100 Mbit/s Laser class 1 according to...
Page 330: Electrical Tests
Technical Data 4.1 General 4.1.5 Electrical Tests Specifications Standards: IEC 60255 (product standards) IEEE Std C37.90.0/.1/.2 UL 508 VDE 0435 For more standards see also individual functions Insulation test Standards: IEC 60255-5 and IEC 60870-2-1 High voltage test (routine test) 2.5 kV (rms), 50 Hz all circuits except power supply, binary inputs, and com- munication / time sync.
Page 331: Mechanical Tests
Technical Data 4.1 General Line conducted HF, amplitude modulated 10 V; 150 kHz to 80 MHz; 80 % AM; 1 kHz IEC 61000-4-6, Class III Power system frequency magnetic field IEC 60255-6 0,5 mT; 50 Hz, IEC 61000-4-8, Class IV 30 A/m continuous;...
Page 332: Climatic Stress Tests
Technical Data 4.1 General Vibration and Shock Resistance during Transport Standards: IEC 60255-21 and IEC 60068 Oscillation Sinusoidal IEC 60255-21-1, Class 2 5 Hz to 8 Hz: ± 7.5 mm Amplitude; IEC 60068-2-6 8 Hz to 150 Hz: 2 g acceleration frequency sweep 1 octave/min 20 cycles in 3 orthogonal axes Shock...
Page 333: Deployment Conditions
Technical Data 4.1 General 4.1.8 Deployment Conditions The protection device is designed for installation in normal relay rooms and plants, so that electromagnetic immunity is ensured if installation is done properly. In addition the following is recommended: • Contacts and relays operating within the same cabinet or on the same relay board with digital protection equipment, should be in principle provided with suitable surge suppression components.
Page 334: Protection Data Interfaces And Differential Protection Topology
Technical Data 4.2 Protection Data Interfaces and differential protection topology Protection Data Interfaces and differential protection topology Differential Protection Topology Number of devices for one protected object (=number of ends delimited by the current transformer) Protection Data Interfaces Number Connection optical fibre Mounting location „D“...
Page 335 Technical Data 4.2 Protection Data Interfaces and differential protection topology Distance, maximum 3.5 km or 2.2 miles Connector Type ST connector Optical wavelength λ = 820 nm Fibre Type Multimode 62.5 μm/125 μm Transmit output (avg) Min. Type 50 μm /125 μm, NA = 0.2 -18.0 dBm -15.0 dBm 62.5 μm /125 μm, NA = 0.275...
Page 336 Technical Data 4.2 Protection Data Interfaces and differential protection topology FO18 Distance, maximum 60 km or 37,3 miles Connector Type LC duplex connector, SFF (IEC 61754–20 Standard) Protocol full-duplex Baudrate 155 MBits/s Receiver interfacing Optical wavelength λ = 1300 nm Fibre Type Monomode 9 µm/125 µm Transmit output coupled in Monomodefaster...
Page 337 Technical Data 4.2 Protection Data Interfaces and differential protection topology Protection Data Communication Direct connection: Transmission rate 512 kbit/s Fibre Type Optical wavelength siehe Tabellen oben Permissible path attenuation Bridgeable distance Connection via communication networks: Communication converter see Appendix A.1, Section Accessories Supported network interfaces G703.1 with 64 kbit/s G703-T1 with 1.455 Mbit/s...
Page 338: Differential Protection
Technical Data 4.3 Differential Protection Differential Protection Pickup Values Differential current, = 1 A 0.10 to 20.00 A Increment 0.01 A I-DIFF> = 5 A 0.50 to 100.00 A Differential current when switching onto a = 1 A 0.10 to 20.00 A Increment 0.01 A fault;...
Page 339 Technical Data 4.3 Differential Protection Self-Restraint Current transformer error at each end of the protected object Ratio between operating accuracy limit factor 1 to 10.00 Increment 0.01 and nominal accuracy limit factor n'/n Transformer error at n'/n 0.5 % to 50.0 % Steps 0.1 % Transformer error at n (class)
Page 340: Restricted Earth Fault Protection
Technical Data 4.4 Restricted Earth Fault Protection Restricted Earth Fault Protection Setting ranges Differential current I > for I = 1 A 0.05 A to 2.00 A Increment 0.01 for I = 5 A 0.25 A to 10.00 A Threshold angle ϕ 100°...
Page 341: Breaker Intertrip And Remote Tripping- Direct Local Trip
Technical Data 4.5 Breaker Intertrip and Remote Tripping- Direct Local Trip Breaker Intertrip and Remote Tripping- Direct Local Trip Breaker Intertrip and Remote Tripping Intertripping of all opposite ends when single-end tripping can be switched on/off External direct trip Operating time, total Approx.
Page 342: Transmission Of Binary Information (Optional)
Technical Data 4.6 Transmission of Binary Information (optional) Transmission of Binary Information (optional) Remote commands Number of possible remote commands The operating times depend on the communication speed. The following data require a transmission rate of 512 kBit/s. The operating times refer to the entire signal path from entry via binary inputs until output of commands via output relays. Operating times, total approx.
Page 343: Instantaneous High-Current Switch-Onto-Fault Protection (Sotf)
Technical Data 4.7 Instantaneous High-Current Switch-onto-Fault Protection (SOTF) Instantaneous High-Current Switch-onto-Fault Protection (SOTF) Pickup High current pickup I>>> for I = 1 A 0.10 A to 15.00 A or ∞ (disabled) Increment 0.01 A for I = 5 A 0.50 A to 75.00 A or ∞ (disabled) High current pickup I>>>>...
Page 344: Backup Time Overcurrent Protection
Technical Data 4.8 Backup Time Overcurrent Protection Backup Time Overcurrent Protection Operating Modes As emergency overcurrent protection or back-up overcurrent protection Backup time overcurrent protection Effective when the differential protection system is blocked (e.g. because of a failure of the device communication) Backup overcurrent protection operates independent of any events Characteristics...
Page 345 Technical Data 4.8 Backup Time Overcurrent Protection Overcurrent Stages Pickup value Iph> for I = 1 A 0.10 A to 25.00 A Increment 0.01 A (phases) or ∞ (ineffective) for I = 5 A 0.50 A to 125.00 A or ∞ (ineffective) Pickup value 3I0>...
Page 346 Technical Data 4.8 Backup Time Overcurrent Protection Inverse Time Stages (IEC) Pickup value Ip> for I = 1 A 0.10 A to 4.00 A Increment 0.01 A (phases) or ∞ (ineffective) for I = 5 A 0.50 A to 20.00 A or ∞...
Page 347 Technical Data 4.8 Backup Time Overcurrent Protection Inverse Time Stages (ANSI) Pickup value Ip>I for I = 1 A 0.10 A to 4.00 A Increment 0.01 A (phases) or ∞ (disabled) for I = 5 A 0.50 A to 20.00 A or ∞...
Page 348 Technical Data 4.8 Backup Time Overcurrent Protection Figure 4-2 Trip time characteristics of inverse time overcurrent stage, acc. IEC (phases and earth) SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 349 Technical Data 4.8 Backup Time Overcurrent Protection Figure 4-3 Trip time characteristics of inverse time overcurrent stage, acc. ANSI/IEEE (phases and earth) SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 350 Technical Data 4.8 Backup Time Overcurrent Protection Figure 4-4 Trip time characteristics of inverse time overcurrent stage, acc. ANSI/IEEE (phases and earth) SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 351: Automatic Reclosure (Optional)
Technical Data 4.9 Automatic Reclosure (optional) Automatic Reclosure (optional) Automatic Reclosures Number of reclosures Max. 8, first 4 with individual settings Type (depending on ordered version) 1-pole, 3-pole or 1-/3-pole Control With pickup or trip command Action times 0.01 s to 300.00 s; ∞ Increments 0.01 s Initiation possible without pickup and action time Different dead times before...
Page 352: Voltage Protection (Optional)
Technical Data 4.10 Voltage Protection (optional) 4.10 Voltage Protection (optional) Phase-earth overvoltages Overvoltage U >> 1.0 V to 170.0 V; ∞ Increments 0.1 V Delay T 0.00 s to 100.00 s; ∞ Increments 0.01 s UPh> Overvoltage U > 1.0 V to 170.0 V; ∞ Increments 0.1 V Delay T 0.00 s to 100.00 s;...
Page 353 Technical Data 4.10 Voltage Protection (optional) Overvoltage negative sequence system U Overvoltage U >> 2.0 V to 220.0 V; ∞ Increments 0.1 V Delay T 0.00 s to 100.00 s; ∞ Increments 0.01 s U2>> Overvoltage U >> 2.0 V to 220.0 V; ∞ Increments 0.1 V Delay T 0.00 s to 100.00 s;...
Page 354 Technical Data 4.10 Voltage Protection (optional) Phase-phase undervoltages Undervoltage U << 1.0 V to 175.0 V Increments 0.1 V PhPh Delay T 0.00 s to 100.00 s; ∞ Increments 0.01 s UPhPh<< Undervoltage U < 1.0 V to 175.0 V Increments 0.1 V PhPh Delay T...
Page 355: Frequency Protection (Optional)
Technical Data 4.11 Frequency Protection (optional) 4.11 Frequency Protection (optional) Frequency Elements Quantity 4, depending on setting effective on f< or f> Pick-up Values f> or f< adjustable for each element For f = 50 Hz 45.50 Hz to 54.50 Hz Increments 0.01 Hz For f = 60 Hz...
Page 356: Circuit Breaker Failure Protection (Optional)
Technical Data 4.12 Circuit Breaker Failure Protection (optional) 4.12 Circuit Breaker Failure Protection (optional) Circuit breaker monitoring Current flow monitoring for I = 1 A 0.05 A to 20.00 A Increments 0.01 A for I = 5 A 0.25 A to 100.00 A Zero sequence current monitoring for I = 1 A...
Page 357: Thermal Overload Protection
Technical Data 4.13 Thermal Overload Protection 4.13 Thermal Overload Protection Setting Ranges Factor k according to IEC 60255-8 0.10 to 4.00 Increments 0.01 Time Constant τ 1.0 min to 999.9 min Increments 0.1 min Thermal Alarm Θ /Θ 50 % to 100 % of the trip overtemperature Increments 1 % Alarm Trip Current Overload I...
Page 358 Technical Data 4.13 Thermal Overload Protection Figure 4-5 Trip time characteristics of the overload protection SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 359: Monitoring Functions
Technical Data 4.14 Monitoring Functions 4.14 Monitoring Functions Measured Values Current sum = | I · I | > SUM.I Threshold · I + SUM. IFACTOR ·Σ | I | - SUM.ILimit for I = 1 A 0.10 A to 2.00 A Increment 0.01 A for I = 5 A...
Page 360: User Defined Functions (Cfc)
Technical Data 4.15 User defined functions (CFC) 4.15 User defined functions (CFC) Function Blocks and their Possible Allocation to the Priority Classes Function Module Explanation Task Level MW_BEARB PLC1_BEARB PLC_BEARB SFS_BEARB ABSVALUE Magnitude Calculation – – – Addition ALARM Alarm clock AND - Gate BLINK Flash block...
Page 361 Technical Data 4.15 User defined functions (CFC) 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 – RS_FF_MEMO Status memory for restart SI_GET_STATUS Information status single point indication, decoder SI_SET_STATUS Single point indication with...
Page 362 Technical Data 4.15 User defined functions (CFC) Device-specific Limits Description Limit Comments Maximum number of concurrent changes to planned inputs When the limit is exceeded, an error per task level message is output by the device. Conse- Chart inputs per task level quently, the device is put into monitoring mode.
Page 363 Technical Data 4.15 User defined functions (CFC) Processing Times in TICKS required by the Individual Elements Individual Element Number of TICKS Block, basic requirement Each input more than 3 inputs for generic modules Connection to an input signal Connection to an output signal Additional for each chart Operating sequence module CMD_CHAIN...
Page 364: Auxiliary Functions
Technical Data 4.16 Additional Functions 4.16 Additional Functions Operational measured values Operational measured values of currents ; 3I in A primary and secondary and in % of I NOperation Tolerance 0.5 % of measured value, or 0.5 % of I Phase angles of currents );...
Page 365 Technical Data 4.16 Additional Functions Operational Indication Buffer Capacity 200 records Fault Logging Capacity 8 faults with a total of max. 600 messages and up to 100 binary signal traces (marks) Fault recording Number of stored faults Max. 8. Storage time maximum of 5 s per fault total of approx.
Page 366 Technical Data 4.16 Additional Functions Time synchronisation/Clock Time synchronisation DCF 77/IRIG-B-Signal Binary Inputs Communication Operating modes of the clock management No. Operating mode Description Internal synchronisation via RTC or Timing Master Internal External synchronisation using system interface (IEC 60870-5-103) or Timing Master IEC 60870-5-103 External synchronisation via IRIG B (telegram format IRIG-B000) or Timing Master Time signal IRIG-B...
Page 367: Dimensions
Technical Data 4.17 Dimensions 4.17 Dimensions 4.17.1 Housing for Panel Flush Mounting or Cubicle Installation Figure 4-6 Dimensions of a device for panel flush mounting or cubicle installation (size SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 368: Panel Surface Mounting
Technical Data 4.17 Dimensions 4.17.2 Panel Surface Mounting Figure 4-7 Dimensions of a device for panel surface mounting (size ■ SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 369: Appendix
Appendix This appendix is primarily a reference for the experienced user. It contains the ordering data, overview and con- nection diagrams, default settings as well as tables with all parameters and information for the device with its maximum extent. Ordering Information and Accessories Terminal Assignments Connection Examples Default Settings...
Page 370: Ordering Information And Accessories
Appendix A.1 Ordering Information and Accessories Ordering Information and Accessories A.1.1 Ordering Information A.1.1.1 Ordering Code (MLFB) 10 11 12 13 14 15 16 Line Differential Protection — — L/M/N Measurement Input Pos. 7 = 1 A, I = 1 A = 5 A, I = 5 A Auxiliary Voltage (Power Supply, Pickup Threshold of Binary Inputs)
Page 371 Appendix A.1 Ordering Information and Accessories Additional Specification L for Further System Interfaces (Port B) Pos. 21 Pos. 22 (only if Pos. 11 = 9) Profibus DP Slave, electrical RS485 Profibus DP Slave, optical, 820 nm, double ring, ST connector MODBUS, electrical RS 485 MODBUS, 820 nm, optical, ST connector DNP 3.0, electrical RS485...
Page 372 Appendix A.1 Ordering Information and Accessories Function 2 Pos. 14 with backup time delay overcurrent protection / emergency overcurrent protection with backup time delay overcurrent protection / emergency overcurrent protection with breaker failure protection C with directional backup time delay overcurrent protection / emergency overcurrent protection with directional backup time delay overcurrent protection / emergency overcurrent protection with breaker failure protection Function 3...
Page 373: Accessories
1 set of optical attenuators (2 pcs) 7XV5107–0AA00 Fibre-optic cables 6XV8100 Fibre-optic cables with different connectors, in different lengths and designs. More information will be avail- able from your local Siemens sales representative. SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 374 Appendix A.1 Ordering Information and Accessories Isolating Transformers Isolating transformers are needed on copper lines if the longitudinal voltage induced in the pilot wires can result in more than 60 % of the test voltage at the communication converter (i.e. 3 kV for CC-CU). They are connected between the communication converter and the communication line.
Page 375 Appendix A.1 Ordering Information and Accessories Exchangeable interface modules Name Order No. RS232 C53207-A351-D641-1 RS485 C73207-A351-D642-1 FO 820 nm C53207-A351-D643-1 Profibus DP RS485 C53207-A351-D611-1 Profibus DP double ring C53207-A351-D613-1 Modbus RS 485 C53207-A351-D621-1 Modbus 820 nm C53207-A351-D623-1 DNP 3.0 RS485 C53207-A351-D631-1 DNP 3.0 820 nm C53207-A351-D633-1...
Page 376 Appendix A.1 Ordering Information and Accessories Short-Circuit Links Short-circuit Links as Jumper Kit Order No. 3 pcs for current terminals + 6 pcs for voltage terminals C73334-A1-C40-1 Plug-in Connector Plug-in Connector Order No. 2-pin C73334-A1-C35-1 3-pin C73334-A1-C36-1 Mounting Brackets for 19" Racks Name Order No.
Page 377: Terminal Assignments
Appendix A.2 Terminal Assignments Terminal Assignments A.2.1 Housing for Panel Flush and Cubicle Mounting 7SD610*-*B/K Figure A-1 General diagram for 7SD610*-*B/K (panel flush mounted or cubicle mounted) SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 378: Housing For Panel Surface Mounting
Appendix A.2 Terminal Assignments A.2.2 Housing for panel surface mounting 7SD610*-*F Figure A-2 Connection diagram for 7SD610*-*F (panel surface mounted) SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 379: Connection Examples
Appendix A.3 Connection Examples Connection Examples A.3.1 Current Transformer Connection Examples Figure A-3 Current connections to three current transformers with a starpoint connection for earth current (residual 3I0 neutral current), normal circuit layout Figure A-4 Current connections to three current transformers with separate earth current transformer (summation current transformer or toroidal current transformer) Important! The cable shield must be earthed on the cable side.
Page 380 Appendix A.3 Connection Examples Figure A-5 Restricted earth fault protection on an earthed transformer winding Figure A-6 Restricted earth fault protection on a non-earthed transformer winding with neutral reactor SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 381: Voltage Transformer Examples
Appendix A.3 Connection Examples A.3.2 Voltage Transformer Examples Figure A-7 Voltage connections to three wye-connected voltage transformers (normal circuit layout) Figure A-8 Voltage connections to three wye-connected voltage transformers with additional broken delta windings (da–dn–winding) SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 382: Default Settings
Appendix A.4 Default Settings Default Settings A.4.1 LEDs Table A-1 LED Indication Presettings LEDs Allocated Func- Function No. Description tion LED1 Relay TRIP Relay GENERAL TRIP command LED2 Relay PICKUP L1 Relay PICKUP Phase L1 LED3 Relay PICKUP L2 Relay PICKUP Phase L2 LED4 Relay PICKUP L3 Relay PICKUP Phase L3...
Page 383: Function Keys
Appendix A.4 Default Settings A.4.4 Function Keys Table A-4 Applies to all devices and ordered variants Function Keys Allocated Function Display of Operational Annunciations Operating Measured Values, Primary An overview of the last eight network faults Not pre-assigned A.4.5 Default Display 4-line Display Table A-5 This selection is available as start page which may be configured.
Page 384: Pre-Defined Cfc Charts
Appendix A.4 Default Settings A.4.6 Pre-defined CFC Charts Device and System Logic A negator block of the slow logic (PLC1-BEARB) is created from the binary input „>DataStop“ into the internal single point indication „Unblock DT“. Figure A-9 Logical Link between Input and Output SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 385: Protocol-Dependent Functions
Appendix A.5 Protocol-dependent Functions Protocol-dependent Functions Protocol → IEC 60870-5-103 IEC 61850 Profibus DP DNP 3.0 Ethernet MODBUS Function ↓ (EN100) Operational measured values Metered values Fault recording No, only via No, only via additional additional service interface service interface Remote relay setting No, only via No, only via...
Page 386: Functional Scope
Appendix A.6 Functional Scope Functional Scope Addr. Parameter Setting Options Default Setting Comments Grp Chge OPTION Disabled Disabled Setting Group Change Option Enabled Trip mode 3pole only 3pole only Trip mode 1-/3pole DIFF.PROTECTION Enabled Enabled Differential protection Disabled DTT Direct Trip Disabled Disabled DTT Direct Transfer Trip...
Page 387: Settings
Appendix A.7 Settings Settings Addresses which have an appended "A" can only be changed with DIGSI, under Additional Settings. The table indicates region-specific presettings. Column C (configuration) indicates the corresponding second- ary nominal current of the current transformer. Addr. Parameter Function Setting Options Default Setting...
Page 388 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments FltDisp.LED/LCD Device Target on PU Target on PU Fault Display on LED / LCD Target on TRIP 625A T MIN LED HOLD Device 0 .. 60 min; ∞ 0 min Minimum hold time of lachted LEDs Start image DD...
Page 389 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 1210 I-DIFF> Diff. Prot 0.10 .. 20.00 A 0.30 A I-DIFF>: Pickup value 0.50 .. 100.00 A 1.50 A 1213 I-DIF>SWITCH ON Diff. Prot 0.10 .. 20.00 A 0.30 A I-DIFF>: Value under switch on condition 0.50 ..
Page 390 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 2614 I>> Telep/BI Back-Up O/C Instantaneous trip via Tele- prot./BI 2615 I>> SOTF Back-Up O/C Instantaneous trip after Switch- OnToFault 2620 Iph> Back-Up O/C 0.05 .. 50.00 A; ∞ 1.50 A Iph>...
Page 391 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 2686 I>Dir.Telep/BI Back-Up O/C Instantaneous trip via Tele- prot./BI 2687 I> Dir. SOTF Back-Up O/C Instantaneous trip after Switch- OnToFault 2688 Direction IP Back-Up O/C Forward Forward Direction of stage Ip> Dir. Reverse 2689 Ip>...
Page 392 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 2933 FAST Σ i SUPERV Measurem.Superv State of fast current summation supervis 2935A ΔI min Measurem.Superv 0.05 .. 1.00 A 0.10 A Min. current diff. for wire break det. 0.25 ..
Page 393 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 3455 1.AR Tdead 3Flt Auto Reclose 0.01 .. 1800.00 sec; ∞ 0.50 sec Dead time after 3phase faults 3456 1.AR Tdead1Trip Auto Reclose 0.01 .. 1800.00 sec; ∞ 1.20 sec Dead time after 1pole trip 3457 1.AR Tdead3Trip...
Page 394 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 3621 O/U FREQ. f3 Frequency Prot. ON: Alarm only ON: Alarm only Over/Under Frequency Protec- ON: with Trip tion stage f3 3622 f3 PICKUP Frequency Prot. 45.50 .. 54.50 Hz 47.50 Hz f3 Pickup 3623...
Page 395 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 3749A U2>(>) RESET Voltage Prot. 0.30 .. 0.99 0.98 U2>(>) Reset ratio 3751 Uph-e<(<) Voltage Prot. Operating mode Uph-e under- Alarm Only voltage prot. U<Alarm U<<Trip 3752 Uph-e< Voltage Prot. 1.0 ..
Page 396 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 3932 T-PoleDiscrep. Breaker Failure 0.00 .. 30.00 sec; ∞ 2.00 sec Trip delay with pole discrepancy 4001 FCT TripSuperv. TripCirc.Superv TRIP Circuit Supervision is 4002 No. of BI TripCirc.Superv 1 ..
Page 397: Information List
Appendix A.8 Information List 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. The function type of Differential Protection 7SD610 regarding IEC 60 870-5-103 refers to as “compatible func- tion type 192”...
Page 398 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio Setting Group C is active (P- Change Group IntSP GrpC act) Setting Group D is active (P- Change Group IntSP GrpD act) Fault Recording Start (FltRecSta) Osc.
Page 399 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio >Cabinet door open (>Door Process Data LED BI open) >CB waiting for Spring charged Process Data LED BI (>CB wait) >Error Motor Voltage (>Err Mot Process Data LED BI >Error Control Voltage (>ErrCntr-...
Page 400 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio Reset LED (Reset LED) Device OUT_ Resume (Resume) Device Clock Synchronization Error Device (Clock SyncError) Daylight Saving Time (DayLight- Device SavTime) Setting calculation is running Device (Settings Calc.) Settings Check (Settings Check) Device...
Page 401 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio Error: A/D converter (Error A/D- Device conv.) Error Board 1 (Error Board 1) Device Error Board 2 (Error Board 2) Device Error Board 3 (Error Board 3) Device Error Board 4 (Error Board 4) Device...
Page 402 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio Warn: Limit of Memory Data ex- Device ceeded (Warn Mem. Data) Warn: Limit of Memory Parameter Device exceeded (Warn Mem. Para.) Warn: Limit of Memory Operation Device exceeded (Warn Mem.
Page 403 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio Relay PICKUP Earth (Relay P.System Data 2 PICKUP E) Relay TRIP command Phase L1 P.System Data 2 (Relay TRIP L1) Relay TRIP command Phase L2 P.System Data 2 (Relay TRIP L2) Relay TRIP command Phase L3...
Page 404 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 1002 Number of breaker TRIP com- Statistics mands L2 (TripNo L2=) 1003 Number of breaker TRIP com- Statistics mands L3 (TripNo L3=) 1027 Accumulation of interrupted Statistics...
Page 405 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 1493 BF Trip in case of defective CB Breaker Failure (BF TRIP CBdefec) 1494 BF Trip T2 (busbar trip) (BF T2- Breaker Failure TRIP(bus)) 1495 BF Trip End fault stage (BF...
Page 406 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 2737 >AR: Block 1pole AR-cycle Auto Reclose LED BI (>BLOCK 1pole AR) 2738 >AR: Block 3pole AR-cycle Auto Reclose LED BI (>BLOCK 3pole AR) 2739 >AR: Block 1phase-fault AR- Auto Reclose...
Page 407 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 2821 AR dead time after evolving fault Auto Reclose on off (AR Td. evol.Flt) 2839 AR dead time after 1pole trip Auto Reclose running (AR Tdead 1pTrip) 2840 AR dead time after 3pole trip...
Page 408 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 2897 No. of higher AR-cycle CLOSE Statistics commands,1p (AR #Close2./1p=) 2898 No. of higher AR-cycle CLOSE Statistics commands,3p (AR #Close2./3p=) 3102 Diff: 2nd Harmonic detected in Diff.
Page 409 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 3183 Diff: Fault detection L3E (Diff Flt. Diff. Prot L3E) 3184 Diff: Fault detection L31 (Diff Flt. Diff. Prot L31) 3185 Diff: Fault detection L31E (Diff Flt. Diff.
Page 410 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 3250 GPS:PI1 unsym.propagation Prot. Interface delay too high (PI 1 PD unsym.) 3252 > PI1 Synchronization RESET Prot. Interface LED BI (>SYNC PI1 RESET) 3254 Prot.1: Delay time change recog- Prot.
Page 411 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 3502 I.Trip: >Intertrip L2 signal input Intertrip LED BI (>Intertrip L2) 3503 I.Trip: >Intertrip L3 signal input Intertrip LED BI (>Intertrip L3) 3504 I.Trip: >Intertrip 3 pole signal Intertrip...
Page 412 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 3550 >Remote Signal 2 input Remote Signals LED BI (>Rem.Signal 2) 3551 >Remote Signal 3 input Remote Signals LED BI (>Rem.Signal 3) 3552 >Remote Signal 4 input Remote Signals...
Page 413 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 3578 Remote signal 6 received Remote Signals (Rem.Sig 6recv) 3579 Remote signal 7 received Remote Signals (Rem.Sig 7recv) 3580 Remote signal 8 received Remote Signals (Rem.Sig 8recv) 3581...
Page 414 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 4285 High Speed-O/C Pickup I>>>> L1 SOTF Overcurr. (I>>>>O/C p.upL1) 4286 High Speed-O/C Pickup I>>>> L2 SOTF Overcurr. (I>>>>O/C p.upL2) 4287 High Speed-O/C Pickup I>>>> L3 SOTF Overcurr.
Page 415 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 5212 Frequency protection is Frequency Prot. on off BLOCKED (Freq. BLOCKED) 5213 Frequency protection is ACTIVE Frequency Prot. (Freq. ACTIVE) 5215 Frequency protection undervolt- Frequency Prot.
Page 416 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 6858 >Trip circuit superv. 3: Trip Relay TripCirc.Superv LED BI (>TripC3 TripRel) 6859 >Trip circuit superv. 3: Breaker TripCirc.Superv LED BI Relay (>TripC3 Bkr.Rel) 6861 Trip circuit supervision OFF TripCirc.Superv...
Page 417 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 7165 Backup O/C PICKUP EARTH Back-Up O/C (O/C Pickup E) 7171 Backup O/C Pickup - Only Back-Up O/C EARTH (O/C PU only E) 7172 Backup O/C Pickup - Only L1 Back-Up O/C...
Page 418 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 7222 Backup O/C TRIP I> (O/C TRIP Back-Up O/C I>) 7223 Backup O/C TRIP Ip (O/C TRIP Back-Up O/C 7235 O/C I-STUB TRIP (I-STUB TRIP) Back-Up O/C 7236 Backup O/C TRIP I>...
Page 419 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 10202 >BLOCK Uph-ph>(>) Overvolt Voltage Prot. LED BI (phase-phase) (>Uph-ph>(>) BLK) 10203 >BLOCK 3U0>(>) Overvolt. (zero Voltage Prot. LED BI sequence) (>3U0>(>) BLK) 10204 >BLOCK U1>(>) Overvolt.
Page 420 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 10243 Uph-e>(>) Pickup L2 (Uph-e>(>) Voltage Prot. on off PU L2) 10244 Uph-e>(>) Pickup L3 (Uph-e>(>) Voltage Prot. on off PU L3) 10245 Uph-e>...
Page 421 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 10274 3U0>(>) TRIP command Voltage Prot. (3U0>(>) TRIP) 10280 U1> Pickup (U1> Pickup) Voltage Prot. on off 10281 U1>> Pickup (U1>> Pickup) Voltage Prot.
Page 422 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 10328 Uphph<(<) Pickup L2-L3 (Uph- Voltage Prot. on off ph<(<)PU L23) 10329 Uphph<(<) Pickup L3-L1 (Uph- Voltage Prot. on off ph<(<)PU L31) 10330 Uphph<...
Page 423 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 30053 Fault recording is running (Fault Osc. Fault Rec. rec. run.) 31000 Q0 operationcounter= (Q0 Control Device OpCnt=) 31001 Q1 operationcounter= (Q1 Control Device OpCnt=) 31002...
Page 424: Group Alarms
Appendix A.9 Group Alarms Group Alarms Description Function No. Description Error Sum Alarm Error 5V Error1A/5Awrong Error A/D-conv. Alarm Sum Event Failure Σi Fail I balance Fail Σ U Ph-E Fail U balance Fail U absent VT FuseFail>10s VT FuseFail Fail Ph.
Page 425: Measured Values
Appendix A.10 Measured Values A.10 Measured Values Description Function IEC 60870-5-103 Configurable in Matrix Lower setting limit for Power Factor (PF<) Set Points(MV) I L1 (IL1 =) Measurement I L2 (IL2 =) Measurement I L3 (IL3 =) Measurement 3I0 (zero sequence) (3I0 =) Measurement IY (star point of transformer) (IY =) Measurement...
Page 426 Appendix A.10 Measured Values Description Function IEC 60870-5-103 Configurable in Matrix 7738 PHI UIL2 (local) (Φ UIL2=) Measurement 7739 PHI UIL3 (local) (Φ UIL3=) Measurement 7742 IDiffL1(% Operational nominal current) IDiff/IRest (IDiffL1=) 7743 IDiffL2(% Operational nominal current) IDiff/IRest (IDiffL2=) 7744 IDiffL3(% Operational nominal current) IDiff/IRest (IDiffL3=)
Page 427 Appendix A.10 Measured Values Description Function IEC 60870-5-103 Configurable in Matrix 7793 UL3(% of Operational nominal voltage) Measure relay2 (UL3_opN=) 7794 Angle UL3_rem <-> UL3_loc (ΦU L3=) Measure relay2 7875 Prot.Interface 1:Transmission delay rec. (PI1 Statistics TD R) 7876 Prot.Interface 1:Transmission delay send Statistics (PI1 TD S) 30654...
Page 428 Appendix A.10 Measured Values SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 429: Literature
Literature SIPROTEC 4 System Description; E50417-H1100-C151-B2 SIPROTEC DIGSI, Start Up; E50417-G1176-C152-A3 DIGSI CFC, Manual; E50417-H1176-C098-A9 SIPROTEC SIGRA 4, Manual; E50417-H1100-C070-A4 Digital Distance Protection: Basics and Applications; Edition: 2. completely revised and extended version (May 14, 2008); Language: German ISBN-10: 389578320X, ISBN-13: 987-3895783203 Application Examples for SIPROTEC Protection Devices, E50001-K4451-A101-A1 Case Studies for SIPROTEC Protection Devices and Power Quality;...
Page 430 Literature SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 431: Glossary
Glossary Battery The buffer battery ensures that specified data areas, flags, timers and counters are retained retentively. Bay controllers Bay controllers are devices with control and monitoring functions without protective functions. Bit pattern indication Bit pattern indication is a processing function by means of which items of digital process information applying across several inputs can be detected together in parallel and processed further.
Page 432 Glossary Combination matrix From DIGSI V4.6 onward, up to 32 compatible SIPROTEC 4 devices can communicate with one another in an Inter Relay Communication combination (IRC combination). Which device exchanges which information is defined with the help of the combination matrix. Communication branch A communications branch corresponds to the configuration of 1 to n users that communicate by means of a common bus.
Page 433 Glossary Double command Double commands are process outputs which indicate 4 process states at 2 outputs: 2 defined (for example ON/OFF) and 2 undefined states (for example intermediate positions) Double-point indication Double-point indications are items of process information which indicate 4 process states at 2 inputs: 2 defined (for example ON/OFF) and 2 undefined states (for example intermediate positions).
Page 434 Glossary External command without feedback via an ETHERNET connection, device-specific ExCF External command with feedback via an ETHERNET connection, device-specific ExDP External double point indication via an ETHERNET connection, device-specific → Double point indication ExDP_I External double point indication via an ETHERNET connection, intermediate position 00, device-specific → Double point indication ExMV External metered value via an ETHERNET connection, device-specific...
Page 435 Glossary GOOSE message GOOSE messages (Generic Object Oriented Substation Event) are data packets which are transferred event- controlled via the Ethernet communication system. They serve for direct information exchange among the relays. This mechanism implements cross-communication between bay units. Global Positioning System. Satellites with atomic clocks on board orbit the earth twice a day on different paths in approx.
Page 436 Glossary IEC61850 International communication standard for communication in substations. The objective of this standard is the interoperability of devices from different manufacturers on the station bus. An Ethernet network is used for data transfer. Initialization string An initialization string comprises a range of modem-specific commands. These are transmitted to the modem within the framework of modem initialization.
Page 437 Glossary Limit value Limit value, user-defined Master Masters may send data to other users and request data from other users. DIGSI operates as a master. Metered value Metered values are a processing function with which the total number of discrete similar events (counting pulses) is determined for a period, usually as an integrated value.
Page 438 Glossary 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. Object Each element of a project structure is called an object in DIGSI. Object properties Each object has properties.
Page 439 Glossary PROFIBUS address Within a PROFIBUS network a unique PROFIBUS address has to be assigned to each SIPROTEC 4 device. A total of 254 PROFIBUS addresses are available for each PROFIBUS network. 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.
Page 440 Glossary SICAM PAS (Power Automation System) Substation control system: The range of possible configurations spans from integrated standalone systems (SICAM PAS and M&C with SICAM PAS CC on one computer) to separate hardware for SICAM PAS and SICAM PAS CC to distributed systems with multiple SICAM Station Units. The software is a modular system with basic and optional packages.
Page 441 Glossary Transient information A transient information is a brief transient → single-point indication at which only the coming of the process signal is detected and processed immediately. Tree view 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 442 Glossary SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...
Page 443: Index
Index Service interface 289 Switching the configured resources 318 AC voltage 323 Time Synchronisation Interface 291 Acknowledgement of commands 266 Check: System Connections 293 Adaptive Dead Time 351 Check: System interface 290 Adaptive dead time (ADT) 143 Checking a Connection 303 Alarm levels 197 Checking: Analog inputs and outputs 322...
Page 444 Index Communication media 50 Tolerances 67 Configuration of auto-reclosure 143 Topology 334 Configuring the functional scope 31 Tripping logic 72 Consistency Direct connection 50 Parameterisation 305 Direct Voltage 323 Topology 305 Display of measured values 251 Constructive versions 333 Control Logic 264 Control Voltage 277 Control Voltage for Binary Inputs 274 Control Voltages of BI1 to BI5 277...
Page 445 Index Frequency measurement 172 Frequency stages 172 k-factor 196 Operating ranges 172 Overfrequency protection 172 Pickup values 175 Pickup/tripping 173 Power swings 173 Limits for CFC blocks 361 Underfrequency protection 172 Limits for user-defined functions 361 Function Blocks 360 Line energization recognition 222 Function Control 222 Live Contact 274 Fuse Failure Monitor 206, 215...
Page 446 Index Overtemperature 198 Remote tripping 80 Overvoltage protection 153 Replacing Interfaces 275 Compounding 156 Requirements for current transformers 322 Reset of Stored LED / Relays 238 Negative sequence system U 157, 165, 353 Optional single-phase voltage 353 Restraint current values 254 Phase-earth 352 Restricted Earth Fault Protection 25 Phase-phase 154, 352...
Page 447 Index Indication Direction 298 Trips 249 LEDs 301 Two-stage circuit breaker failure protection 190 Output Relays 300 Type of Commands 260 Signal Transmission (int., ext. Remote Tripping) 317 Switching States of the Binary Inputs/Outputs 299 System Interface 297 Testing: Time Synchronisation Interface 296 Undervoltage protection User-defined Functions 318 Phase-earth 160, 353...
Page 448 Index SIPROTEC, 7SD610, Manual C53000-G1176-C145-6, Release date 02.2011...

Siemens SIPROTEC 7SD610 Manual

1 Introduction

2 Functions

3 Mounting and Commissioning

4 Technical Data

Appendix

Literature

Glossary

Index

Quick Links

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Summary of Contents for Siemens SIPROTEC 7SD610