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Siemens SIPROTEC 7UM62 Manual

Multifunctional machine protection
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Table of Contents

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SIPROTEC
Multifunctional Machine
Protection
7UM62
V4.6
Manual
C53000-G1176-C149-7
Preface
Contents
Introduction
Functions
Mounting and Commissioning
Technical Data
Appendix
Literature
Glossary
Index
1
2
3
4
A

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Summary of Contents for Siemens SIPROTEC 7UM62

  • Page 1 Preface Contents Introduction SIPROTEC Functions Multifunctional Machine Mounting and Commissioning Protection 7UM62 Technical Data Appendix V4.6 Literature Manual Glossary Index C53000-G1176-C149-7...
  • Page 2 SIPROTEC, SINAUT, SICAM and DIGSI are registered trademarks Document Version V04.63.00 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 03.2010 fringe the rights of the owner.
  • Page 3 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 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 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................21 Overall Operation.
  • Page 10 Contents Definite-Time Overcurrent Protection (I>, ANSI 50/51) with Undervoltage Seal-In....65 2.8.1 Function Description ............65 2.8.2 Setting Notes .
  • Page 11 Contents 2.15 Earth Current Differential Protection (ANSI 87GN,TN) ........128 2.15.1 Function Description .
  • Page 12 Contents 2.23 Frequency Protection (ANSI 81) ........... . . 181 2.23.1 Functional Description .
  • Page 13 Contents 2.31 100-%-Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G - 100%) ... .223 2.31.1 Function Description ............223 2.31.2 Setting Notes .
  • Page 14 Contents 2.39 Inadvertent Energization (ANSI 50, 27) ..........268 2.39.1 Functional Description .
  • Page 15 Contents 2.46 Temperature Detection by Thermoboxes..........316 2.46.1 Function Description .
  • Page 16 Contents 2.50 Command Processing............. 349 2.50.1 Control Device.
  • Page 17 Contents Commissioning ..............400 3.3.1 Test Mode / Transmission Block .
  • Page 18 Contents 4.10 Underexcitation (Loss-of-Field) Protection (ANSI 40) ........482 4.11 Reverse Power Protection (ANSI 32R) .
  • Page 19 Contents 4.39 Dimensions ..............525 4.39.1 Panel Flush and Cubicle Mounting (Housing Size ) .
  • Page 20 Contents A.10 Measured Values ..............616 Literature.

  • Page 21: Introduction

    Introduction This chapter introduces the SIPROTEC 4 7UM62. It provides an overview of the scopes of application, features and of the functional scope. Overall Operation Application Scope Characteristics SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 22: Overall Operation

    Introduction 1.1 Overall Operation Overall Operation The digital multifunctional protective relay 7UM62 is equipped with a high performance microprocessor. All tasks such as the acquisition of the measured values and issuing of commands to circuit breakers and other switching equipment are processed digitally. Figure 1-1 shows the basic structure of the device. Analog Inputs The measuring inputs (MI) section effect a gavanic isolation.
  • Page 23 Introduction 1.1 Overall Operation The device has 8 current and 4 voltage inputs. Three current inputs are used on each side of the protected object for measuring of the phase currents. 2 current inputs are equipped with sensitive input transformers (I and can measure secondary currents in the mA range.
  • Page 24 Introduction 1.1 Overall Operation Front Elements Light-emitting diodes (LEDs) and a display (LCD) on the front panel provide information on the functional status of the device and report events, states and measured values. The integrated control keys and numeric keys in conjunction with the LCD enable local interaction with the device.

  • Page 25: Application Scope

    Introduction 1.2 Application Scope Application Scope The SIPROTEC 4 7UM62 is a numerical machine protection unit from the „7UM6 Numerical Protection“ series. It provides all functions necessary for protection of generators, motors and transformers. As the scope of func- tions of the 7UM62 can be customized, it is suited for small, medium-sized and large generators. The device fulfills the protection requirements for the two typical basic connections: •...
  • Page 26 Introduction 1.2 Application Scope Messages and Measured Values; Recording of Event and Fault Data The operational indications provide information about conditions in the power system and the device itself. Measurement quantities and resulting computed values can be displayed locally and communicated via the serial interfaces.

  • Page 27: Characteristics

    Introduction 1.3 Characteristics Characteristics General Features • Powerful 32-bit microprocessor system. • Complete digital processing of measured values and control, from sampling and digitalization of measured quantities to tripping circuit breakers or other switchgear devices. • Total galvanic and disturbance-immune separation between the internal processing stages of the device and the measuring, control and supply circuits of the system using measurement transducers, binary input and output modules and and the DC converters.
  • Page 28 Introduction 1.3 Characteristics Thermal Overload Protection 49 • Temperature image of current heat losses (overload protection with full memory capability, single body thermal model). • Additional adjustable warning levels based on temperature rise and current magnitude. • Consideration of coolant and ambient temperatures possible. Negative Sequence Protection 46-1, 46-2, 46-TOC •...
  • Page 29 Introduction 1.3 Characteristics Reverse Power Protection • Calculation of power from positive sequence components. • Highly sensitive and precise active power measurement (detection of small motoring powers even with low power factor cos ϕ, angle error compensation). • Insensitive to power fluctuations. •...
  • Page 30 Introduction 1.3 Characteristics Frequency Protection 81 O/U • Monitoring on undershooting (f<) and/or overshooting (f>) with 4 frequency limits and delay times that are independently adjustable. • Insensitive to harmonics and abrupt phase angle changes. • Settable undervoltage threshold. Overexcitation Protection •...
  • Page 31 Introduction 1.3 Characteristics 100 % Stator Earth Fault Protection with 20 Hz Bias Voltage • Evaluation of the 20 Hz measurement (7XT33 and 7XT34). • Warning and trip stage R< and R<<. • Trip stage with earth current. • High sensitivity also with large stator earth capacitances. Earth Current Protection B •...
  • Page 32 Introduction 1.3 Characteristics Restart Inhibit for Motors 66 • Approximate computation of rotor overtemperature. • Startup is permitted only if the rotor has sufficient thermal reserves for a complete startup • Calculation of waiting time until restarting is enabled. • Different prolongation of cooldown time constants for standstill/operation period is taken into consideration. •...
  • Page 33 Introduction 1.3 Characteristics User-defined Functions • Internal and external signals can be logically combined to establish user-defined logic functions. • All common logic functions (AND, OR, NOT, Exclusive OR, etc.). • Time delays and limit value interrogations. • Processing of measured values, including zero suppression, adding a knee characteristic for a transducer input, and live-zero monitoring.
  • Page 34 Introduction 1.3 Characteristics SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 35: Functions

    Functions This chapter describes the individual functions of the SIPROTEC 4 device 7UM62. It shows the setting possi- bilities 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. Introduction, Reference Power System Device Ethernet EN100 Modul...
  • Page 36 Functions 2.26 Rate-of-Frequency-Change Protection df/dt (ANSI 81R) 2.27 Jump of Voltage Vector 2.28 90-%-Stator Earth Fault Protection (ANSI 59N, 64G, 67G) 2.29 Sensitive Earth Fault Protection (ANSI 51GN, 64R) 2.30 100-%-Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) 2.31 100-%-Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G - 100%) 2.32...

  • Page 37: Introduction, Reference Power System

    Functions 2.1 Introduction, Reference Power System Introduction, Reference Power System The following section will explain the individual protection and additional functions and provide information about the setting values. 2.1.1 Functional Description Generator The calculation examples are based on two reference power systems with the two typical basic configurations busbar connection and unit connection.
  • Page 38 Functions 2.1 Introduction, Reference Power System Technical Data of the Reference Power Systems Generator = 5.27 MVA N, G = 6.3 kV N, G = 483 A N, G cos ϕ = 0.8 Current transformer: = 500 A; = 1 A N,prim N, sec Toroidal c.t.:...

  • Page 39: Device

    Functions 2.2 Device Device The device can issue a serie of general annunciations about itself and the substation. These annunciations are listed in the following information list. Most annunciations are self-explanatory. The special cases are described below: Reset: Device is reset on each Power ON. Initial Start: Initial start occurs after initialization of the device by DIGSI.

  • Page 40: Settings

    Functions 2.2 Device Note Setting address 610 FltDisp.LED/LCD to (Target on TRIP) is only reasonable if address 615 T MIN LED HOLD is set to 0. Figure 2-3 Creation of the resetting command for stored LEDs / relays Default display of a 4-line display After startup of the device featuring a 4-line display, measured values are displayed by default.

  • Page 41: Information List

    Functions 2.2 Device 2.2.3 Information List Information Type of In- Comments formation Reset LED IntSP Reset LED Test mode IntSP Test mode DataStop IntSP Stop data transmission UnlockDT IntSP Unlock data transmission via BI >Light on >Back Light on SynchClock IntSP_Ev Clock Synchronization HWTestMod...

  • Page 42: Ethernet En100 Modul

    Functions 2.3 Ethernet EN100 Modul Ethernet EN100 Modul 2.3.1 Functional Description An Ethernet EN100 Modul allows to integrate the 7UM62 into 100 Mbit Ethernet communication networks used by process control and automation systems and running IEC 61850 protocols. This standard provides consistent inter-relay communication without gateways or protocol converters.

  • Page 43: Functional Scope

    Functions 2.4 Functional Scope Functional Scope The 7UM62 device incorporates numerous protection and supplementary functions. The hardware and firm- ware provided is designed for this scope of functions. Nevertheless a few restrictions apply to the use of the earth fault current and earth fault voltage inputs I and U respectively.

  • Page 44: Setting Notes

    Functions 2.4 Functional Scope 2.4.2 Setting Notes Peculiarities Most settings are self-explanatory. The special cases are described below. If the setting group change function has to be used, address 103 Grp Chge OPTION must be set to enabled. In this case, it is possible to apply two groups of settings for function parameters (refer also to Section 2.6) al- lowing convenient and fast switch-over between these setting groups.
  • Page 45 Functions 2.4 Functional Scope Protection function Side 1 Side 2 L1S1 L2S1 L1S2 L2S2 L3S1 L3S2 Out-of-Step Protection (ANSI 78) Fixed – – – Fixed – – Undervoltage Protection Fixed – – – – – – Overvoltage Protection Fixed – –...
  • Page 46 Functions 2.4 Functional Scope Figure 2-4 Use as Generator Differential Protection Figure 2-5 Use as Block Differential Protection (Overall Protection) For the following application, the settings of the generator data under P.System Data 1 must be same as for the transformer data of side 2: Figure 2-6 Use as Transformer Differential Protection For the following application, the differential protection of device A must be set to Generator/Motor, in the...
  • Page 47 Functions 2.4 Functional Scope Figure 2-7 Use as Redundant Overall Protection For earth fault protection, Address 150 S/E/F PROT. presents the options non-dir. U0, non-dir. U0&I0 and directional, unless the whole function is Disabled. The first option evaluates only the displacement voltage (to be used with unit connection).

  • Page 48: Settings

    Functions 2.4 Functional Scope 2.4.3 Settings Addr. Parameter Setting Options Default Setting Comments Grp Chge OPTION Disabled Disabled Setting Group Change Option Enabled FAULT VALUE Disabled Instant. values Fault values Instant. values RMS values O/C PROT. I> Disabled Side 2 Overcurrent Protection I>...
  • Page 49 Functions 2.4 Functional Scope Addr. Parameter Setting Options Default Setting Comments INV.UNDERVOLT. Disabled Enabled Inverse Undervoltage Protection Enabled Up< df/dt Protect. Disabled 2 df/dt stages Rate-of-frequency-change protec- 2 df/dt stages tion 4 df/dt stages VECTOR JUMP Disabled Enabled Jump of Voltage Vector Enabled S/E/F PROT.
  • Page 50 Functions 2.4 Functional Scope Addr. Parameter Setting Options Default Setting Comments ANALOGOUTP B1/1 Disabled Disabled Analog Output B1/1 (Port B) I1 [%] I2 [%] IEE1 [%] IEE2 [%] U1 [%] U0 [%] U03H [%] |P| [%] |Q| [%] |S| [%] f [%] U/f [%] PHI [%]...
  • Page 51 Functions 2.4 Functional Scope Addr. Parameter Setting Options Default Setting Comments ANALOGOUTP D1/1 Disabled Disabled Analog Output D1/1 (Port D) I1 [%] I2 [%] IEE1 [%] IEE2 [%] U1 [%] U0 [%] U03H [%] |P| [%] |Q| [%] |S| [%] f [%] U/f [%] PHI [%]...
  • Page 52 Functions 2.4 Functional Scope Addr. Parameter Setting Options Default Setting Comments RTD-BOX INPUT Disabled Disabled External Temperature Input Port C Port D RTD CONNECTION 6 RTD simplex 6 RTD simplex Ext. Temperature Input Connec- 6 RTD HDX tion Type 12 RTD HDX ANALOGOUTP B1/2 Disabled Disabled...

  • Page 53: Power System Data 1

    Functions 2.5 Power System Data 1 Power System Data 1 The device requires some plant and power system data to adapt its functions to the actual application. These include, for instance, rated power system and transformer data, measured quantity polarities and connection, breaker properties etc.
  • Page 54 Functions 2.5 Power System Data 1 Figure 2-9 Current transformer starpoints in transverse differential protection - Example Nominal Values of the Transformers on Side 1 At addresses 202 IN-PRI I-SIDE1 and 203 IN-SEC I-SIDE1 information is entered regarding the primary and secondary nominal currents of the CTs of side 1.
  • Page 55 Functions 2.5 Power System Data 1 Connection At address 223 UE CONNECTION, the user specifies to the device which type of voltage is connected to the input. The device establishes from this information the type of processing involved. The U input is used for either the various stator earth fault protection functions or for rotor earth fault protection using the rated frequen- cy measurement method (see Section 2.34).
  • Page 56 Functions 2.5 Power System Data 1 In this context, U is the primary voltage (generally phase-ground voltage) and U is the secondary VT, prim E, sec displacement voltage applied to the device. If a voltage divider is used, its division ratio also influences this factor.
  • Page 57 Functions 2.5 Power System Data 1 For the overcurrent protection functions (Sections 2.8, 2.9, and 2.10) and for the breaker failure protection, sides 1 and 2 can be allocated freely. If the differential protection is set to 120 3 phase transf., the following normalizing factors apply for the primary side protection settings in DIGSI.
  • Page 58 Functions 2.5 Power System Data 1 Phase Rotation Address 271 PHASE SEQ. is used to change the default phase sequence (L1 L2 L3 for clockwise rotation), if your power system permanently has an anti-clockwise phase sequence (L1 L3 L2). A temporary reversal of rotation is also possible using binary inputs (see Section 2.47).
  • Page 59 Functions 2.5 Power System Data 1 Measuring Transducer 1 Measuring transducer 1 is provided for DC voltage/DC current protection or the rotor earth fault protection with ). Depending on the application, select at address 295 TRANSDUCER 1 one of the alternatives 1 to 3 Hz (U Control 10 V, 4-20 mA or 20 mA.

  • Page 60: Settings

    Functions 2.5 Power System Data 1 2.5.2 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 61: Information List

    Functions 2.5 Power System Data 1 Addr. Parameter Setting Options Default Setting Comments SN TRANSFORMER 0.20 .. 5000.00 MVA 5.30 MVA Rated Apparent Power of the Transformer UN GEN/MOTOR 0.40 .. 800.00 kV 6.30 kV Rated Primary Voltage Generator/Motor SN GEN/MOTOR 0.20 ..

  • Page 62: Change Group

    Functions 2.6 Change Group Change Group Two independent groups of parameters can be set for the device functions. During operation, the user can switch between setting groups locally using the operator panel, binary inputs (if so configured), the operator and service interface from a personal computer or via the system interface. A setting group comprises the setting values for all functions that have been configured as Enabled (see Section 2.4).

  • Page 63: Power System Data 2

    Functions 2.7 Power System Data 2 Power System Data 2 The general protection data (P.System Data 2) include settings associated with all functions rather than a specific protection or monitoring function. Parameter settings P.System Data 2 can be switched using the setting group.

  • Page 64: Information List

    Functions 2.7 Power System Data 2 2.7.4 Information List Information Type of In- Comments formation Relay PICKUP Relay PICKUP Relay TRIP Relay GENERAL TRIP command IL1 S1: Primary fault current IL1 Side1 IL2 S1: Primary fault current IL2 Side1 IL3 S1: Primary fault current IL3 Side1 IL1 S2: Primary fault current IL1 Side2...

  • Page 65: Definite-Time Overcurrent Protection (I>, Ansi 50/51) With Undervoltage Seal-In

    Functions 2.8 Definite-Time Overcurrent Protection (I>, ANSI 50/51) with Undervoltage Seal-In Definite-Time Overcurrent Protection (I>, ANSI 50/51) with Undervoltage Seal-In The time-overcurrent protection is used as backup protection for the short-circuit protection of the protected object. It also provides backup protection for downstream network components if faults there are not discon- nected in time thus endangering the protected object.

  • Page 66: Setting Notes

    Functions 2.8 Definite-Time Overcurrent Protection (I>, ANSI 50/51) with Undervoltage Seal-In Figure 2-12 Logic Diagram of the Overcurrent Stage I> with Undervoltage Seal-In 2.8.2 Setting Notes General Overcurrent protection is only effective and available if address 112 O/C PROT. I> is set to Side 1 or Side 2 during configuration.
  • Page 67 Functions 2.8 Definite-Time Overcurrent Protection (I>, ANSI 50/51) with Undervoltage Seal-In Undervoltage Seal-In The 1205 U< undervoltage stage (positive-sequence voltage) is set to a value below the lowest phase-to-phase voltage admissible during operation, e.g. 80 V. The seal-in time 1206 T-SEAL-IN limits the pickup seal-in introduced by the overcurrent/undervoltage. It must be set to a value higher than the T I>...

  • Page 68: Settings

    Functions 2.8 Definite-Time Overcurrent Protection (I>, ANSI 50/51) with Undervoltage Seal-In 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.

  • Page 69: Definite-Time Overcurrent Protection (I>>, Ansi 50, 51, 67) With Direction Detection

    Functions 2.9 Definite-Time Overcurrent Protection (I>>, ANSI 50, 51, 67) with Direction Detection Definite-Time Overcurrent Protection (I>>, ANSI 50, 51, 67) with Direction Detection The time-overcurrent protection is used as backup protection for the short-circuit protection of the protected object. It also provides backup protection for downstream network components if faults there are not discon- nected in time thus endangering the protected object.
  • Page 70 Functions 2.9 Definite-Time Overcurrent Protection (I>>, ANSI 50, 51, 67) with Direction Detection Figure 2-14 Cross-Polarized Voltages for Direction Determination The phase carrying the highest current is selected for the direction decision. With equal current levels, the phase with the smaller number is chosen (I before I before I ).
  • Page 71 Functions 2.9 Definite-Time Overcurrent Protection (I>>, ANSI 50, 51, 67) with Direction Detection Figure 2-15 Logic Diagram of I>> Stage with Direction Element SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 72: Setting Notes

    Functions 2.9 Definite-Time Overcurrent Protection (I>>, ANSI 50, 51, 67) with Direction Detection 2.9.2 Setting Notes General The high-current stage I>> of the overcurrent protection is only effective and accessible if it has been assigned within the framework of configuration at address 113 O/C PROT. I>> to either side 1 or side 2, i.e. if either set = NonDirec.
  • Page 73 Functions 2.9 Definite-Time Overcurrent Protection (I>>, ANSI 50, 51, 67) with Direction Detection Current Trans-former on the Output Side (with direction detection) If at address 113 O/C PROT. I>> was configured as directional, the addresses 1304 Phase Direction and 1305 LINE ANGLE are accessible. The inclination of the direction straight line (see figure 2-16) represent- ing the separating line between the tripping and the blocking zone can be adapted to the network conditions by way of the LINE ANGLE parameter.

  • Page 74: Settings

    Functions 2.9 Definite-Time Overcurrent Protection (I>>, ANSI 50, 51, 67) with Direction Detection Figure 2-17 I>> Stage as 'Differential Protection' 2.9.3 Settings The table indicates region-specific presettings. Column C (configuration) indicates the corresponding second- ary nominal current of the current transformer. Addr.

  • Page 75: Inverse-Time Overcurrent Protection (Ansi 51V)

    Functions 2.10 Inverse-Time Overcurrent Protection (ANSI 51V) 2.10 Inverse-Time Overcurrent Protection (ANSI 51V) The inverse-time overcurrent protection protects extra-low voltage and low-voltage machines against short cir- cuits. For larger machines it is used as back-up protection for the machine short-circuit protection (differential protection and/or impedance protection).
  • Page 76 Functions 2.10 Inverse-Time Overcurrent Protection (ANSI 51V) Figure 2-18 Pick-up Value Voltage Dependency The Ip reference value is decreased proportional to the voltage decrease. Consequently, for a constant current I, the I/Ip ratio is increased and the trip time is reduced. Compared with the standard characteristics represent- ed in the „Technical Data“...
  • Page 77 Functions 2.10 Inverse-Time Overcurrent Protection (ANSI 51V) Figure 2-19 Logic Diagram of the Inverse Time Overcurrent Protection without Undervoltage Influencing Figure 2-20 Logic Diagram of the Voltage Controlled Inverse Time Overcurrent Protection The changeover to the lower current pickup value on decreasing voltage (loop release) is performed on a phase by phase basis in accordance with Table 2-4.
  • Page 78 Functions 2.10 Inverse-Time Overcurrent Protection (ANSI 51V) Figure 2-21 Logic Diagram of the Voltage Restraint Inverse Time Overcurrent Protection The reduction of the current pick-up threshold in case of a decreasing voltage (control voltage assignment) is performed phase by phase according to table 2-4. SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 79: Setting Notes

    Functions 2.10 Inverse-Time Overcurrent Protection (ANSI 51V) 2.10.2 Setting Notes General The inverse overcurrent time protection is only effective and available if this function was allocated to the input CTs of either side 1 or side 2 during configuration (see Section 2.4), i.e. if address 114 O/C PROT. Ip was set to IEC SIDE 1, ANSI SIDE 1, IEC SIDE 2 or ANSI SIDE 2.

  • Page 80: Settings

    Functions 2.10 Inverse-Time Overcurrent Protection (ANSI 51V) 2.10.3 Settings The table indicates region-specific presettings. Column C (configuration) indicates the corresponding second- ary nominal current of the current transformer. Addr. Parameter Setting Options Default Setting Comments 1401 O/C Ip Inverse O/C Time Protec- tion Ip Block relay 1402...

  • Page 81: Thermal Overload Protection (Ansi 49)

    Functions 2.11 Thermal Overload Protection (ANSI 49) 2.11 Thermal Overload Protection (ANSI 49) The thermal overload protection prevents thermal overloading of the stator windings of the machine being pro- tected. 2.11.1 Functional Description Thermal Profile The device calculates the overtemperature in accordance with a single-body thermal model, based on the fol- lowing differential equation: with Actual operating temperature expressed in percent of the operating temperature correspond-...
  • Page 82 Functions 2.11 Thermal Overload Protection (ANSI 49) Coolant Temperature (Ambient Temperature) With 7UM62, the thermal model considers an external temperature value. Depending on the application, this temperature can be the coolant or ambient temperature or, in the case of gas turbines, the entry temperature of the cold gas.
  • Page 83 Functions 2.11 Thermal Overload Protection (ANSI 49) Blocking The thermal memory may be reset via a binary input („>RM th.rep. O/L“). The current-induced excessive temperature value is reset to zero. The same is achieved by entering a blocking („>BLK ThOverload“); in that case the overload protection is blocked completely, including the current alarm stage.
  • Page 84 Functions 2.11 Thermal Overload Protection (ANSI 49) Figure 2-22 Logic of the Overload Protection Function SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 85: Setting Notes

    Functions 2.11 Thermal Overload Protection (ANSI 49) 2.11.2 Setting Notes General Overload protection is only effective and accessible if address 116 Therm.Overload is set to Enabled during configuration. If the function is not required, it is set to Disabled. Transformers and generators are especially prone to damage by extended overloads. These overloads cannot and should not be detected by short-circuit protection.
  • Page 86 Functions 2.11 Thermal Overload Protection (ANSI 49) Time Constant The overload protection tracks overtemperature progression, employing a thermal differential equation whose steady state solution is an exponential function. The TIME CONSTANT τ (address 1603) is used in the calcu- lation to determine the threshold of excess temperature and thus the tripping temperature. If the overload characteristic of the generator to be protected is pre-determined, the user must select the pro- tection trip characteristic so that it largely corresponds the overload characteristic, at least for small overloads.
  • Page 87 Functions 2.11 Thermal Overload Protection (ANSI 49) Emergency Start The run-on time to be entered at address 1616 T EMERGENCY must be sufficient to ensure that after an emer- gency startup and dropout of binary input „>Emer.Start O/L“ the trip command is blocked until the thermal replica is again below the dropout threshold.
  • Page 88 Functions 2.11 Thermal Overload Protection (ANSI 49) If the temperature input is used, the trip times change if the coolant temperature deviates from the internal ref- erence temperature of 40 °C. The following formula can be used to calculate the trip time: with TIME CONSTANT (address 1603) τ...

  • Page 89: Settings

    Functions 2.11 Thermal Overload Protection (ANSI 49) 2.11.3 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 90: Information List

    Functions 2.11 Thermal Overload Protection (ANSI 49) 2.11.4 Information List Information Type of In- Comments formation 1503 >BLK ThOverload >BLOCK thermal overload protection 1506 >RM th.rep. O/L >Reset memory for thermal replica O/L 1507 >Emer.Start O/L >Emergency start O/L 1508 >Fail.Temp.inp >Failure temperature input 1511...

  • Page 91: Unbalanced Load (Negative Sequence) Protection (Ansi 46)

    Functions 2.12 Unbalanced Load (Negative Sequence) Protection (ANSI 46) 2.12 Unbalanced Load (Negative Sequence) Protection (ANSI 46) The unbalanced load protection detects asymmetrical loads of three-phase induction machines. Unbalanced loads create a counter-rotating field which acts on the rotor at double frequency. Eddy currents are induced on the rotor surface, leading to local overheating at the transition between the slot wedges and the winding bun- dles.
  • Page 92 Functions 2.12 Unbalanced Load (Negative Sequence) Protection (ANSI 46) Cool Down A cool-down time with adjustable parmeters starts as soon as the constantly permissible unbalanced load I2> is undershot. The tripping drops out on dropout of the pickup. However, the counter content is reset to zero with the cooling time parameterized at address 1705 T COOL DOWN.
  • Page 93 Functions 2.12 Unbalanced Load (Negative Sequence) Protection (ANSI 46) Logic The following figure shows the logic diagram of the unbalanced load protection. The protection may be blocked via a binary input („>BLOCK I2“). Pickups and time stages are reset and the metered values in the thermal replica are cleared.

  • Page 94: Setting Notes

    Functions 2.12 Unbalanced Load (Negative Sequence) Protection (ANSI 46) 2.12.2 Setting Notes General Unbalanced load protection is only in effect and accessible if address 117 UNBALANCE LOAD is set to Enabled during configuration. If the function is not required, it is set to Disabled. The address 1701 UNBALANCE LOAD serves to switch the unbalanced load protection ON or OFF or to block only the trip command (Block relay).
  • Page 95 Functions 2.12 Unbalanced Load (Negative Sequence) Protection (ANSI 46) Conversion to Secondary Values The factor K can be derived from the unbalanced load characteristic according to the figure below by reading the time corresponding to the FACTOR K at the point I = 1.
  • Page 96 Functions 2.12 Unbalanced Load (Negative Sequence) Protection (ANSI 46) Cool-down Time The parameter 1705 T COOL DOWN establishes the time required by the protection object to cool down under admissible unbalanced load I2> to the initial value. If the machine manufacturer does not provide this informa- tion, the setting value can be calculated by assuming an equal value for cool-down time and heatup time of the object to be protected.

  • Page 97: Settings

    Functions 2.12 Unbalanced Load (Negative Sequence) Protection (ANSI 46) 2.12.3 Settings Addr. Parameter Setting Options Default Setting Comments 1701 UNBALANCE LOAD Unbalance Load Protection Block relay 1702 I2> 3.0 .. 30.0 % 10.6 % Continously Permissible Current 1703 T WARN 0.00 ..

  • Page 98: Startup Overcurrent Protection (Ansi 51)

    Functions 2.13 Startup Overcurrent Protection (ANSI 51) 2.13 Startup Overcurrent Protection (ANSI 51) Gas turbines can be started by means of a startup converter. A controlled converter feeds a current into the generator creating a rotating field of gradually increasing frequency. This causes the rotor to turn and thus drive the turbine.

  • Page 99: Setting Notes

    Functions 2.13 Startup Overcurrent Protection (ANSI 51) The startup overcurrent protection is a short-circuit protection function that operates below 10 Hz. Its operating range is designed for 2 Hz to approx. 10 Hz (change to operational condition 1). Beyond this range the above short-circuit protection functions are active.
  • Page 100 Functions 2.13 Startup Overcurrent Protection (ANSI 51) Figure 2-28 Short-circuit currents in the generator during startup (generator: 300 MVA, 15.75 kV, 50 Hz) Delay Since the generator circuit breaker is open during startup, there is no need to coordinate the delay time with the network.

  • Page 101: Settings

    Functions 2.13 Startup Overcurrent Protection (ANSI 51) Figure 2-29 Operating range and possible pickup threshold of short-circuit protection functions 2.13.3 Settings The table indicates region-specific presettings. Column C (configuration) indicates the corresponding second- ary nominal current of the current transformer. Addr.

  • Page 102: Differential Protection And Its Protected Objects

    Functions 2.14 Differential Protection and Its Protected Objects 2.14 Differential Protection and Its Protected Objects The numerical current differential protection of the 7UM62 is a high speed selective short-circuit protection for generators, motors and transformers. The individual application can be configured, which ensures optimum matching to the protected object.
  • Page 103 Functions 2.14 Differential Protection and Its Protected Objects Current Stabilization When an external fault causes heavy currents to flow through the protected zone, differences in the magnetic characteristics of the current transformers CT1 and CT2 under conditions of saturation may cause a significant current to flow through the element M, which can cause a tripping.
  • Page 104 Functions 2.14 Differential Protection and Its Protected Objects Figure 2-32 Tripping Characteristic of the Differential Protection with Fault Characteristic Quantitative Matching of Measured values The rated CT currents are matched to the rated current of the protected object, regardless of what that object is.
  • Page 105 Functions 2.14 Differential Protection and Its Protected Objects The currents II and I are compared by the differential protection with the operating characteristic according diff stab to the following figure. If these values result result in a point within the tripping area, a trip signal is issued. If the current conditions I appear near the fault characteristic (≥...
  • Page 106 Functions 2.14 Differential Protection and Its Protected Objects Add-On Stabilization During Current Transformer Saturation During an external fault which produces a high through-flowing short-circuit current causing current transformer saturation, a considerable differential current can be simulated, especially when the degree of saturation is dif- ferent at the two measuring points.
  • Page 107 Functions 2.14 Differential Protection and Its Protected Objects Figure 2-35 Add-on Stabilization During Current Transformer Saturation Identification of DC Components A further stabilization (restraint) comes into effect when differential secondary currents are simulated by differ- ent transient behaviour of the current transformer sets. This differential current is caused by different DC time constants in the secondary circuits during through-current conditions, i.e.
  • Page 108 Functions 2.14 Differential Protection and Its Protected Objects Besides the second harmonic, another harmonic can be selected in the 7UM62 to cause stabilization. A choice can be made between the third and fifth harmonic for harmonic stabilization. Steady-state overexcitation is characterized by odd harmonics. The 3rd or 5th harmonic is suitable to detect overexcitation.
  • Page 109 Functions 2.14 Differential Protection and Its Protected Objects Figure 2-37 Increase of pickup value for stage I on startup DIFF> Fault Detection, Dropout The differential protection does not normally use a "pickup", since the detection of a fault is identical with the tripping condition.
  • Page 110 Functions 2.14 Differential Protection and Its Protected Objects For special cases, the trip command can be delayed. The following figure shows a simplified diagram of the tripping logic. A dropout is detected when, during 2 cycles, pick-up is no longer recognized in the differential value, i.e. the differential current has fallen below 70 % of the set value, and the other pickup conditions are no longer fulfilled either.
  • Page 111 Functions 2.14 Differential Protection and Its Protected Objects Figure 2-39 Logic Diagram of the Tripping Logic in Differential Protection SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 112: Setting Notes

    Functions 2.14 Differential Protection and Its Protected Objects 2.14.1.2 Setting Notes General Differential protection is only effective and available if the type of protected object for this function was set during protective function configuration (Section 2.4, address 120, DIFF. PROT. = Generator/Motor or 3 phase transf.).

  • Page 113: Information List

    Functions 2.14 Differential Protection and Its Protected Objects Addr. Parameter Setting Options Default Setting Comments 2042A BASE POINT 1 0.00 .. 2.00 I/InO 0.00 I/InO Base Point for Slope 1 of Charac. 2043A SLOPE 2 0.25 .. 0.95 0.50 Slope 2 of Tripping Characteristic 2044A BASE POINT 2 0.00 ..
  • Page 114 Functions 2.14 Differential Protection and Its Protected Objects Information Type of In- Comments formation 5663 Block Iflt.L2 Diff. prot.: Blocked by CT fault L2 5664 Block Iflt.L3 Diff. prot.: Blocked by CT fault L3 5666 Diff in.char.L1 Diff: Increase of char. phase L1 5667 Diff in.char.L2 Diff: Increase of char.

  • Page 115: Protected Object Generator Or Motor

    Functions 2.14 Differential Protection and Its Protected Objects 2.14.2 Protected Object Generator or Motor The following section describes the special features of the generator and motor as the protection objects. 2.14.2.1 Functional Description Definition and Matching of Measured Quantities The differential protection function of the 7UM62 can be used as longitudinal or as transverse differential pro- tection.

  • Page 116: Setting Notes

    Functions 2.14 Differential Protection and Its Protected Objects The CTs also determine the limits of sensitivity in the case of motors. In asynchronous motors, the startup op- eration may be modelled in different ways by the CTs, so that major differential currents occur (see also side title "Increase of Pickup Value on Startup").
  • Page 117 Functions 2.14 Differential Protection and Its Protected Objects The second branch produces a higher stabilization in the range of high currents which may lead to current transformer saturation. Its base point is set at address 2044 BASE POINT 2. The gradient is set at address 2043 SLOPE 2.

  • Page 118: Protected Object Transformer

    Functions 2.14 Differential Protection and Its Protected Objects 2.14.3 Protected Object Transformer Transformers are subject to a number of influences that induce differential currents even during normal opera- tion: 2.14.3.1 Functional Description Mismatching of CTs Differences in the matching of CTs to the transformer rated current are not uncommon. These differences result in an error that leads to a differential current.
  • Page 119 Functions 2.14 Differential Protection and Its Protected Objects Quantitative matching of Measured values The input currents are converted in relation to the power transformer rated current. The nominal values of the transformer, i.e. rated apparent power, rated voltages and primary rated CT currents, are entered in the protec- tive device, and a correction factor k is calculated according to the following formula: with...
  • Page 120 Functions 2.14 Differential Protection and Its Protected Objects Figure 2-43 Vector group matching for a Yd5 transformer (isolated starpoint) Deducting on side 2 the currents I – I , results in the current I , which has the same direction as I on side 1.
  • Page 121 Functions 2.14 Differential Protection and Its Protected Objects Figure 2-44 Vector group matching for Y(N) d5 (with earthed starpoint) In the following figure on the left-hand side, a zero sequence current will occur in case of e.g. an external fault; on the right-hand side, it will not.

  • Page 122: Setting Notes

    Functions 2.14 Differential Protection and Its Protected Objects 2.14.3.2 Setting Notes Requirement A precondition for the transformer differential protection function is that on configuration address 120 DIFF. PROT. was set to 3 phase transf.. To ensure the correct polarity for the formation of the differential current, the polarity of the sets of CTs must be specified.
  • Page 123 Functions 2.14 Differential Protection and Its Protected Objects Zero Sequence Current Treatment The treatment of the winding starpoints is of no concern if the zero sequence current is eliminated from the phase currents. By this means fault currents which flow through the CTs during earth faults in the network if there is an earthing point in the protected zone (transformer starpoint or starpoint earthing transformer) are neu- tralized without any special external measures.
  • Page 124 Functions 2.14 Differential Protection and Its Protected Objects The harmonic restraint operates individually per phase. However, it is also possible – as it is for the inrush re- straint – to set the protection such that not only the phase with harmonics content in excess of the permissible value is stabilized but also the other phases of the differential stage IDIFF>...
  • Page 125 Functions 2.14 Differential Protection and Its Protected Objects The second branch produces a higher restraint in the range of high currents which may lead to current trans- former saturation. Its base point is set at address 2044 BASE POINT 2 and is referred to the rated power transformer current.

  • Page 126: Current Transformer Requirements

    Functions 2.14 Differential Protection and Its Protected Objects 2.14.4 Current Transformer Requirements The differential protection is of decisive importance for the requirements that the current transformers must meet. The high-speed trip stage (IDiff >>) uses instantaneous values and can therefore reliably trip high-current internal short-circuits.
  • Page 127 Functions 2.14 Differential Protection and Its Protected Objects Table 2-6 Transformer Requirements Transformer Generator Transient dimensioning factor K ≥ 4 > (4 to 5), with τ > 100 ms with τ ≤ 100 ms Symmetrical short circuit current I pSSC Example = 0.1 ’’...

  • Page 128: Earth Current Differential Protection (Ansi 87Gn,Tn)

    Another application would be transformer windings in wye connection. For applications such as auto-transformers, starpoint earthing transformers and shunt reactors, Siemens rec- ommends that the 7UT612 protective device be used instead.
  • Page 129 Functions 2.15 Earth Current Differential Protection (ANSI 87GN,TN) Measuring Principle The 2 possible implementations of the earth fault differential protection differ only in their method of determining the zero sequence current. This is shown in the following picture. This figure also shows the definition of the current direction.
  • Page 130 Functions 2.15 Earth Current Differential Protection (ANSI 87GN,TN) Figure 2-49 Example of an external fault When an external non-earthed fault causes heavy currents to flow through the protected zone, differences in the magnetic characteristics of the phase current transformers under conditions of saturation may cause a sig- nificant summation current which resembles an earth current flowing into the protected zone.
  • Page 131 Functions 2.15 Earth Current Differential Protection (ANSI 87GN,TN) Figure 2-50 Tripping and restraint characteristic In applications with direct measurement of the starpoint current (e.g. earth current differential protection for transformers), the starpoint current is queried in addition to evaluation of the characteristic. This provides ad- ditional restraint against CT problems such as wrong zero sequence current modeling of the phase current transformers on side 1.
  • Page 132 Functions 2.15 Earth Current Differential Protection (ANSI 87GN,TN) Figure 2-51 Operating ranges of the direction criterion • Phase current monitoring To exclude spurious tripping due to CT saturation in the presence of external faults, the protection function is blocked as soon as a maximum phase current is reached. For this purpose, the phase currents of side 1 are monitored.

  • Page 133: Setting Notes

    Functions 2.15 Earth Current Differential Protection (ANSI 87GN,TN) Figure 2-52 Logic Diagram of the Earth Current Differential Protection with 1) Use of generator: always side 1 LxSm Use of transformer: I according to allocation of sides LxSm 2.15.2 Setting Notes General A precondition for the operation of the earth current differential protection is that during the configuration of the scope of functions (Section 2.4) the correct selection for the application in hand was made at address 121 REF...
  • Page 134 Functions 2.15 Earth Current Differential Protection (ANSI 87GN,TN) Note When using the I input, it must be kept in mind that this is a sensitive current input. The current amplitude is limited to approx. √2 1.6 A. A secondary rated current of 1 A is to be used for the starpoint CT. If a 5-A trans- former is used, the appropriate transformation ratio has to be set.

  • Page 135: Settings

    Functions 2.15 Earth Current Differential Protection (ANSI 87GN,TN) 2.15.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Additional Settings. Addr. Parameter Setting Options Default Setting Comments 2101 REF PROT. Restricted Earth Fault Protection Block relay 2102 REF I>...

  • Page 136: Underexcitation (Loss-Of-Field) Protection (Ansi 40)

    Functions 2.16 Underexcitation (Loss-of-Field) Protection (ANSI 40) 2.16 Underexcitation (Loss-of-Field) Protection (ANSI 40) The underexcitation protection protects a synchronous machine from asynchronous operation in the event of faulty excitation or regulation and from local overheating of the rotor. Furthermore, it prevents that the network stability is endangered by underexcitation of large synchronous machines.
  • Page 137 Functions 2.16 Underexcitation (Loss-of-Field) Protection (ANSI 40) Figure 2-54 Stator circuit criterion: Pick–Up Characteristic in Admittance Diagram A further characteristic (1/xd CHAR.3 /α can be matched to the dynamic stability characteristic of the synchro- nous machine. Since stable operation is impossible if this characteristic is exceeded, immediate tripping is then required (time stage T CHAR 3).
  • Page 138 Functions 2.16 Underexcitation (Loss-of-Field) Protection (ANSI 40) Undervoltage Blocking The admittance calculation requires a minimum measurement voltage. During a severe collapse (short-circuit) or failure of stator voltages, the protection is blocked by an integrated AC voltage monitor whose pickup thresh- old 3014 Umin is set on delivery to 25 V.

  • Page 139: Setting Notes

    Functions 2.16 Underexcitation (Loss-of-Field) Protection (ANSI 40) 2.16.2 Setting Notes General The underexcitation protection is only effective and available if this function was set during protective function configuration (Section 2.4), address 130, UNDEREXCIT. is set to Enabled. If the function is not required Disabled is set.
  • Page 140 Functions 2.16 Underexcitation (Loss-of-Field) Protection (ANSI 40) Figure 2-57 Capability Curve of a Salient-Pole Generator, Indicated per Unit Example: = 6300 V 5270 kVA 50.0 Hz 1500 RPM cos ϕ = 0,800 2,470 1,400 The primary setting values can be read out directly from the diagram. The related values must be converted for the protection setting.
  • Page 141 Functions 2.16 Underexcitation (Loss-of-Field) Protection (ANSI 40) Instead of 1/x the approximate value I can be used (with I = short-circuit current at no-load excita- d Mach tion). Setting example: Machine = 6.3 kV N Mach /√3 U = 5270 kVA/√3 · 6.3 kV = 483 A N Mach = 2.47 d Mach...
  • Page 142 Functions 2.16 Underexcitation (Loss-of-Field) Protection (ANSI 40) Delay Times If the static limit curve consisting of the characteristics 1 and 2 is exceeded, the voltage regulator must first have the opportunity of increasing the excitation. For this reason, a warning message due to this criterion is "long- time"...

  • Page 143: Settings

    Functions 2.16 Underexcitation (Loss-of-Field) Protection (ANSI 40) 2.16.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Additional Settings. Addr. Parameter Setting Options Default Setting Comments 3001 UNDEREXCIT. Underexcitation Protection Block relay 3002 1/xd CHAR. 1 0.20 ..

  • Page 144: Information List

    Functions 2.16 Underexcitation (Loss-of-Field) Protection (ANSI 40) 2.16.4 Information List Information Type of In- Comments formation 5323 >Exc. BLOCK >BLOCK underexcitation protection 5327 >Char. 3 BLK. >BLOCK underexc. prot. char. 3 5328 >Uexc fail. >Exc. voltage failure recognized 5329 >Char. 1 BLK. >BLOCK underexc.

  • Page 145: Reverse Power Protection (Ansi 32R)

    Functions 2.17 Reverse Power Protection (ANSI 32R) 2.17 Reverse Power Protection (ANSI 32R) Reverse power protection is used to protect a turbo-generator unit on failure of energy to the prime mover when the synchronous generator runs as a motor and drives the turbine taking motoring energy from the network. This condition leads to overheating of the turbine blades and must be interrupted within a short time by tripping the network circuit-breaker.

  • Page 146: Setting Notes

    Functions 2.17 Reverse Power Protection (ANSI 32R) Figure 2-59 Logic Diagram of the Reverse Power Protection 2.17.2 Setting Notes General Reverse power protection is only effective and available if this function was set during protective function con- figuration (Section 2.4), address 131, REVERSE POWER is set to Enabled. If the function is not required Disabled is set.
  • Page 147 Functions 2.17 Reverse Power Protection (ANSI 32R) The pickup value 3102 P> REVERSE is set in percent of the secondary apparent power rating S = √3 · U Nsek Nsec · I . If the primary motoring energy is known, it must be converted to secondary quantities using the following Nsec formula: with...

  • Page 148: Settings

    Functions 2.17 Reverse Power Protection (ANSI 32R) 2.17.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Additional Settings. Addr. Parameter Setting Options Default Setting Comments 3101 REVERSE POWER Reverse Power Protection Block relay 3102 P>...

  • Page 149: Forward Active Power Supervision (Ansi 32F)

    Functions 2.18 Forward Active Power Supervision (ANSI 32F) 2.18 Forward Active Power Supervision (ANSI 32F) The machine protection 7UM62 includes an active power supervision which monitors whether the active power falls below one settable value as well as whether a separate second settable value is exceeded. Each of these functions can initiate different control functions.

  • Page 150: Setting Notes

    Functions 2.18 Forward Active Power Supervision (ANSI 32F) 2.18.2 Setting Notes General Forward active power protection is only effective and available if this function was set during protective function configuration (Section 2.4, address 132, FORWARD POWER is set to Enabled). If the function is not required Disabled is set.

  • Page 151: Settings

    Functions 2.18 Forward Active Power Supervision (ANSI 32F) 2.18.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Additional Settings. Addr. Parameter Setting Options Default Setting Comments 3201 FORWARD POWER Forward Power Supervision Block relay 3202 Pf<...

  • Page 152: Impedance Protection (Ansi 21)

    Functions 2.19 Impedance Protection (ANSI 21) 2.19 Impedance Protection (ANSI 21) Machine impedance protection is used as a selective time graded protection to provide the shortest possible tripping times for short-circuits in the synchronous machine, on the terminal leads as well as in the unit trans- former.
  • Page 153 Functions 2.19 Impedance Protection (ANSI 21) Loop Selection The corresponding phase-earth loop is used for a 1-pole pickup With a 2-pole pickup, the phase-phase loop with the corresponding phase-to-phase voltage is used for impedance calculation. With a 3-pole pickup, the phase-earth loop with the highest current value is used and with equal current amplitudes, the procedure described in the last row of the following table is applied.
  • Page 154 Functions 2.19 Impedance Protection (ANSI 21) Figure 2-61 Logic Diagram of the Pickup Stage of the Impedance Protection Tripping Characteristic The tripping characteristic of the impedance protection is a polygon (see also Figure 2-62). It is symmetrical even though a fault in reverse direction (negative R and/or X values) is physically impossible provided the usual connection to the current transformers at the star-point side of the generator is used.
  • Page 155 Functions 2.19 Impedance Protection (ANSI 21) Figure 2-62 Tripping Characteristics of the Impedance Protection Tripping Logic The T END time delay is started subsequent to the protection pickup, establishing the fault loop. The loop im- pedance components are compared with the limit values of the zones previously set. The tripping is executed if the impedance is within its zone during the course of the corresponding time stage.
  • Page 156 Functions 2.19 Impedance Protection (ANSI 21) Figure 2-63 Logic Diagram of the Impedance Protection SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 157: Power Swing Blocking

    Functions 2.19 Impedance Protection (ANSI 21) 2.19.2 Power Swing Blocking General Dynamic occurrences such as sudden load changes, short circuits, automatic reclosure or switching operations within the power system may cause power swings. Therefore impedance protection is complemented by a power swing blocking function to avoid spurious tripping.

  • Page 158: Setting Notes

    Functions 2.19 Impedance Protection (ANSI 21) Figure 2-64 Logic Diagram for the Power Swing Blocking of the Impedance Protection Z(Tent) First value inside the power swing polygon (at the moment of Tent) Z(Tent-Δt) Last value outside the power swing polygon P/SPOL Power swing polygon TPOL...
  • Page 159 Functions 2.19 Impedance Protection (ANSI 21) Impedance Stages The protection has the following characteristics which may be set independently: 1. Zone (fast tripping zone Z1 ) with parameters ZONE Z1 Reactance = reach, T-Z1 = 0 or short delay, if required. Overreach zone Z1B, externally controlled via binary input, with parameters ZONE Z1B Reactance = reach,...
  • Page 160 Functions 2.19 Impedance Protection (ANSI 21) Example: Transformer data: = 7 % = 5.3 MVA = 6.3 kV Transformation ratios: Current transformer ratio = 500 A / 1 A This results for a 70 % reach for zone 1 in: The following secondary side setting value of zone 1 results at address 3306 ZONE Z1: Note: The following ratio would result from the connection of a 5 A device to a 5 A transformer: Likewise the following primary reactance results for a 100 % reach for zone 2:...
  • Page 161 Functions 2.19 Impedance Protection (ANSI 21) Figure 2-65 Time Grading for Machine Impedance Protection – Example Z1B Overreach Zone The Z1B overreach zone (address 3308 ZONE Z1B) is an externally controlled stage. It does not influence the Z1 zone normal stage. Consequently there is no changeover, but the overreach zone is enabled or disabled depending on the position of the high-voltage side circuit breaker.
  • Page 162 Functions 2.19 Impedance Protection (ANSI 21) The following relation allows estimation of the rate of change: Definitions: Reactance between the sources of the power swing Swing frequency Swing angle δ Figure 2-66 shows an example of how the rate of change evolves as a function of the power swing angle. For an angle of 180°...

  • Page 163: Settings

    Functions 2.19 Impedance Protection (ANSI 21) If safety factor 4 is chosen, dZ/dt should never be set higher than 500 Ω/s (or 100 Ω/s for 5 A transformers). The default setting for dZ/dt is 300 Ω/s, which should be adequate for most applications. This is also the basis for the minimum distance P/SPOL - TPOL, assuming that for detection of a power swing there must be one impedance value between P/SPOL and TPOL.

  • Page 164: Information List

    Functions 2.19 Impedance Protection (ANSI 21) Addr. Parameter Setting Options Default Setting Comments 3307 T-Z1 0.00 .. 60.00 sec; ∞ 0.10 sec Impedance Zone Z1 Time Delay 3308 ZONE Z1B 0.01 .. 13.00 Ω 0.99 Ω Impedance Zone Z1B 0.05 .. 65.00 Ω 4.95 Ω...

  • Page 165: Out-Of-Step Protection (Ansi 78)

    Functions 2.20 Out-of-Step Protection (ANSI 78) 2.20 Out-of-Step Protection (ANSI 78) Depending on power network conditions and feeding generators, dynamic occurrences such as load jumps, short-circuits not disconnected quickly enough, auto-reclosure or switching actions, may cause system swings. Such power swings endanger power network stability. Stability problems often result from active power swings which can lead to pole-slipping and generator overloading.
  • Page 166 Functions 2.20 Out-of-Step Protection (ANSI 78) Thus, this results in: where δ is the phase shift angle between the generator voltage and the network equivalent voltage. Under normal conditions, this angle depends on the load situation and is largely constant. In the event of an out-of- step condition, however the angle fluctuates continually and can vary between 0°...

  • Page 167: Out-Of-Step Protection Logic

    Functions 2.20 Out-of-Step Protection (ANSI 78) Figure 2-68 Impedance Trajectory at Measurement Location m 2.20.2 Out-of-Step Protection Logic The following figure shows the power swing polygon in greater detail. For transparency purposes the inclination angle ϕ is assumed to be 90°. The setting parameters of impedances Z and (Z –Z ) determine the...
  • Page 168 Functions 2.20 Out-of-Step Protection (ANSI 78) Figure 2-69 Polygonal Out-of-Step Characteristic with Typical Power Swings Detection of an out-of-step condition requires, additionally, that the impedance vector enters a power swing characteristic at one side, passes through the imaginary axis or characteristic dividing line, and exits the polygon at the opposite side (loss of synchronism, cases (1) and (2)).

  • Page 169: Setting Notes

    Functions 2.20 Out-of-Step Protection (ANSI 78) Figure 2-70 Logic Diagram of the Out-of-Step Protection 2.20.3 Setting Notes General Out-of-step protection is only effective and available if this function was set during protective function configu- ration (Section 2.4, address 135, OUT-OF-STEP is set to Enabled. If the function is not required Disabled is set.
  • Page 170 Functions 2.20 Out-of-Step Protection (ANSI 78) Impedance Values The measured impedances perceived by the protection device are decisive for the settings. For the direction to the machine (as viewed from the location of the voltage transformers), the power swing reactance of the machine must be considered, which is approximately the transient reactance X ' of the machine.
  • Page 171 Functions 2.20 Out-of-Step Protection (ANSI 78) Table 2-11 Transient Machine Reactances (Referred to Secondary Side) Generator Type = 100 V/ I = 1 A = 120 V/ I = 1 A = 100 V/ I = 5 A = 120 V/ I = 5 A Non-salient pole 0,13...0,35 7.5 Ω...20.2 Ω...
  • Page 172 Functions 2.20 Out-of-Step Protection (ANSI 78) Figure 2-72 Power swing polygon and impedance vectors with angle δ Maximum power swing frequency The polygon width Z determines also the maximum detectable power swing frequency. Considering that even with rapid power swings, at least two impedance values must have been established within the power swing polygon (which in a limit case differ by the width of the polygon), the following approximative formula can be used for the maximum detectable power swing frequency f At a rated frequency of 50 Hz (i.e.
  • Page 173 Functions 2.20 Out-of-Step Protection (ANSI 78) Transformation ratios: Current Transformer = 500 A/1 A Ratio This gives the secondary transient reactance of the generator: ≈ X ' thus determines the setting of address 3505 Zb. The secondary short circuit reactance of the unit transformer is derived by considering the transformation ratios: If characteristic 1 covers 85 % of the transformer reactance, this results in the setting of Z ≈...

  • Page 174: Settings

    Functions 2.20 Out-of-Step Protection (ANSI 78) 2.20.4 Settings The table indicates region-specific presettings. Column C (configuration) indicates the corresponding second- ary nominal current of the current transformer. Addr. Parameter Setting Options Default Setting Comments 3501 OUT-OF-STEP Out-of-Step Protection Block relay 3502 I1>...

  • Page 175: Undervoltage Protection (Ansi 27)

    Functions 2.21 Undervoltage Protection (ANSI 27) 2.21 Undervoltage Protection (ANSI 27) The undervoltage protection function detects voltage dips on electrical machines and prevents inadmissible op- erating states and a possible loss of stability. Two-pole short circuits or ground faults cause a dip in asymmet- rical voltages.

  • Page 176: Setting Notes

    Functions 2.21 Undervoltage Protection (ANSI 27) Figure 2-73 Logic diagram of the undervoltage protection 2.21.2 Setting Notes General The undervoltage protection is only effective and available if this function was set during protective function configuration (Section 2.4, address 140, UNDERVOLTAGE is set to Enabled). If the function is not required Disabled is set.

  • Page 177: Settings

    Functions 2.21 Undervoltage Protection (ANSI 27) 2.21.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Additional Settings. Addr. Parameter Setting Options Default Setting Comments 4001 UNDERVOLTAGE Undervoltage Protection Block relay 4002 U< 10.0 .. 125.0 V 75.0 V U<...

  • Page 178: Overvoltage Protection (Ansi 59)

    Functions 2.22 Overvoltage Protection (ANSI 59) 2.22 Overvoltage Protection (ANSI 59) Overvoltage protection serves to protect the electrical machine and connected electrical plant components from the effects of inadmissible voltage increases. Overvoltages can be caused by incorrect manual operation of the excitation system, faulty operation of the automatic voltage regulator, (full) load shedding of a generator, separation of the generator from the system or during island operation.

  • Page 179: Setting Notes

    Functions 2.22 Overvoltage Protection (ANSI 59) 2.22.2 Setting Notes General Overvoltage protection is only effective and available if this function was set during protective function config- uration (Section 2.4, address 141, OVERVOLTAGE is set to Enabled. If the function is not required Disabled is set.

  • Page 180: Settings

    Functions 2.22 Overvoltage Protection (ANSI 59) 2.22.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Additional Settings. Addr. Parameter Setting Options Default Setting Comments 4101 OVERVOLTAGE Overvoltage Protection Block relay 4102 U> 30.0 .. 170.0 V 115.0 V U>...

  • Page 181: Frequency Protection (Ansi 81)

    Functions 2.23 Frequency Protection (ANSI 81) 2.23 Frequency Protection (ANSI 81) The frequency protection function detects abnormally high and low frequencies in the generator. If the frequen- cy lies outside the permissible range, appropriate switching actions are initiated, e.g. separating the generator from the system.

  • Page 182: Setting Notes

    Functions 2.23 Frequency Protection (ANSI 81) Figure 2-75 Logic diagram of the frequency protection 2.23.2 Setting Notes General Frequency protection is only in effect and accessible if address 142 FREQUENCY Prot. is set to Enabled during configuration of protective functions. If the function is not required Disabled is set. Address 4201 O/U FREQUENCY serves to switch the function ON or OFF or to block only the trip command (Block relay).

  • Page 183: Settings

    Functions 2.23 Frequency Protection (ANSI 81) Further application examples are covered under power stations. The frequency values to be set mainly depend, also in these cases, on power system/power station operator specifications. In this context, frequency decrease protection ensures the power station's own demand by disconnecting it from the power system on time. The turbo regulator regulates the machine set to the nominal speed.

  • Page 184: Information List

    Functions 2.23 Frequency Protection (ANSI 81) Addr. Parameter Setting Options Default Setting Comments 4209 f3 PICKUP 40.00 .. 66.00 Hz 59.50 Hz f3 Pickup 4210 T f3 0.00 .. 100.00 sec 20.00 sec T f3 Time Delay 4211 f4 PICKUP 40.00 ..

  • Page 185: Overexcitation (Volt/Hertz) Protection (Ansi 24)

    Functions 2.24 Overexcitation (Volt/Hertz) Protection (ANSI 24) 2.24 Overexcitation (Volt/Hertz) Protection (ANSI 24) Overexcitation protection is used to detect inadmissibly high induction in generators and transformers, espe- cially in power station unit transformers. The protection must intervene when the limit value for the protected object (e.g.
  • Page 186 Functions 2.24 Overexcitation (Volt/Hertz) Protection (ANSI 24) Figure 2-76 Tripping Range of the Overexcitation Protection The characteristic resulting from the device default settings is shown in the Technical Data Section Overexci- tation Protection. Figure 2-76 illustrates the behaviour of the protection on the assumption that within the frame- work of configuration the setting for the pickup threshold (parameter4302 U/f >) was chosen higher or lower than the first setting value of the thermal characteristic.

  • Page 187: Setting Notes

    Functions 2.24 Overexcitation (Volt/Hertz) Protection (ANSI 24) Figure 2-77 Logic Diagram of the Overexcitation Protection 2.24.2 Setting Notes General Overexcitation protection is only effective and available if address 143 OVEREXC. PROT. is set to Enabled during configuration. If the function is not required, it is set to Disabled. Address 4301 OVEREXC. PROT. serves to switch the function ON or OFF or to block only the trip command (Block relay).
  • Page 188 Thermal tripping time characteristic (with default settings) The characteristic of a Siemens standard transformer was selected as a default setting for the parameters 4306 to 4313. If the protection object manufacturer did not provide any information, the preset standard char- acteristic should be used.

  • Page 189: Settings

    Functions 2.24 Overexcitation (Volt/Hertz) Protection (ANSI 24) 2.24.3 Settings Addr. Parameter Setting Options Default Setting Comments 4301 OVEREXC. PROT. Overexcitation Protection (U/f) Block relay 4302 U/f > 1.00 .. 1.20 1.10 U/f > Pickup 4303 T U/f > 0.00 .. 60.00 sec; ∞ 10.00 sec T U/f >...

  • Page 190: Inverse-Time Undervoltage Protection (Ansi 27)

    Functions 2.25 Inverse-Time Undervoltage Protection (ANSI 27) 2.25 Inverse-Time Undervoltage Protection (ANSI 27) The inverse undervoltage protection mainly protects consumers (induction machines) from the consequences of dangerous voltage drops in island networks thus avoiding inadmissible operating conditions and possible loss of stability. It can also be used as a criterion for load shedding in interconnected networks. Two-pole short circuits or earth faults cause asymmetrical voltage collapse.

  • Page 191: Setting Notes

    Functions 2.25 Inverse-Time Undervoltage Protection (ANSI 27) Figure 2-79 Logic Diagram of the Inverse-Time Undervoltage Protection 2.25.2 Setting Notes General The inverse-time undervoltage protection is only effective and available if this function was set during protective function configuration (Section 2.4, address 144, INV.UNDERVOLT. is set to Enabled. If the function is not required Disabled is set.

  • Page 192: Settings

    Functions 2.25 Inverse-Time Undervoltage Protection (ANSI 27) 2.25.3 Settings Addr. Parameter Setting Options Default Setting Comments 4401 INV. UNDERVOLT. Inverse Undervoltage Protection Up< Block relay 4402 Up< PICKUP 10.0 .. 125.0 V 75.0 V Up< Pickup 4403 T MUL 0.10 .. 5.00 sec; 0 1.00 sec Time Multiplier for Characteristic 4404...

  • Page 193: Rate-Of-Frequency-Change Protection Df/Dt (Ansi 81R)

    Functions 2.26 Rate-of-Frequency-Change Protection df/dt (ANSI 81R) 2.26 Rate-of-Frequency-Change Protection df/dt (ANSI 81R) With the rate-of-frequency-change protection, frequency changes can be quickly detected. This allows a prompt response to frequency dips or frequency rises. A trip command can be issued even before the pickup threshold of the frequency protection (see Section 2.23) is reached.
  • Page 194 Functions 2.26 Rate-of-Frequency-Change Protection df/dt (ANSI 81R) Figure 2-80 Logic Diagram of the Rate-of-Frequency-Change Protection SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 195: Setting Notes

    Functions 2.26 Rate-of-Frequency-Change Protection df/dt (ANSI 81R) 2.26.2 Setting Notes General The rate-of-frequency-change protection is only effective and accessible if during the configuration address 145 df/dt Protect. has been set accordingly. The user can select between 2 or 4 stages. The default setting is 2 df/dt stages.
  • Page 196 Functions 2.26 Rate-of-Frequency-Change Protection df/dt (ANSI 81R) Time Delays The delay time should be set to zero wherever the protection function is supposed to respond very quickly. This will be the case with high setting values. For the monitoring of small changes (< 1Hz/s), on the other hand, a small delay time can be useful to avoid overfunctioning.

  • Page 197: Settings

    Functions 2.26 Rate-of-Frequency-Change Protection df/dt (ANSI 81R) 2.26.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Additional Settings. Addr. Parameter Setting Options Default Setting Comments 4501 df/dt Protect. Rate-of-frequency-change pro- tection Block relay 4502 df1/dt >/<...

  • Page 198: Information List

    Functions 2.26 Rate-of-Frequency-Change Protection df/dt (ANSI 81R) 2.26.4 Information List Information Type of In- Comments formation 5503 >df/dt block >BLOCK Rate-of-frequency-change prot. 5504 >df1/dt block >BLOCK df1/dt stage 5505 >df2/dt block >BLOCK df2/dt stage 5506 >df3/dt block >BLOCK df3/dt stage 5507 >df4/dt block >BLOCK df4/dt stage...

  • Page 199: Jump Of Voltage Vector

    Functions 2.27 Jump of Voltage Vector 2.27 Jump of Voltage Vector Consumers with their own generating plant, for example, feed power directly into a network. The incoming feeder line is usually the technical and legal ownership boundary between the network operator and these con- sumers/producers.
  • Page 200 Functions 2.27 Jump of Voltage Vector Measuring Principle The vector of the positive sequence system voltage is calculated from the phase-to-earth voltages, and the phase angle change of the voltage vector is determined over a delta interval of 2 cycles. The presence of a phase angle jump indicates an abrupt change of current flow.

  • Page 201: Setting Notes

    Functions 2.27 Jump of Voltage Vector Figure 2-83 Logic diagram of the vector jump detection 2.27.2 Setting Notes General The vector jump protection is only effective and available if address 146 VECTOR JUMP is set to Enabled during configuration. Address 4601 VECTOR JUMP serves to switch the function ON or OFF or to block only the trip command (Block relay).

  • Page 202: Settings

    Functions 2.27 Jump of Voltage Vector Time Delays The time delay T DELTA PHI (address 4603) should be left at zero, unless you wish to transmit the trip indi- cation with a delay to a logic (CFC), or to leave enough time for an external blocking to take effect. After expiry of the timer T RESET (address 4604), the protection function is automatically reset.

  • Page 203: Stator Earth Fault Protection (Ansi 59N, 64G, 67G)

    Functions 2.28 90-%-Stator Earth Fault Protection (ANSI 59N, 64G, 67G) 2.28 90-%-Stator Earth Fault Protection (ANSI 59N, 64G, 67G) The stator earth fault protection detects earth faults in the stator windings of three-phase machines. The machine can be operated in busbar connection (directly connected to the network) or in unit connection (via unit transformer).
  • Page 204 Functions 2.28 90-%-Stator Earth Fault Protection (ANSI 59N, 64G, 67G) Figure 2-84 Unit Connection with Neutral Transformer Loading resistance Voltage divider Displacement Voltage Generator earth capacitance Line earth capacitance Unit transformer earth capacitance Unit transformer coupling capacitance coup Figure 2-85 Unit Connection with Earthing Transformer Loading resistance Voltage divider...
  • Page 205 Functions 2.28 90-%-Stator Earth Fault Protection (ANSI 59N, 64G, 67G) Earth Current Direction Detection For machines in busbar connection, it is not possible to differentiate between network earth faults and machine earth faults using the displacement voltage alone. In this case the earth fault current is used as a further crite- rion, and the displacement voltage as a necessary enabling condition.
  • Page 206 Functions 2.28 90-%-Stator Earth Fault Protection (ANSI 59N, 64G, 67G) The protection then detects a machine earth fault if the following three criteria are fulfilled: • Displacement voltage larger than set value U0>, • Earth fault current across the measurement location larger than set value 3I0>, •...
  • Page 207 Functions 2.28 90-%-Stator Earth Fault Protection (ANSI 59N, 64G, 67G) Earth Current Detection (Earth Differential Protection with Displacment Voltage as the Pickup Criterion) In the industrial sector, busbar systems are designed with high or low resistance, switchable starpoint resis- tances. For earth-fault detection, the starpoint current and the total current are detected via toroidal current transformers and transmitted to the protective device as current difference.

  • Page 208: Setting Notes

    Functions 2.28 90-%-Stator Earth Fault Protection (ANSI 59N, 64G, 67G) Figure 2-89 Logic Diagram of 90 % Stator Earth Fault Protection 2.28.2 Setting Notes General 90 % stator earth fault protection is only effective and available if address 150 S/E/F PROT. is set to directional;...
  • Page 209 Functions 2.28 90-%-Stator Earth Fault Protection (ANSI 59N, 64G, 67G) Delay The stator earth fault trip is delayed by the time set under address 5005 T S/E/F. For the delay time, the overload capacity of the load equipment must be considered. All set times are additional delay times and do not include operating times (measurement time, reset time) of the protection function itself.

  • Page 210: Settings

    Functions 2.28 90-%-Stator Earth Fault Protection (ANSI 59N, 64G, 67G) For a protected zone of 90 %, the protection should already operate at 1/10 of the full displacement voltage, whereby only 1/10 of the earth fault current is generated: In this example 3I0> is set to 11 mA. For the displacement voltage setting, 1/10 of the full displacement voltage is used (because of the 90% protected zone).

  • Page 211: Sensitive Earth Fault Protection (Ansi 51Gn, 64R)

    Functions 2.29 Sensitive Earth Fault Protection (ANSI 51GN, 64R) 2.29 Sensitive Earth Fault Protection (ANSI 51GN, 64R) The sensitive earth current protection detects earth faults in systems with isolated or high-impedance earthed starpoint. This stage operates with the magnitudes of the earth current. It is therefore useful in applications where the magnitude of the earth current is an indicator of the earth fault.
  • Page 212 Functions 2.29 Sensitive Earth Fault Protection (ANSI 51GN, 64R) Figure 2-90 Application example as rotor earth fault protection Note 3PP13 is only necessary if more than 0.2 A are flowing permanently; (rule: Uerr load > 150 V). In this case the internal resistors Rpre inside the 7XR61 must be shorted. Figure 2-91 Logic Diagram of the Sensitive Earth Fault Detection Parameters and indications are only visible if Rotor Earth Fault Protection R, fn...

  • Page 213: Setting Notes

    Functions 2.29 Sensitive Earth Fault Protection (ANSI 51GN, 64R) 2.29.2 Setting Notes General The sensitive earth fault protection is only effective and available if address 151 O/C PROT. IEE> = with IEE1 or with IEE2 is assigned. If when configuring the 90 % stator earth fault protection (150 S/E/F PROT., see subsection 2.4) one of the options with current value is chosen, the sensitive current measuring inpu of the device 7UM62 is thus occupied.

  • Page 214: Settings

    Functions 2.29 Sensitive Earth Fault Protection (ANSI 51GN, 64R) 2.29.3 Settings Addr. Parameter Setting Options Default Setting Comments 5101 O/C PROT. IEE Sensitive Earth Current Protec- tion Block relay 5102 IEE> 2 .. 1000 mA 10 mA IEE> Pickup 5103 T IEE>...

  • Page 215: Stator Earth Fault Protection With 3Rd Harmonics (Ansi 27/59Tn 3Rd Harm.)

    Functions 2.30 100-%-Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) 2.30 100-%-Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) The measurement method described in section 2.28 is based on the fundamental wave of the displacement voltage and allows protecting up to 90 % to 95 % of the stator winding.
  • Page 216 Functions 2.30 100-%-Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) Measuring Principle The content of the 3rd harmonic in the measurement value is the pickup criterion. The 3rd harmonic is deter- mined from the displacement voltage measured over two cycles by means of digital filtering. Different measuring procedures are applied, depending on how the displacement voltage is detected (config- uration parameter 223 UE CONNECTION): neutr.
  • Page 217 Functions 2.30 100-%-Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) Automatic Lowering of Pickup Value U0 3.HARM> Figure 2-93 The trip characteristic is released as soon as the settable minimum active power is reached. As an additional security feature, the following limitation is provided: If due to the power-dependent correction factor the correct- ed pickup value U drops below the minimum possible setting value (0,2 V), the pickup value will be...
  • Page 218 Functions 2.30 100-%-Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) Figure 2-94 Logic diagram of the 100% stator earth fault protection SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 219: Setting Notes

    Functions 2.30 100-%-Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) 2.30.2 Setting Notes General The 100 % stator earth fault protection is only effective and available if address 152 SEF 3rd HARM. = Enabled is set during configuration. If the function is not required Disabled is set. Address 5201 SEF 3rd HARM.
  • Page 220 Functions 2.30 100-%-Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) Figure 2-95 3rd harmonic secondary voltage as a function of the active power (reactive power as parame- ter) As Figure 2-95 shows, the rise is almost equal in both cases. The most unfavourable case is operation in un- derexcitation conditions.
  • Page 221 Functions 2.30 100-%-Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) Figure 2-96 3. harmonic secondary voltage as a function of the active power referred to S (extrapo- N device lation of this voltage and final characteristic) With 100 % active power the extrapolated value is (U ) 12.7 V.

  • Page 222: Settings

    Functions 2.30 100-%-Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) Operating Range Due to the strong dependency of the measurable 3rd harmonic from the corresponding working point of the generator, the working area of the 100–%–stator earth fault protection is only tripped above the active-power threshold set via 5205 P min >...

  • Page 223: Stator Earth Fault Protection With 20 Hz Voltage Injection (Ansi 64G - 100%)

    Functions 2.31 100-%-Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G - 100%) 2.31 100-%-Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G - 100%) The 100 % stator earth fault protection detects earth faults in the stator windings of generators which are con- nected with the network via a unit transformer.
  • Page 224 Functions 2.31 100-%-Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G - 100%) To prevent the secondary load resistance from becoming too small (it should be greater than 0.5 Ω where pos- sible), a high secondary rated voltage should be chosen for the earthing or neutral transformer. 500 V has proven to be a practical value.
  • Page 225 Functions 2.31 100-%-Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G - 100%) Logic The following figure shows the logic diagram. It comprises: • Monitoring of the 20 Hz connection • Resistance calculation and threshold value decision • Independent current measurement stage The protection function has an alarm stage and a tripping stage.

  • Page 226: Setting Notes

    Functions 2.31 100-%-Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G - 100%) 2.31.2 Setting Notes General The 100 % stator earth fault protection is only effective and available if address 153 100% SEF-PROT. is set to Enabled during configuration. In addition, the function requires the following settings to be made in Power System Data 1: •...
  • Page 227 Functions 2.31 100-%-Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G - 100%) This formula applies only for almost ideal earthing or neutral transformers. If necessary, the measuring result from the primary tests must be set as FACTOR R SEF. For this the inserted fault resistance (trip stage) is related to the measured secondary fault resistance.
  • Page 228 Functions 2.31 100-%-Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G - 100%) Correction Angle, Transfer Resistance The parameter PHI I SEF (default setting 0 °) at address 5309 is used to compensate the angle errors of the CTs and angle distortions caused by a nonideal earthing or neutral transformer.
  • Page 229 Functions 2.31 100-%-Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G - 100%) A two pole isolated voltage transformer must be used with low primary/secondary impedance. This applies for the 20 Hz frequency. Primary voltage: / √3 N,Generator (non-saturated up to U N,Generator Secondary voltage:...

  • Page 230: Settings

    Functions 2.31 100-%-Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G - 100%) Trip stage: primary 2 kΩ, secondary 66 Ω Alarm stage: primary 5 kΩ, secondary 165 Ω 2.31.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Additional Settings. Addr.

  • Page 231: Sensitive Earth Fault Protection B (Ansi 51Gn)

    Functions 2.32 Sensitive Earth Fault Protection B (ANSI 51GN) 2.32 Sensitive Earth Fault Protection B (ANSI 51GN) The IEE-B sensitive earth current protection feature of 7UM62 provides greater flexibility and can be used for the following applications. Applications • Earth current monitoring to detect earth faults (generator stator, terminal lead, transformer). •...
  • Page 232 Functions 2.32 Sensitive Earth Fault Protection B (ANSI 51GN) Figure 2-101 Connection of the shaft current transformer (possible current flow in the event of a fault) The shaft current transformer has to be purchased separately from a transformer manufacturer, or the existing shaft current transformer can be used when replacing the protection.
  • Page 233 Functions 2.32 Sensitive Earth Fault Protection B (ANSI 51GN) Measurement Method In order to preserve the flexibility of the application, there are different measurement methods available for pro- cessing the sensitive earth current. The protection setting determines the measurement method to be used. In algorithmic terms, this means that the FIR filter parameters have to be modified.

  • Page 234: Setting Notes

    Functions 2.32 Sensitive Earth Fault Protection B (ANSI 51GN) 2.32.2 Setting Notes General The sensitive earth fault protection IEE-B is only effective and available if configured to with IEE1 or with IEE2 at address 154. If the sensitive earth fault detection IEE-B is not required, Disabled is set. Address 5401serves to switch the function ON or OFF or to block only the trip command (Block relay).

  • Page 235: Settings

    Functions 2.32 Sensitive Earth Fault Protection B (ANSI 51GN) 2.32.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Additional Settings. Addr. Parameter Setting Options Default Setting Comments 5401 O/C PROT IEE-B Sensitive O/C Protection B Block relay Alarm Only 5402...

  • Page 236: Interturn Protection (Ansi 59N (It))

    Functions 2.33 Interturn Protection (ANSI 59N (IT)) 2.33 Interturn Protection (ANSI 59N (IT)) The interturn fault protection detects faults between turns within a generator winding (phase). This situation may involve relatively high circulating currents that flow in the short-circuited turns and damage the winding and the stator.
  • Page 237 Functions 2.33 Interturn Protection (ANSI 59N (IT)) Figure 2-105 Alternative connection of the interturn fault protection The wide setting range allows the protective function to be used also as single-stage, single-phase overvoltage protection. Measurement Method The U input of the protection is connected as shown in Figure 2-104 or 2-105. An FIR filter determines the fundamental component of the voltage based on the scanned displacement voltage.

  • Page 238: Setting Notes

    Functions 2.33 Interturn Protection (ANSI 59N (IT)) 2.33.2 Setting Notes General The interturn fault protection is only in effect and accessible if address 155 INTERTURN PROT is set to during configuration of protective functions. Also it has to be specified in the Power System Data 1 that the input U is used for the interturn fault protection.

  • Page 239: Settings

    Functions 2.33 Interturn Protection (ANSI 59N (IT)) 2.33.3 Settings Addr. Parameter Setting Options Default Setting Comments 5501 INTERTURN PROT Interturn Protection Block relay 5502 U Interturn > 0.3 .. 130.0 V 2.0 V Pick up Value U Interturn> 5503 T-U Interturn > 0.00 ..

  • Page 240: Rotor Earth Fault Protection R, Fn (Ansi 64R)

    Functions 2.34 Rotor Earth Fault Protection R, fn (ANSI 64R) 2.34 Rotor Earth Fault Protection R, fn (ANSI 64R) Rotor earth fault protection is used to detect earth faults in the excitation circuit of synchronous machines. An earth fault in the rotor winding does not cause immediate damage; however, if a second earth fault occurs it constitutes a winding short-circuit of the excitation circuit.
  • Page 241 Functions 2.34 Rotor Earth Fault Protection R, fn (ANSI 64R) The rotor earth fault protection calculates the complex earth impedance from the auxiliary AC voltage U the current I . The earth resistance R of the excitation circuit is then calculated from the earth impedance. The coupling capacitance of the coupling unit C , the series resistance R including the brush resistance,...

  • Page 242: Setting Notes

    Functions 2.34 Rotor Earth Fault Protection R, fn (ANSI 64R) 2.34.2 Setting Notes General Rotor earth fault protection protection is only effective and accessible if address 160 ROTOR E/F has been set = to Enabled. If the function is not required Disabled is set. Address 6001 ROTOR E/F serves to switch the function ON or OFF or to block only the trip command (Block relay).
  • Page 243 Functions 2.34 Rotor Earth Fault Protection R, fn (ANSI 64R) The series resistors R for the protection of the coupling capacitors can be considered with the total series re- sistance (address 6007) since the brush resistance and the series resistance are connected in series in the measurement circuit.

  • Page 244: Settings

    Functions 2.34 Rotor Earth Fault Protection R, fn (ANSI 64R) 2.34.3 Settings Addr. Parameter Setting Options Default Setting Comments 6001 ROTOR E/F Rotor Earth Fault Protection (R, Block relay 6002 RE< WARN 3.0 .. 30.0 kΩ 10.0 kΩ Pickup Value of Warning Stage Re<...

  • Page 245: Sensitive Rotor Earth Fault Protection With 1 To 3 Hz Square Wave Voltage Injection (Ansi 64R - 1 To 3 Hz)

    Functions 2.35 Sensitive Rotor Earth Fault Protection with 1 to 3 Hz Square Wave Voltage Injection (ANSI 64R - 1 to 3 Hz) 2.35 Sensitive Rotor Earth Fault Protection with 1 to 3 Hz Square Wave Voltage Injection (ANSI 64R - 1 to 3 Hz) The rotor earth fault protection detects high and low resistance earth faults in the excitation circuit of synchro- nous generators.
  • Page 246 Functions 2.35 Sensitive Rotor Earth Fault Protection with 1 to 3 Hz Square Wave Voltage Injection (ANSI 64R - 1 to 3 Hz) Measurement Method From the control voltage U , the function determines the timing for the polarity reversals and triggers the mea- Ctrl surement.
  • Page 247 Functions 2.35 Sensitive Rotor Earth Fault Protection with 1 to 3 Hz Square Wave Voltage Injection (ANSI 64R - 1 to 3 Hz) Monitoring Functions On each polarity reversal, the charging current of the earth capacitance is determined. If this is undershot, errors in the measuring circuit such as wire break, poor brush contacts etc.
  • Page 248 Functions 2.35 Sensitive Rotor Earth Fault Protection with 1 to 3 Hz Square Wave Voltage Injection (ANSI 64R - 1 to 3 Hz) Logic The logic diagram shows the parts: • Monitoring of the series device • Supervision of the measurement circuit •...

  • Page 249: Setting Notes

    Functions 2.35 Sensitive Rotor Earth Fault Protection with 1 to 3 Hz Square Wave Voltage Injection (ANSI 64R - 1 to 3 Hz) 2.35.2 Setting Notes General Sensitive rotor earth fault protection is only effective and available if configured at address 161 REF 1-3Hz to Enabled.

  • Page 250: Settings

    Functions 2.35 Sensitive Rotor Earth Fault Protection with 1 to 3 Hz Square Wave Voltage Injection (ANSI 64R - 1 to 3 Hz) 2.35.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Additional Settings. Addr.

  • Page 251: Motor Starting Time Supervision (Ansi 48)

    Functions 2.36 Motor Starting Time Supervision (ANSI 48) 2.36 Motor Starting Time Supervision (ANSI 48) When using the 7UM62 to protect motors, the motor starting protection supplements the overload protection described in Section 2.11 by protecting the motor against too long starting procedures. In particular, rotor-criti- cal high-voltage motors can quickly be heated above their thermal limits when multiple starting attempts occur in a short period of time.
  • Page 252 Functions 2.36 Motor Starting Time Supervision (ANSI 48) Therefore, if the starting current I actually measured is smaller (or larger) than the nominal starting current I Start- entered at address 6502 (parameter START. CURRENT), the actual tripping time t is lengthened (or Curr TRIP shortened) accordingly (see also Figure 2-114).

  • Page 253: Setting Notes

    Functions 2.36 Motor Starting Time Supervision (ANSI 48) 2.36.2 Setting Notes General Startup Time Monitoring is only active and available if address 165 STARTUP MOTOR was set to Enabled during configuration. If the function is not required, it is set to Disabled. Address 6501 STARTUP MOTOR serves to switch the function ON or OFF or to block only the trip command (Block relay).

  • Page 254: Settings

    Functions 2.36 Motor Starting Time Supervision (ANSI 48) Under nominal conditions, the tripping time is the maximum starting time t . For ratios deviating from Start max nominal conditions, the motor tripping time changes. At 80% of nominal voltage (which corresponds to 80% of nominal starting current), the tripping time is for example: After the delay time LOCK ROTOR TIME has expired, the binary input becomes effective and initiates a tripping signal.

  • Page 255: Restart Inhibit For Motors (Ansi 66, 49Rotor)

    Functions 2.37 Restart Inhibit for Motors (ANSI 66, 49Rotor) 2.37 Restart Inhibit for Motors (ANSI 66, 49Rotor) The rotor temperature of a motor generally remains well below its admissible limit temperature during normal operation and also under increased load conditions. However, with startups and resulting high startup currents caused by small thermal time constants of the rotor it may suffer more thermal damage than the stator.
  • Page 256 Functions 2.37 Restart Inhibit for Motors (ANSI 66, 49Rotor) Although the heat distribution at the rotor cage bars can range widely during motor startup, the different maximum temperatures in the rotor do not necessarily affect the motor restart inhibit (see Figure 2-116). It is much more important to establish a thermal profile, after a complete motor startup, that is appropriate for pro- tection of the motor's thermal state.
  • Page 257 Functions 2.37 Restart Inhibit for Motors (ANSI 66, 49Rotor) Prolonging the Cooling Time Constant In order to properly account for the reduced heat removal when a self-ventilated motor is stopped, the cooldown time constant can be increased relative to the time constants for a running machine with the factor Kτ at STOP (address 6608).
  • Page 258 Functions 2.37 Restart Inhibit for Motors (ANSI 66, 49Rotor) Logic The thermal profile can also be reset via a binary input. This may be useful for testing and commissioning, and after power supply voltage restoration. The following figure shows the logic diagram for the restart inhibit. Figure 2-117 Logic diagram of the Restart Inhibit SIPROTEC, 7UM62, Manual...

  • Page 259: Setting Notes

    Functions 2.37 Restart Inhibit for Motors (ANSI 66, 49Rotor) 2.37.2 Setting Notes General Restart inhibit is only effective and available if address 166 RESTART INHIBIT was set to Enabled during configuration. If the function is not required Disabled is set. Address 6601RESTART INHIBIT serves to switch the function ON or OFF or to block only the trip command (Block relay).
  • Page 260 Functions 2.37 Restart Inhibit for Motors (ANSI 66, 49Rotor) The following settings are made: IStart/IMOTnom . = 4.9 T START MAX . = 8.5 sec MAX.WARM STARTS . #COLD-#WARM . For the rotor temperature equilibrium time, a setting of approx. T EQUAL = 1.0 min has proven to be a practical value.
  • Page 261 Functions 2.37 Restart Inhibit for Motors (ANSI 66, 49Rotor) In Figure 2-119, the motor is also restarted twice in warm condition, but the pause between the restart attempts is longer than in the first example. After the second restart attempt, the motor is operated at 90 % nominal cur- rent.

  • Page 262: Settings

    Functions 2.37 Restart Inhibit for Motors (ANSI 66, 49Rotor) 2.37.3 Settings Addr. Parameter Setting Options Default Setting Comments 6601 RESTART INHIBIT Restart Inhibit for Motors Block relay 6602 IStart/IMOTnom 1.5 .. 10.0 I Start / I Motor nominal 6603 T START MAX 3.0 ..

  • Page 263: Breaker Failure Protection (Ansi 50Bf)

    Functions 2.38 Breaker Failure Protection (ANSI 50BF) 2.38 Breaker Failure Protection (ANSI 50BF) The breaker failure protection can be assigned to the current inputs of side 1 or side 2 during configuration of the protective functions (see Section 2.4). The breaker failure protection monitors whether the associated circuit breaker is opened correctly.
  • Page 264 Functions 2.38 Breaker Failure Protection (ANSI 50BF) Criteria The two pickup criteria (current criterion, circuit breaker auxiliary contact) are OR-combined. In case of a trip- ping without short circuit current, e.g. for voltage protection on light load, the current is not a safe criterion for circuit breaker response.
  • Page 265 Functions 2.38 Breaker Failure Protection (ANSI 50BF) Figure 2-121 Logic Diagram of the Breaker Failure Protection SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 266: Setting Notes

    Functions 2.38 Breaker Failure Protection (ANSI 50BF) 2.38.2 Setting Notes General Breaker failure protection is only effective and available if address 170 BREAKER FAILURE is set to Side 1 or Side 2 during configuration. If the function is not required Disabled is set. Address 7001 BREAKER FAILURE serves to switch the function ON or OFF or to block only the trip command (Block relay).

  • Page 267: Settings

    Functions 2.38 Breaker Failure Protection (ANSI 50BF) 2.38.3 Settings The table indicates region-specific presettings. Column C (configuration) indicates the corresponding second- ary nominal current of the current transformer. Addr. Parameter Setting Options Default Setting Comments 7001 BREAKER FAILURE Breaker Failure Protection Block relay 7002 TRIP INTERN...

  • Page 268: Inadvertent Energization (Ansi 50, 27)

    Functions 2.39 Inadvertent Energization (ANSI 50, 27) 2.39 Inadvertent Energization (ANSI 50, 27) The inadvertent energization protection has the task to limit damage caused by the accidental energization of the stationary or already started, but not yet synchronized generator by quickly actuating the generator circuit breaker.

  • Page 269: Setting Notes

    Functions 2.39 Inadvertent Energization (ANSI 50, 27) 2.39.2 Setting Notes General Inadvertent energizing protection is only effective and available if address 171 INADVERT. EN. is set to Enabled during configuration. If the function is not required Disabled is set. Address 7101 INADVERT. EN. serves to switch the function ON or OFF or to block only the trip command (Block relay).

  • Page 270: Settings

    Functions 2.39 Inadvertent Energization (ANSI 50, 27) 2.39.3 Settings The table indicates region-specific presettings. Column C (configuration) indicates the corresponding second- ary nominal current of the current transformer. Addr. Parameter Setting Options Default Setting Comments 7101 INADVERT. EN. Inadvertent Energisation Block relay 7102 I STAGE...

  • Page 271: Dc Voltage/Current Protection (Ansi 59Ndc/51Ndc)

    Functions 2.40 DC Voltage/Current Protection (ANSI 59NDC/51NDC) 2.40 DC Voltage/Current Protection (ANSI 59NDC/51NDC) To detect DC voltages, DC currents and small AC quantities, the 7UM62 is equipped with a measuring trans- ducer input (TD1) that can be used either for voltages (± 10V) or currents (± 20mA). Higher DC voltages are connected via an external voltage divider.
  • Page 272 Functions 2.40 DC Voltage/Current Protection (ANSI 59NDC/51NDC) Earth Fault Detection in the Startup Converter If an earth fault occurs in the startup converter circuit, a current flows through all earthed parts of the system because of the DC voltage. As earthing and neutral transformers have a lower ohmic resistance than voltage transformers, the thermal load is the highest on them.

  • Page 273: Setting Notes

    Functions 2.40 DC Voltage/Current Protection (ANSI 59NDC/51NDC) 2.40.2 Setting Notes General The DC voltage protection is only effective and available if set to Enabled at address 172 DC PROTECTION. If the function is not required, Disabled is set. For the associated measuring transducer 1, address 295 TRANSDUCER 1 was set to one of the alternatives 10 V, 4-20 mA or 20 mA (see section 2.5).

  • Page 274: Settings

    Functions 2.40 DC Voltage/Current Protection (ANSI 59NDC/51NDC) If we assume that the earthing transformer has an ohmic winding resistance of R ≈ 150 Ω, a DC current of I 945 V/150 Ω = 6.3 A will flow through its starpoint. Note: The ohmic winding resistances of earthing and neutral transformers can differ widely depending on the type.

  • Page 275: Analog Outputs

    Functions 2.41 Analog Outputs 2.41 Analog Outputs Depending on the variant ordered, the 7UM62 machine protection can have up to four analog outputs (plug-in modules on ports B and D). Starting from firmware version 4.62, the device features a universal analog output (type 2) for additional select- ed measured values.
  • Page 276 Functions 2.41 Analog Outputs For measured values that can also be negative (power, power factor), absolute values are formed and output in the type-1 analog output. The analog output type 2 (additionally available starting from firmware version V4.62) allows the negative values to be output as well (see 2.41.2, example 2). Analog values are output as injected currents.

  • Page 277: Setting Notes

    Functions 2.41 Analog Outputs 2.41.2 Setting Notes General You have specified during configuration of the analog outputs (Section 2.4.2, addresses173 to 176) for analog output type 1 and addresses 200 to 203 for analog output type 2 which of the analog inputs in the device will be used for which measured value.
  • Page 278 Functions 2.41 Analog Outputs Example 1: The positive sequence components of the currents are to be output as analog output B1 at location "B". 10 mA is to be the value at nominal operational current, consequently 20 mA corresponds to 200 %. Values below 1 mA are invalid.
  • Page 279 Functions 2.41 Analog Outputs The following diagram illustrates the relationships. Figure 2-129 Definition of output range display for type 2 Example 2: The reactive power Q is to be output over analog output D1 with a sign and between 4 to 20 mA. A reactive power Q = 0 % is to be equivalent to a current value of 12 mA.
  • Page 280 Functions 2.41 Analog Outputs Figure 2-130 Example of a reactive power Q output If the machine is run with cos j = 0.8, the resulting active power is 80 % referring to the apparent power. The reactive power is correspondingly 60 % of the apparent power. This measured reactive power value results in an output value of 18 mA.

  • Page 281: Settings

    Functions 2.41 Analog Outputs 2.41.3 Settings Addr. Parameter Setting Options Default Setting Comments 7301 20 mA (B1/1) = 10.0 .. 1000.0 % 200.0 % 20 mA (B1/1) correspond to 7302 MIN VALUE(B1/1) 0.0 .. 5.0 mA 1.0 mA Output value (B1/1) valid from 7303 20 mA (B2/1) = 10.0 ..

  • Page 282: Monitoring Functions

    Functions 2.42 Monitoring Functions 2.42 Monitoring Functions The device is equipped with extensive monitoring capabilities - both for hardware and software. In addition, the measured values are also constantly monitored for plausibility, therefore, the current transformer and voltage transformer circuits are largely integrated into the monitoring. 2.42.1 Measurement Supervision 2.42.1.1 Hardware Monitoring...
  • Page 283 Functions 2.42 Monitoring Functions Measurement Value Acquisition – Currents In the current paths there are three input transformers each on side 1 and side 2; the digitized sum of the trans- former currents of one side must be almost zero for generators with isolated starpoint during earth-fault-free operation.

  • Page 284: Software Monitoring

    Functions 2.42 Monitoring Functions Note Voltage sum monitoring is only effective if an external displacement voltage is connected at the displacement voltage measuring input and this is also notified via the parameter 223 UE CONNECTION to the device. Voltage sum monitoring can operate properly only if the adaptation factor Uph / Udelta at address 225 has been correctly configured (see Subsection 2.5.1).

  • Page 285: Monitoring Of External Transformer Circuits

    Functions 2.42 Monitoring Functions 2.42.1.3 Monitoring of External Transformer Circuits Interruptions or short circuits in the secondary circuits of the current and voltage transformers, as well as faults in the connections (important for commissioning!), are detected and reported by the device. The measured values are cyclically checked in background routines for this purpose, as long as no system fault is present.
  • Page 286 Functions 2.42 Monitoring Functions This malfunction is reported as „Fail U balance“. If the 90% stator earth fault protection functions are active, a zero voltage results on voltage asymmetry. If this causes protection pickup, monitoring is relegated to the background and issues no indication. Figure 2-134 Voltage symmetry monitoring Phase Sequences of Current and Voltage...

  • Page 287: Setting Notes

    Functions 2.42 Monitoring Functions 2.42.1.4 Setting Notes Measured Value Monitoring Measured value monitoring can be turned ON or OFF at address 8101 MEASURE. SUPERV. In addition, the sensitivity of measured value monitoring can be modified. Experiential values set ex works are sufficient in most cases.

  • Page 288: Information List

    Functions 2.42 Monitoring Functions Addr. Parameter Setting Options Default Setting Comments 8107 BAL. FACT. I S2 0.10 .. 0.90 0.50 Balance Factor for Current Monitor S2 8108 SUM.thres. U 10 .. 200 V 10 V Summation Thres. for Volt. Monitoring 8109 SUM.Fact.

  • Page 289: Supervision

    Functions 2.42 Monitoring Functions 2.42.2 Supervision 2.42.2.1 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. The measuring results of the undervoltage protection, the impedance protection and other voltage-dependent protective functions may be falsified in this way, possibly causing an unwanted operation.
  • Page 290 Functions 2.42 Monitoring Functions Additional Criteria In addition to this, the function can either be blocked via a binary input or deactivated by an undervoltage pro- tection at a separate voltage transformer set. If an undervoltage is also detected at a separate transformer set, this is most probably not due to a transformer error and the monitoring switching can be blocked.

  • Page 291: Malfunction Responses Of The Monitoring Functions

    Functions 2.42 Monitoring Functions 2.42.2.2 Malfunction Responses of the Monitoring Functions Depending on the type of malfunction detected, an indication is sent, a restart of the processor system initiated, or the device is taken out of service. After three unsuccessful restart attempts, the device is also taken out of service.
  • Page 292 Functions 2.42 Monitoring Functions Table 2-14 Summary of Malfunction Responses by the Protection Relay Monitoring Possible Causes Malfunction Message (No.) Output Response Auxiliary Supply Voltage External (aux. voltage) in- Device nonoperational all LEDs dark drops out Loss ternal (converter) Internal Supply Voltages Internal (converter) or refer- Device shutdown LED ”ERROR"...

  • Page 293: Setting Notes

    Functions 2.42 Monitoring Functions Monitoring Possible Causes Malfunction Message (No.) Output Response Current Phase Sequence External Indication „FailPh.Seq I S2“ as allocated Side 2 (power system or connec- (No. 266) tion) Fuse Failure Monitor External Indication „VT Fuse Failure“ as allocated (voltage transformer) (No.

  • Page 294: Information List

    Functions 2.42 Monitoring Functions 2.42.2.5 Information List Information Type of In- Comments formation Clock SyncError Clock Synchronization Error Event Lost OUT_Ev Event lost Flag Lost Flag Lost Error Sum Alarm Error with a summary alarm Error PwrSupply Error Power Supply Alarm Sum Event Alarm Summary Event Fail Battery...

  • Page 295: Trip Circuit Supervision

    Functions 2.43 Trip Circuit Supervision 2.43 Trip Circuit Supervision The 7UM62 multifunctional protection features an integrated trip circuit supervision. Depending on the number of available binary inputs (connected or not connected to a common potential), monitoring with one or two binary inputs can be selected.
  • Page 296 Functions 2.43 Trip Circuit Supervision The state where both binary inputs are not energized („L“) is only present during a short transition phase (trip relay contact is closed, but the circuit breaker has not yet opened) if the trip circuit is healthy. A continuous state of this condition is only possible when the trip circuit has been interrupted, a short-circuit exists in the trip circuit, battery voltage failure occurs, or malfunctions occur with the circuit breaker mechanism.
  • Page 297 Functions 2.43 Trip Circuit Supervision Figure 2-138 Principle of trip circuit monitor with two binary inputs (connected to common potential) Depending on the switching state of the trip relay and circuit breaker, the binary inputs are initiated (logic state „H“ in the table below) or short circuited (logic state „L“). Table 2-16 Condition Table for Binary Inputs, depending on RTC and CB Position Trip contact...
  • Page 298 Functions 2.43 Trip Circuit Supervision Monitoring with One Binary Input The binary input is connected in parallel to the respective command relay contact of the protection device ac- cording to the following figure. The circuit breaker auxiliary contact is bridged with a high-ohmic equivalent re- sistor R.

  • Page 299: Setting Notes

    Functions 2.43 Trip Circuit Supervision Figure 2-140 Logic diagram for Trip Circuit Monitoring with one binary input The following figure shows the logic diagram for the message that can be generated by the trip circuit monitor, depending on the control settings and binary inputs. Figure 2-141 Message Logic of the Trip Circuit Supervision 2.43.2...
  • Page 300 Functions 2.43 Trip Circuit Supervision Monitoring with One Binary Input Note: When using only one binary input (BI) for the trip circuit monitor, some malfunctions, such as interruption of the trip circuit or loss of battery voltage, can indeed be detected, but malfunctions with closed trip contacts cannot.

  • Page 301: Settings

    Functions 2.43 Trip Circuit Supervision Example: 1.8 mA (SIPROTEC 4 7UM62) BI (HIGH) 19 V for delivery setting for nominal voltage 24/48/60 V (from 7UM62), 88 V for delivery BI min setting for nominal voltage 110/125/220/250 V) (from 7UM62) 110 V (system / trip circuit) 500 Ω...

  • Page 302: Threshold Supervision

    Functions 2.44 Threshold supervision 2.44 Threshold supervision This function monitors the thresholds of selected measured values (for overshoot or undershoot). The process- ing speed of this function is so high that it can be used for protection applications. The necessary logical com- binations can be implemented by means of CFC.
  • Page 303 Functions 2.44 Threshold supervision Measured Value Scaling Explanation /√3) · 100 % The voltage connected to the U input is processed directly, and UL3E L3prim N,G,M (phase-earth volt- (normalized via addr. 251/√3) converted into the primary phase-earth voltage. The calculation is age) performed once per cycle.
  • Page 304 Functions 2.44 Threshold supervision Measured Value Scaling Explanation /0.5 A · 100 % The fundamental frequency component is determined from the IEE2 (Sensitive earth current connected to the I input. The calculation is performed current) once per cycle. Note: Unlike the scaling of the operational measured values, scaling is not to primary values.
  • Page 305 Functions 2.44 Threshold supervision The following figure shows an overview of the logic. Figure 2-142 Logic of the Threshold Supervision The figure shows that the measured values can be freely allocated to the threshold supervision blocks. The dropout ratio for the MVx> stage is 0.95 or 1 %. Accordingly, it is 1.05 or 1 % for the MVx< stage. SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 306: Setting Notes

    Functions 2.44 Threshold supervision 2.44.2 Setting Notes General The threshold supervision function is only effective and accessible if address 185 THRESHOLD has been set to Enabled during the configuration of the protection functions. Pickup Values The pickup values are set as percentages. Note the scaling factors listed in the Measured values table. The measured values for power P, Q, ΔP and cosϕ...
  • Page 307 Functions 2.44 Threshold supervision Addr. Parameter Setting Options Default Setting Comments 8501 MEAS. VALUE 1> Disabled Disabled Measured Value for Threshold MV1> Delta P UL1E UL2E UL3E UE3h IEE1 IEE2 Transducer 1 8502 THRESHOLD MV1> -200 .. 200 % 100 % Pickup Value of Measured Value MV1>...
  • Page 308 Functions 2.44 Threshold supervision Addr. Parameter Setting Options Default Setting Comments 8505 MEAS. VALUE 3> Disabled Disabled Measured Value for Threshold MV3> Delta P UL1E UL2E UL3E UE3h IEE1 IEE2 Transducer 1 8506 THRESHOLD MV3> -200 .. 200 % 100 % Pickup Value of Measured Value MV3>...
  • Page 309 Functions 2.44 Threshold supervision Addr. Parameter Setting Options Default Setting Comments 8509 MEAS. VALUE 5> Disabled Disabled Measured Value for Threshold MV5> Delta P UL1E UL2E UL3E UE3h IEE1 IEE2 Transducer 1 8510 THRESHOLD MV5> -200 .. 200 % 100 % Pickup Value of Measured Value MV5>...
  • Page 310 Functions 2.44 Threshold supervision Addr. Parameter Setting Options Default Setting Comments 8513 MEAS. VALUE 7> Disabled Disabled Measured Value for Threshold MV7> Delta P UL1E UL2E UL3E UE3h IEE1 IEE2 Transducer 1 8514 THRESHOLD MV7> -200 .. 200 % 100 % Threshold of Measured Value MV7>...
  • Page 311 Functions 2.44 Threshold supervision Addr. Parameter Setting Options Default Setting Comments 8517 MEAS. VALUE 9> Disabled Disabled Measured Value for Threshold MV9> Delta P UL1E UL2E UL3E UE3h IEE1 IEE2 Transducer 1 8518 THRESHOLD MV9> -200 .. 200 % 100 % Threshold of Measured Value MV9>...

  • Page 312: Information List

    Functions 2.44 Threshold supervision 2.44.4 Information List Information Type of In- Comments formation 7960 Meas. Value1> Measured Value MV1> picked up 7961 Meas. Value2< Measured Value MV2< picked up 7962 Meas. Value3> Measured Value MV3> picked up 7963 Meas. Value4< Measured Value MV4<...

  • Page 313: External Trip Functions

    Functions 2.45 External Trip Functions 2.45 External Trip Functions Any signals from external protection or supervision units can be incorporated and processed in the digital machine protection 7UM62 via binary inputs. Like the internal signals, they can be signaled, time delayed, transmitted to the trip matrix, and also individually blocked.
  • Page 314 Functions 2.45 External Trip Functions Addr. Parameter Setting Options Default Setting Comments 8601 EXTERN TRIP 1 External Trip Function 1 Block relay 8602 T DELAY 0.00 .. 60.00 sec; ∞ 1.00 sec Ext. Trip 1 Time Delay 8701 EXTERN TRIP 2 External Trip Function 2 Block relay 8702...

  • Page 315: Information List

    Functions 2.45 External Trip Functions 2.45.4 Information List Information Type of In- Comments formation 4523 >BLOCK Ext 1 >Block external trip 1 4526 >Ext trip 1 >Trigger external trip 1 4531 Ext 1 OFF External trip 1 is switched OFF 4532 Ext 1 BLOCKED External trip 1 is BLOCKED...

  • Page 316: Temperature Detection By Thermoboxes

    Functions 2.46 Temperature Detection by Thermoboxes 2.46 Temperature Detection by Thermoboxes Up to two RTD boxes with a total of 12 measuring points can be used for temperature detection and evaluated by the protection device. In particular they enable the thermal status of motors, generators and transformers to be monitored.

  • Page 317: Setting Notes

    Functions 2.46 Temperature Detection by Thermoboxes Figure 2-144 Logic Diagram for Temperature Processing 2.46.2 Setting Notes General The temperature detection is only active and accessible if it has been assigned to a port during configuration of the protection functions (Section 2.4). At address 190 RTD-BOX INPUT the RTD box(es) is allocated to the port at which it will be operated (e.g.
  • Page 318 Functions 2.46 Temperature Detection by Thermoboxes Furthermore, you can set an alarm temperature and a tripping temperature. Depending on the temperature unit selected in the Power System Data (Section 2.4.2 in address 276 TEMP. UNIT), the alarm temperature can be expressed in Celsius (°C) (address 9013 RTD 1 STAGE 1) or Fahrenheit (°F) (address 9014 RTD 1 STAGE 1).

  • Page 319: Settings

    Functions 2.46 Temperature Detection by Thermoboxes 2.46.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Additional Settings. Addr. Parameter Setting Options Default Setting Comments 9011A RTD 1 TYPE Not connected Pt 100 Ω RTD 1: Type Pt 100 Ω...
  • Page 320 Functions 2.46 Temperature Detection by Thermoboxes Addr. Parameter Setting Options Default Setting Comments 9034 RTD 3 STAGE 1 -58 .. 482 °F; ∞ 212 °F RTD 3: Temperature Stage 1 Pickup 9035 RTD 3 STAGE 2 -50 .. 250 °C; ∞ 120 °C RTD 3: Temperature Stage 2 Pickup...
  • Page 321 Functions 2.46 Temperature Detection by Thermoboxes Addr. Parameter Setting Options Default Setting Comments 9063 RTD 6 STAGE 1 -50 .. 250 °C; ∞ 100 °C RTD 6: Temperature Stage 1 Pickup 9064 RTD 6 STAGE 1 -58 .. 482 °F; ∞ 212 °F RTD 6: Temperature Stage 1 Pickup...
  • Page 322 Functions 2.46 Temperature Detection by Thermoboxes Addr. Parameter Setting Options Default Setting Comments 9092A RTD 9 LOCATION Other RTD 9: Location Ambient Winding Bearing Other 9093 RTD 9 STAGE 1 -50 .. 250 °C; ∞ 100 °C RTD 9: Temperature Stage 1 Pickup 9094 RTD 9 STAGE 1...
  • Page 323 Functions 2.46 Temperature Detection by Thermoboxes Addr. Parameter Setting Options Default Setting Comments 9121A RTD12 TYPE Not connected Not connected RTD12: Type Pt 100 Ω Ni 120 Ω Ni 100 Ω 9122A RTD12 LOCATION Other RTD12: Location Ambient Winding Bearing Other 9123 RTD12 STAGE 1...

  • Page 324: Information List

    Functions 2.46 Temperature Detection by Thermoboxes 2.46.4 Information List Information Type of In- Comments formation 14101 Fail: RTD Fail: RTD (broken wire/shorted) 14111 Fail: RTD 1 Fail: RTD 1 (broken wire/shorted) 14112 RTD 1 St.1 p.up RTD 1 Temperature stage 1 picked up 14113 RTD 1 St.2 p.up RTD 1 Temperature stage 2 picked up...

  • Page 325: Phase Rotation

    Functions 2.47 Phase Rotation 2.47 Phase Rotation A phase sequence reversal feature via binary input and parameter is implemented in the 7UM62. This permits all protection and monitoring functions to operate correctly even with phase rotation reversal, without the need for two phases to be reversed.

  • Page 326: Setting Notes

    Functions 2.47 Phase Rotation 2.47.2 Setting Notes Programming Settings The normal phase sequence is set at 271 (see Subsection 2.5). If, on the system side, phase rotation is tem- porarily changed, then this is communicated to the protective device using the binary input „>Reverse Rot.“ (5145).

  • Page 327: Protection Function Control

    Functions 2.48 Protection Function Control 2.48 Protection Function Control The function logic coordinates the sequence of both the protective and ancillary functions, processes the func- tional decisions, and data received from the system. 2.48.1 Pickup Logic for the Entire Device This section describes the general pickup and spontaneous messages in the device display.

  • Page 328: Tripping Logic For The Entire Device

    Functions 2.48 Protection Function Control 2.48.2 Tripping Logic for the Entire Device This section comprises a description regarding the general trip and termination of the trip command. 2.48.2.1 Functional Description General Trip The tripping signals for all protective functions are connected by ”OR” and generate a message „Relay TRIP“.

  • Page 329: Auxiliary Functions

    Functions 2.49 Auxiliary Functions 2.49 Auxiliary Functions The general functions of the device are described in chapter "Additional Functions". 2.49.1 Processing of Annunciation After occurrence of a system fault, data on the device response and the measured quantities are significant for analysis purposes.
  • Page 330 Functions 2.49 Auxiliary Functions Classification of Messages The indications are categorized as follows: • Operational indications; indications generated while the device is operating: Information regarding the status of device functions, measured data, power system data, control command logs etc. • Fault indications: indications from the last 8 network faults that were processed by the device. •...

  • Page 331: Statistics

    Functions 2.49 Auxiliary Functions Statistics The annunciations in statistics are counters for breaker switching operations instigated by the 7UM62 as well as for accumulation of short-circuit currents involved in disconnections caused by the device protection func- tions. The interrupted currents are in primary terms. Statistics can be viewed on the LCD of the device, or on a PC running DIGSI, and connected to the operator or service interface.

  • Page 332: Information List

    Functions 2.49 Auxiliary Functions Accumulated Shutdown Currents The shutdown currents for each phase, which are indicated at every trip command individually for side 1 and side 2, are accumulated and stored. The counter and memory levels are secured against loss of auxiliary voltage. Setting / Resetting Setting or resetting of these statistical counters takes place under the menu item ANNUNCIATION →...

  • Page 333: Measurement (Secondary/Primary/Percentage Values)

    Functions 2.49 Auxiliary Functions 2.49.3 Measurement (Secondary/Primary/Percentage Values) A series of measured values and the values derived from them are constantly available for call up on site, or for data transfer (see table 2-19, as well as the following list). Measured values can be retrieved by a central control system (SCADA).
  • Page 334 Functions 2.49 Auxiliary Functions Measured second- primary Values EE1 sec EE2 sec L-E sec. L1-L2 LL sec. L2-L3 L3-L1 measured: measured: FACTOR UE · U E sec. E sec. calculated: calculated: = U0 E sec. ·√3 FACTOR UE · U I/T sec I/T sec P, Q, S...
  • Page 335 Functions 2.49 Auxiliary Functions Measured second- primary Values in V- no primary values (measur- ing trans- ducer 1) in mA- (mea- no primary value suring transducer With the following parameters from the Power System Data 1: Parameter Address Parameter Address Unom PRIMARY FACTOR IEE1 Unom SECONDARY...
  • Page 336 Functions 2.49 Auxiliary Functions The following table shows the operating ranges for synchronous and asynchronous machines. For this, param- eter 1108 ACTIVE POWER is set to Generator. „Normal condition“ shows the active power under normal op- erating conditions: + means that a positive power is displayed on the protective device, – means that the power is negative.

  • Page 337: Information List

    Functions 2.49 Auxiliary Functions 2.49.3.2 Information List Information Type of In- Comments formation I1 = I1 (positive sequence) I2 = I2 (negative sequence) UL1E= U L1-E UL2E= U L2-E UL3E= U L3-E UL12= U L12 UL23= U L23 UL31= U L31 UE = Displacement voltage UE U1 =...

  • Page 338: Thermal Measurement

    Functions 2.49 Auxiliary Functions Information Type of In- Comments formation U0 = U0 (zero sequence) U DC = DC voltage U RE = REF(R,fn): Injected Voltage (U RE) I RE = REF(R,fn): Curr. in the Circuit (I RE) PF = Power Factor PHI= Power angle...

  • Page 339: Information List

    Functions 2.49 Auxiliary Functions 2.49.4.2 Information List Information Type of In- Comments formation T Rem.= Remaining Time for Switch ON Θ REST. = Threshold of Restart Inhibit U/f th. = Calculated temperature (U/f) Θ/Θtrip = Temperat. rise for warning and trip Temperature rise for phase L1 Θ/ΘtripL1= Temperature rise for phase L2...

  • Page 340: Diff- And Rest. Measurement

    Functions 2.49 Auxiliary Functions 2.49.5 Diff- and Rest. Measurement Differential and restraint currents (stabilized currents) I , I0 , I0 , 3I0- diff L1 diff L2 diff L3 stab L1 stab L2 stab L3 diff stab 1, 3I0-2 in percent of the nominal values of the protected object. 2.49.5.1 Information List Information Type of In-...

  • Page 341: Min/Max Measurement Setup

    Functions 2.49 Auxiliary Functions 2.49.6 Min/Max Measurement Setup Minimum and maximum values for the positive-sequence components I and U , the active power P, reactive power Q, in primary values, of the frequency and of the 3rd harmonic content in the displacement voltage, in secondary values U .

  • Page 342: Energy

    Functions 2.49 Auxiliary Functions 2.49.7 Energy , metered values of the active and reactive energy in kilowatt, megawatt or gigawatt hours primary or in kVARh, MVARh or GVARh primary, separately according to the input and output, or capacitive and inductive. The calculation of the operational measured values is also performed during a fault.

  • Page 343: Set Points (Measured Values)

    Functions 2.49 Auxiliary Functions 2.49.8 Set Points (Measured Values) The SIPROTEC 4 device 7UM62 allows to set warning levels for important measured and metered values. If one of these limit values is reached or exceeded positively or negatively during operation, the device generates an alarm which is displayed as an operational indication.

  • Page 344: Oscillographic Fault Records

    Functions 2.49 Auxiliary Functions 2.49.10 Oscillographic Fault Records The multi-functional 7UM62 is equipped with a fault memory which optionally scans either the instantaneous values or the rms values of various measured quantities for storage in a ring buffer. 2.49.10.1Functional Description Mode of Operation The instantaneous values of the measured quantities and u...

  • Page 345: Settings

    Functions 2.49 Auxiliary Functions The actual storage time begins at the pre-fault time PRE. TRIG. TIME (address 404) ahead of the reference instant, and ends at the post-fault time POST REC. TIME (address 405) after the storage criterion has reset. The maximum recording duration for each fault (MAX.

  • Page 346: Date And Time Stamping

    Functions 2.49 Auxiliary Functions 2.49.11 Date and Time Stamping The integrated date/clock management enables the exact timely assignment of events e.g., those in the oper- ational messages and fault messages or in the lists of the minimum/maximum values. 2.49.11.1Functional Description Mode of Operation The time can be influenced by •...

  • Page 347: Commissioning Aids

    Functions 2.49 Auxiliary Functions 2.49.12 Commissioning Aids Device data sent to a central or master computer system during test mode or commissioning can be influenced. There are tools for testing the system interface and the binary inputs and outputs of the device. Applications •...

  • Page 348: Checking The Binary Inputs And Outputs

    Functions 2.49 Auxiliary Functions 2.49.12.3Checking the Binary Inputs and Outputs The binary inputs, outputs, and LEDs of a SIPROTEC 4 device can be individually controlled. This feature can be, for example, to verify control wiring from the device to substation equipment (operational checks), during commissioning.

  • Page 349: Command Processing

    Functions 2.50 Command Processing 2.50 Command Processing The SIPROTEC 4 7UM62 includes a command processing function 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 350: Types Of Commands

    Functions 2.50 Command Processing 2.50.2 Types of Commands In conjunction with the power system control the following command types can be distinguished for the device: 2.50.2.1 Description Commands to the System These are all commands that are directly output to the switchgear to change their process state: •...

  • Page 351: Command Processing

    Functions 2.50 Command Processing 2.50.3 Command Processing Security mechanisms in the command path ensure that a switch command can be carried out only if the test of previously established criteria has been successfully completed. In addition to general fixed prescribed tests, further interlocks can be configured for each resource separately.

  • Page 352: Interlocking

    Functions 2.50 Command Processing 2.50.4 Interlocking Interlocking is implemented via the user-definable logic (CFC). 2.50.4.1 Description Switchgear interlocking checks in a SICAM/SIPROTEC 4 system are normally divided in the following groups: • System interlocking, using the system database in the central control system •...
  • Page 353 Functions 2.50 Command Processing Figure 2-148 Example of an operational indication for switching circuit breaker (Q0) Standard Interlocking (hard-coded) The following is a list of Standard Interlocking Conditions that can be selected for each controllable device. All of these are enabled as a default. •...
  • Page 354 Functions 2.50 Command Processing Figure 2-149 Standard interlockings SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...
  • Page 355 Functions 2.50 Command Processing The following figure shows the configuration of the interlocking conditions using DIGSI. Figure 2-150 DIGSI-Dialog Box for Setting the Interlocking Conditions The display shows the configured interlocking reasons. They are marked by letters explained in the following table.
  • Page 356 Functions 2.50 Command Processing Enabling Logic via CFC For bay interlocking, an enable logic can be created using CFC. Via specific release conditions the information „released“ or „bay interlocked“ are available, e.g. object „52 Close“ and „52 Open“ with the data values: ON / OFF).
  • Page 357 Functions 2.50 Command Processing SC = Auto: Commands that are derived internally (command processing in the CFC) are not subject to switching authority and are therefore always "enabled". Switching Mode The switching mode determines whether selected interlocking conditions will be activated or deactivated at the time of the switching operation.
  • Page 358 Functions 2.50 Command Processing Blocking by Protection With this function, switching operations are blocked by the pickup of protective elements. Blocking is config- urable separately for both closing and tripping commands. When configured, "Block CLOSE commands" blocks CLOSE commands, whereas "Block TRIP commands" blocks TRIP signals.

  • Page 359: Command Logging

    Functions 2.50 Command Processing 2.50.5 Command Logging During the processing of the commands, independent of the further message routing and processing, command and process feedback information are sent to the message processing centre. These messages contain information on the cause. With the corresponding allocation (configuration) these messages are entered in the event list, thus serving as a report.
  • Page 360 Functions 2.50 Command Processing SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 361: Mounting And Commissioning

    Mounting and Commissioning This chapter is intended for experienced commissioning staff. They should be familiar with the commissioning of protection and control equipment, with operation of the power system network and with the safety rules and regulations. Certain adaptations of the hardware to the power system specifications may be necessary. For primary testing, the object to be protected (generator, motor, transformer) must be started up and in put into service.

  • Page 362: Mounting And Connections

    Mounting and Commissioning 3.1 Mounting and Connections Mounting and Connections 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 363 Mounting and Commissioning 3.1 Mounting and Connections Example: Summation current transformer 60 A / 1 A Matching factor for sensitive earth fault current detection: FACTOR IEE2 = 60 (if the input on side 2 is used) If the sensitive current input of side 1 is used for rotor earth fault current detection (see Appendix A.3), FACTOR IEE1 = 1 is selected.
  • Page 364 Mounting and Commissioning 3.1 Mounting and Connections Figure „Asynchronous Motor“ in Appendix A.3 shows a typical connection of the protection relay to a large asynchronous motor. The voltages for voltage and zero voltage monitoring are usually taken at the busbar. Where several motors are connected to the busbar, the directional earth fault protection detects single-pole earth faults and can thus open breakers selectively.

  • Page 365: Hardware Modifications

    Mounting and Commissioning 3.1 Mounting and Connections 3.1.2 Hardware Modifications 3.1.2.1 General General A subsequent adaptation of the hardware to the power system conditions can, for example, become necessary with regard to the control voltage for binary inputs or the termination of bus-capable interfaces. Follow the pro- cedure described in this section, whenever hardware modifications are done.
  • Page 366 Mounting and Commissioning 3.1 Mounting and Connections Note If binary inputs are used for trip circuit monitoring, note that two binary inputs (or one binary input and an equiv- alent resistor) are connected in series. The switching threshold must be significantly less than one half of the rated control voltage.

  • Page 367: Disassembly

    Mounting and Commissioning 3.1 Mounting and Connections Spare Parts Spare parts may be the backup battery that maintains the data in the battery-buffered RAM when the voltage supply fails, and the miniature fuse of the internal power supply. Their physical location is shown in Figure 3-3. The ratings of the fuse are printed on the board next to the fuse itself.
  • Page 368 Mounting and Commissioning 3.1 Mounting and Connections Work on the Plug Connectors Caution! Mind electrostatic discharges Non–observance can result in minor personal injury or material damage. Electrostatic discharges through the connections of the components, printed conductors and connector pins must be avoided by touching earthed metal parts beforehand. Do not plug or withdraw interface connections under power! The following must be observed: •...
  • Page 369 Mounting and Commissioning 3.1 Mounting and Connections Figure 3-2 Front view of a 7UM622 (housing size 1/1) after removal of the front cover (simplified and scaled down) SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 370: Switching Elements On The Printed Circuit Boards

    Mounting and Commissioning 3.1 Mounting and Connections 3.1.2.3 Switching Elements on the Printed Circuit Boards Processor Board C-CPU-2 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 3-1, the quiescent state of the life contact accord- ing to Table 3-2, the selected operating voltages of binary inputs BI1 to BI5 according to Table 3-3 and the in- tegrated interface RS232 / RS485 according to Tables 3-4 to 3-6.
  • Page 371 Mounting and Commissioning 3.1 Mounting and Connections Table 3-1 Jumper setting of the rated voltage of the integrated Power Supply on the C-CPU-2 processor board Jumper Nominal Voltage 24 to 48 VDC 60 to 125 VDC 110 to 250 VDC 115/230 VAC not used not used...
  • Page 372 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 3-5 Jumper setting for CTS (flow control) on the C–CPU-2 processor board Jumper /CTS from interface RS232 /CTS triggered by /RTS X111 Default setting of releases 7UM62../CC and higher...
  • Page 373 Mounting and Commissioning 3.1 Mounting and Connections The terminating resistors can also be connected externally (e.g. to the connection module). In this case, the terminating resistors located on the RS485 or PROFIBUS interface module or directly on the PCB of the pro- cessor board C-CPU-2 must be de-energized.
  • Page 374 Mounting and Commissioning 3.1 Mounting and Connections Input/Output Board C-I/O-1 Figure 3-5 Input/output board C-I/O-1 with representation of the jumper settings required for the board configuration In the version 7UM622, binary output BO 13 on the input/output board C–I/O-1 can be configured as normally open or normally closed (see also overview diagrams in Appendix A.2).
  • Page 375 Mounting and Commissioning 3.1 Mounting and Connections Table 3-7 Jumper setting for the Contact Type of the relay for BO13 Jumper Open in quiescent state (NO) Closed in quiescent state (NC) Presetting Table 3-8 Jumper setting of Control Voltages of binary inputs BI8 to BI15 on input/output board C–...
  • Page 376 Mounting and Commissioning 3.1 Mounting and Connections Input/Output Board C-I/O-2 Two different releases of the input output board C-I/O-2 are available. For devices up to release 7UM62.../DD the layout of the printed circuit board is shown in Figure 3-6, for devices of release 7UM62.../EE and higher it is shown in Figure 3-7.
  • Page 377 Mounting and Commissioning 3.1 Mounting and Connections Table 3-10 Jumper setting for the Contact Type of binary output BO6 Jumper Open in quiescent state (NO) Closed in quiescent state (NC) Presetting The set nominal currents of the current input transformers are to be checked on the input/output board C-I/O- 2.
  • Page 378 Mounting and Commissioning 3.1 Mounting and Connections Input/Output Module C-I/O-2 ( from release 7) Figure 3-7 C-I/O-2 input/output board release 7UM62* .../EE or higher, with representation of jumper settings required for checking configuration settings SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...
  • Page 379 Mounting and Commissioning 3.1 Mounting and Connections Table 3-12 Jumper setting for Nominal Current or Measuring Range Jumper Nominal current 1 A Nominal current 5 A Measuring range 20 A Measuring range 100 A Not for version with sensitive earth fault detection Contacts of relays for binary outputs BO6, BO7 and BO8 can be configured as normally open or normally closed (see also General Diagrams in the Appendix).
  • Page 380 Mounting and Commissioning 3.1 Mounting and Connections Input/Output Board C-I/O-6 PCB layout for the Input/Output C-I/O-6 board is shown in the following Figure. Figure 3-8 C-I/O-6 input/output board with representation of jumper settings required for checking config- uration settings SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...
  • Page 381 Mounting and Commissioning 3.1 Mounting and Connections Table 3-16 Jumper setting for Control Voltages of binary inputs BI6 and BI7 on the C–I/O-6 input/output board Binary Inputs Jumper 19 VDC Pickup 88 VDC Pickup 176 V Threshold Factory settings for devices with rated power supply voltages of 24 VDC to 125 VDC Factory settings for devices with power supply voltages of 110 VDC to 250 VDC and 115/230 VAC Use only with pickup voltages 220 or 250 VDC Contacts of relays for binary outputs BO11 and BO12 can be configured as normally open or normally closed...
  • Page 382 Mounting and Commissioning 3.1 Mounting and Connections Table 3-20 Jumper setting for activating/deactivating the f ≈ 10 Hz low-pass filter of measuring transducer Jumper Low-Pass Filter Inactive Low-Pass Filter Active Presetting Note The jumper settings must correspond to the mode set at addresses 295, 296 (voltage or current input) and 297 (with/without filter).

  • Page 383: Interface Modules

    Mounting and Commissioning 3.1 Mounting and Connections 3.1.2.4 Interface Modules Replacing Interface Modules The interface modules are located on the C–CPU-2 board ((1) in Figure 3-1 and 3-2). The following figure shows the PCB with location of the modules. Figure 3-9 C-CPU-2 board with interface modules Please note the following: •...
  • Page 384 Mounting and Commissioning 3.1 Mounting and Connections Table 3-22 Replacing interface modules Interface Mounting Location / Interface Replacement module Only interface modules that can be ordered System interface in our facilities via the order key (see Appen- dix, Section A.1). Analog Output 2 x 0 to 20 mA or 4 to 20 mA Analog Output...
  • Page 385 Mounting and Commissioning 3.1 Mounting and Connections Figure 3-11 Position of the plug-in jumpers for the configuration of the terminating resistors at the Profibus (FMS and DP), DNP 3.0 and Modbus interfaces The terminating resistors can also be connected externally (e.g. to the terminal block), see Figure 3-4. In this case, the terminating resistors located on the RS485 or PROFIBUS interface module or directly on the PCB of the C-CPU-2 board of must be disabled.

  • Page 386: Reassembly

    Mounting and Commissioning 3.1 Mounting and Connections 3.1.2.5 Reassembly The device is assembled in the following steps: • Insert the boards carefully in the housing. The mounting locations are shown in Figures 3-1 to 3-2. For the model of the device designed for surface mounting, use the metal lever to insert the C-CPU-2 board. The installation is easier with the lever.
  • Page 387 Mounting and Commissioning 3.1 Mounting and Connections Figure 3-13 Panel flush mounting of a device (housing size Figure 3-14 Panel flush mounting of a device (housing size SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 388: Rack And Cubicle Mounting

    Mounting and Commissioning 3.1 Mounting and Connections 3.1.3.2 Rack and Cubicle Mounting For the housing size (Figure 3-15), there are four covers and four holes. For the housing size (Figure 3- 16) there are six covers and six holes. To install the device in a frame or cubicle, two mounting brackets are required. The ordering codes are stated in Appendix, Section A.1.

  • Page 389: Panel Surface Mounting

    Mounting and Commissioning 3.1 Mounting and Connections Figure 3-16 Rack or cubicle mounting of a device (housing size 3.1.3.3 Panel Surface Mounting For panel surface mounting of the device proceed as follows: • Secure the device to the panel with four screws. For dimensions refer to Section 4.39. •...

  • Page 390: Checking Connections

    Mounting and Commissioning 3.2 Checking Connections Checking Connections 3.2.1 Checking Data Connections of 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 391: System Interface

    Mounting and Commissioning 3.2 Checking Connections 3.2.2 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 392: Analog Output

    Mounting and Commissioning 3.2 Checking Connections 3.2.4 Analog Output The two analog values are output as currents on a 9-pin DSUB socket. The outputs are isolated. Table 3-25 Pin assignment of DSUB socket for analog output Pin No. Code Channel 1 positive –...

  • Page 393: Optical Fibres

    Mounting and Commissioning 3.2 Checking Connections 3.2.6 Optical Fibres WARNING! Laser Radiation! Do not look directly into the fibre-optic elements! The transmission via fibre optics is particularly insensitive to electromagnetic interference and thus ensures gal- vanic isolation of the connection. Transmit and receive connections are shown with the symbols for transmit and for receive.
  • Page 394 Mounting and Commissioning 3.2 Checking Connections The accuracy which can be achieved during testing depends on the accuracy of the testing equipment. The accuracy values specified in the Technical Data can only be reproduced under the reference conditions set down in IEC 60 255 resp. VDE 0435/part 303 and with the use of precision measuring instruments. Tests can be performed using the currently set values or the default values.
  • Page 395 Mounting and Commissioning 3.2 Checking Connections In order to obtain the pickup value, the setting value I-DIFF> (parameter address 2021) must be multiplied by the factor Table 3-27 Correction factor k depending on vector group and fault type Type of Fault Reference winding Even VG Numeral Odd VG Numeral...
  • Page 396 Mounting and Commissioning 3.2 Checking Connections Because of the odd vector group numeral, the following pickup values apply Wiring It is particularly important to check the correct wiring and allocation of all device interfaces. The margin heading titled„Test function for checking the binary inputs and outputs“ provides additional information to this end. For checking the analog inputs a plausibility check can be conducted as described above under the margin title „Secondary Testing“...

  • Page 397: Checking System Incorporation

    Mounting and Commissioning 3.2 Checking Connections 3.2.8 Checking System Incorporation General Information 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 398 Mounting and Commissioning 3.2 Checking Connections Acquisition of Technical Power System Data For checking protection parameterization (allocation and settings) in accordance with power system require- ments, it is necessary to record the technical data of the individual components in the primary system. This includes, among others, the data of generator or motor, unit transformer and voltage and current transformers.
  • Page 399 Mounting and Commissioning 3.2 Checking Connections Voltage Transformer-Protective Switch Since it is very important for the undervoltage protection, impedance protection and voltage-dependent definite time and inverse time overcurrent protection that these functions are blocked automatically if the circuit breaker for the voltage transformers has tripped, the blocking should be checked along with the voltage circuits. Switch off the voltage transformer protection switches.

  • Page 400: 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 401: Test Mode / Transmission Block

    Mounting and Commissioning 3.3 Commissioning 3.3.1 Test Mode / Transmission Block If the device is connected to a central or main computer system via the SCADA interface, then the information that is transmitted can be influenced. This is only possible with some of the protocols available (see Table „Pro- tocol-dependent functions“...
  • Page 402 Mounting and Commissioning 3.3 Commissioning Structure of the Test Dialogue Box In the column Indication the display texts of all indications are displayed which were allocated to the system interface in the matrix. In the column Status SCHEDULED the user has to define the value for the messages to be tested.

  • Page 403: Checking The Binary Inputs And Outputs

    Mounting and Commissioning 3.3 Commissioning 3.3.3 Checking the Binary Inputs and 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 404 Mounting and Commissioning 3.3 Commissioning Figure 3-20 Test of the Binary Inputs and Outputs — Example Changing the Operating State To change the condition of a hardware component, click on the associated switching field in the Scheduled column. Password No. 6 (if activated during configuration) will be requested before the first hardware modification is allowed.
  • Page 405 Mounting and Commissioning 3.3 Commissioning Test of the Binary Inputs To test the wiring between the plant and the binary inputs of the 7UM62, the condition in the system which ini- tiates the binary input must be generated and the response of the device checked. To do this, the dialog box Hardware Test must again be opened to view the physical state of the binary inputs.

  • Page 406: Tests For Circuit Breaker Failure Protection

    Mounting and Commissioning 3.3 Commissioning 3.3.4 Tests for Circuit Breaker Failure Protection General If the device is equipped with the breaker failure protection and this function is used, its interaction with the breakers of the power plant must be tested in practice. Especially important for checking the system is the correct distribution of the trip commands to the adjacent circuit breakers in the event of breaker failure.

  • Page 407: Checking The Rotor Ground Fault Protection At Standstill

    Mounting and Commissioning 3.3 Commissioning 3.3.7 Checking the Rotor Earth Fault Protection at Standstill Rotor Earth Fault Protection (R, fn) The rotor earth fault protection can be checked with the machine at standstill. For this purpose, the coupling device must be fed an external AC voltage. This may be 100 V to 125 V or 230 V (see also connection example in Section 2.34).
  • Page 408 Mounting and Commissioning 3.3 Commissioning Figure 3-21 Types of excitation Lift measurement brushes or interrupt measurement circuit. After a delay of approx. 5 s, the indication „Fail. REF IEE<“ is issued (not allocated on delivery). Reclose the measuring circuit. If the indication „Fail. REF IEE<“ is present even with closed measuring circuit, the rotor-earth capacity is less than 0.15 µF.
  • Page 409 Mounting and Commissioning 3.3 Commissioning Table 3-28 Operational measured values of the rotor earth fault protection Measured Value Explanation fgen = xx.x Hz Shows the frequency of the injected square-wave voltage. The frequency can be set by a jumper in the 7XT71. The default setting is approx. 1.5 Hz (tolerance approx.
  • Page 410 Mounting and Commissioning 3.3 Commissioning Figure 3-22 Test fault recording After this the fault resistors for the warning and the trip stage are installed, and the operational measured value is read out. The two measured values are the basis for the setting values of the warning stage (address earth 6102 RE<...

  • Page 411: Checking The 100 % Stator Earth Fault Protection

    Mounting and Commissioning 3.3 Commissioning Finally switch the AC voltage source of the 7XT71 off. After about 5 s the protection device issues the indication „Fail REF 1-3Hz“ (not allocated on delivery). To eliminate interference which might originate from the running machine, in particular from the excitation system, it is recommended to perform an additional operational check.
  • Page 412 Mounting and Commissioning 3.3 Commissioning DANGER! In the generator, voltage hazardous to the stator winding can be caused by external 20 Hz bias voltage, even at standstill. Non-observance of the following procedures will result in death, serious injury or substantial property damage, since 1% to 3% of the primary rated voltage of the generator being protected may be present.
  • Page 413 Mounting and Commissioning 3.3 Commissioning Note For the settings, only secondary values should be used. If you find during the conversion from secondary to primary values that the theoretical conversion factor is not quite correct, FACTOR R SEF should be modified to match the measuring results (for conversion formulae refer to Section 2.31.2).

  • Page 414: Checking The Dc Voltage / Dc Current Circuit

    Mounting and Commissioning 3.3 Commissioning 3.3.9 Checking the DC Voltage / DC Current Circuit Preparation Set the DC voltage/DC current protection (address 7201 DC PROTECTION) to Block relay. You can now modify the plant voltage to match the conditions of the intended application, and verify the re- sponse of the 7UM62.
  • Page 415 Mounting and Commissioning 3.3 Commissioning WARNING! Warning of dangers evolving from improper primary tests Non-observance of the following measures can result in death, personal injury or substantial property damage. Primary test may only be carried out by qualified personnel, who are familiar with the commissioning of protec- tion systems, the operation of the plant and the safety rules and regulations (switching, earthing, etc.).
  • Page 416 Mounting and Commissioning 3.3 Commissioning Testing Sequence Primary testing is usually performed in the following order: • Short circuit tests • Voltage tests • Earth fault tests • Synchronization • Load measurements at the network The following instructions are arranged in this sequence. All protection functions should be initially switched off (condition as delivered from factory) so that they do not influence one another.
  • Page 417 Mounting and Commissioning 3.3 Commissioning Operating Range of the Protection Functions For commissioning tests with the generator, care should be taken that the operating range of the protection functions as specified in section 4 is not exceeded and that the measuring quantities applied are high enough. Where tests are performed with reduced pickup values, the pickup value may appear to deviate from the setting value (e.g.
  • Page 418 Mounting and Commissioning 3.3 Commissioning Figure 3-23 Phasor diagram of the secondary measured values — Example For a test of the differential protection, the differential and restraint currents are entered in the characteristic. The characteristic shown is a result of the settings for the differential protection. In Figure 3-24, a load current has been simulated.

  • Page 419: Checking The Current Circuits

    Mounting and Commissioning 3.3 Commissioning 3.3.12 Checking the Current Circuits General The checks of the current circuits are performed with the generator to ensure correct CT circuit connections with regard to cabling, polarity, phase sequence, CT ratio etc., not in order to verify individual protection func- tions in the device.
  • Page 420 Mounting and Commissioning 3.3 Commissioning Calibrating the Impedance Protection Switch impedance protection (address 3301) to IMPEDANCE PROT. = Block relay. With the primary system voltage-free and earthed, install a three-pole short-circuit bridge which is capable of carrying rated current (e.g. earthing isolator) to the primary side of the unit transformer. DANGER! Primary measurements may only be carried out with the generator at stand–still on disconnected and grounded equipment of the power system.

  • Page 421: Checking The Differential Protection

    Mounting and Commissioning 3.3 Commissioning 3.3.13 Checking the Differential Protection Preparation Before commencing any primary tests, make sure that the configured object is actually the one you want to protect, and that the amplitude matching for the current ratings of the protected object and the main primary CTs, and the vector group matching are correctly set.
  • Page 422 Mounting and Commissioning 3.3 Commissioning Symmetrical Current Test The operational measured values supplied by the 7UM62 device allow a fast commissioning without external instruments. The indices of the measured currents are as follows: The symbol for current I is followed by the phase identifier Lx and by the index of the side of the protected object (e.g.
  • Page 423 Mounting and Commissioning 3.3 Commissioning The theoretical angles depend on the protected object and – in the case of transformers – on the vector group. They are listed in Table 3-29 for clockwise phase rotation. The polarity of the CT connections and the parameterized polarity are taken into consideration for the angles displayed.

  • Page 424: Checking The Earth Current Differential Protection

    Mounting and Commissioning 3.3 Commissioning 3.3.14 Checking the Earth Current Differential Protection Preparation The primary test checks correct integration into the system, especially the CT connection. Before commencing any primary tests, make sure that the configured object is actually the one you want to protect. To do so, verify the settings used in the configuration of the protection function, Power System Data 1 and in the protection function itself.
  • Page 425 Mounting and Commissioning 3.3 Commissioning For the external fault, the percentages of the operational measured values are (on the device: Measurement → I-Diff, I-Rest) to be read out: 3I0-1 Calculated zero sequence current of side 1 3I0-2 calculated zero sequence current of side 2 or measured earth current I (depending on configuration) I0-Diff...
  • Page 426 Mounting and Commissioning 3.3 Commissioning Test with Secondary Test Equipment Measurements are always performed from the side with the earthed starpoint. In transformers, there must be a delta winding (d-winding or compensating winding). The side which is not included in the tests remains open as the delta winding ensures low-ohmic termination of the current path.
  • Page 427 Mounting and Commissioning 3.3 Commissioning Figure 3-31 Zero sequence current measurement on a zig-zag-winding Figure 3-32 Zero sequence current measurement on a delta winding with artificial starpoint A zero sequence current of at least 2 % the rated generator current is required for tests per phase, i.e. the test current is at least 6 %.

  • Page 428: Checking The Voltage Circuits

    Mounting and Commissioning 3.3 Commissioning If there are deviations, connection errors are normally assumed (see margin title „Primary test with generator“) • Disconnect test source and protected object • Check and correct connections and test setup • Repeat measurement Checking the Zero Voltage Release If the zero voltage release is used, it must be checked during the test of the stator earth fault protection.
  • Page 429 Mounting and Commissioning 3.3 Commissioning Amplitudes Read out voltages in all three phases in the operational measured values and compare with the actual voltages. The voltage of the positive sequence system U must be approximately the same as the voltage values indi- cated for the phase-earth voltages.

  • Page 430: Checking The Stator Ground Fault Protection

    Mounting and Commissioning 3.3 Commissioning 3.3.16 Checking the Stator Earth Fault Protection General The procedure for checking the stator earth fault protection depends mainly on whether the generator is con- nected to the network in unit connection or in busbar connection. In both cases correct functioning and protect- ed zone must be checked.
  • Page 431 Mounting and Commissioning 3.3 Commissioning Since the reactance of the coupling capacitance is much larger than the referred resistance of the loading re- sistor R ', U can be assumed to be U /√3 (compare also vector diagram Figure 3-34), where U /√3 is the neutral displacement voltage with a full displacement of the network (upper-voltage) neutral.
  • Page 432 Mounting and Commissioning 3.3 Commissioning Figure 3-35 Displacement voltage during earth faults Checking for Generator Earth Fault Switch rotor earth fault protection S/E/F PROT. (address 5001) to Block relay. If the sensitive earth fault detection is used for stator earth fault protection, switch it to Block relay also under address 5101 as well. With the primary equipment disconnected and earthed, insert a single-pole earth fault bridge in the generator terminal circuit.
  • Page 433 Mounting and Commissioning 3.3 Commissioning Check Using Network Earth Fault With the primary plant voltage-free and earthed, install a single-pole earth fault bridge on the high voltage side of the unit transformer. DANGER! Primary measurements may only be carried out with the generator at stand–still on disconnected and grounded equipment of the power system.
  • Page 434 Mounting and Commissioning 3.3 Commissioning Figure 3-36 Earth fault with busbar connection For this test, connections must be such that the generator is galvanically connected with the load equipment. If the plant conditions do not allow this, the hints given overleaf under the side title „Directional check without Loading Resistor“...
  • Page 435 Mounting and Commissioning 3.3 Commissioning Example: Machine voltage at pick-up 0.1 x U Measured value = 10 V Setting value U0> = 10 V Protection range = 90 % With Direction Determination The earth fault directional determination requires a check of the current and voltage connections for correct- ness and correct polarity.
  • Page 436 Mounting and Commissioning 3.3 Commissioning Figure 3-37 Directional check with toroidal transformers Directional Check in Holmgreen Connection If the current is supplied from a Holmgreen connection, the displacement voltage is obtained in the same manner as in the above circuit. Only the current of that current transformer which is in the same phase as the by-passed voltage transformer in the delta connection is fed via the current path.
  • Page 437 Mounting and Commissioning 3.3 Commissioning Figure 3-38 Directional check with holmgreen connection If in an isolated network the voltage connections for the reactive current measurement should be kept for test- ing, then it should be noted that for a power flow with inductive component in forwards direction a backwards direction results (contrary to an earth fault in this direction).

  • Page 438: Checking The 100 % Stator Ground Fault Protection

    Mounting and Commissioning 3.3 Commissioning 3.3.17 Checking the 100 % Stator Earth Fault Protection General The 100% stator earth fault connection is tested together with the 90% stator earth fault protection. Set the 100% stator earth fault protection (address 5301 100% SEF-PROT.) to Block relay (if not done so already).

  • Page 439: Checking The Sensitive Ground Fault Protection As Rotor Ground Fault Protection

    Mounting and Commissioning 3.3 Commissioning Caution! Possible starpoint earthing at transformer with simultaneous earthing on high voltage side during test! Nonobservance of the following procedures can result in minor injury or material damage. The starpoints of the unit transformer must be disconnected from earth during this test! Start up the generator and slowly excite it to 30 % of rated machine voltage (max.

  • Page 440: Checking The Rotor Ground Fault Protection During Operation

    Mounting and Commissioning 3.3 Commissioning The sensitive earth fault detection used for rotor earth fault protection is then activated: O/C PROT. IEE = ON in address 5101. 3.3.19 Checking the Rotor Earth Fault Protection during Operation Rotor Earth Fault Protection (R, fn) In Section 3.3, the rotor earth fault protection with earth resistance measurement was checked with the machine at standstill.

  • Page 441: Checking The Interturn Fault Protection

    Mounting and Commissioning 3.3 Commissioning Check the operational measured value Rearth and the pickup indication („REF 1-3Hz Fault“) and, after T- TRIP-RE<< (10 s on delivery) has expired, check the trip indication („REF 1-3Hz Trip“). Set the resistance to approx. 90 % of the warning stage (address 6102 RE< WARN), read out the operational measured value „Re =“, and check the warning message („REF 1-3Hz Warn“).
  • Page 442 Mounting and Commissioning 3.3 Commissioning Shut down the generator. Remove short-circuit bridge. The measured displacement voltage has to be extrapolated to the nominal excitation current to make sure that the function does not pick up erroneously on external short-circuits. The function is then set to at least twice the fault value at nominal excitation.

  • Page 443: Checks With The Network

    Mounting and Commissioning 3.3 Commissioning 3.3.21 Checks with the Network Note Since the protective function adjusts the scanning frequency, the test requires that a nominal-frequency phase- to-earth voltage (e.g. U ) is injected at least at one voltage input. Checking the Correct Connection Polarity The following test instructions apply to a synchronous generator.
  • Page 444 Mounting and Commissioning 3.3 Commissioning Caution! Under-excitation may cause the generator to fall out of step! Nonobservance of the following procedures can result in minor injury or material damage. Operation with underexcitation is admissible only for a short period Proceed as follows: Adjust excitation until the reactive power amounts to approximately Q = 0.
  • Page 445 Mounting and Commissioning 3.3 Commissioning Calibrating the Reverse Power Protection If a generator is connected with the network, reverse power can be caused by • closing of the regulating valves, • closing of the stop valve Because of possible leakages in the valves, the reverse power test should – if possible – be performed for both cases.
  • Page 446 Mounting and Commissioning 3.3 Commissioning Note If operation with capacitive load is not possible, then load points in the underexcited range can be achieved by changing the polarity of the current transformer connections (address 210). Thereby the characteristics of the underexcitation protection are mirrored around the zero point.

  • Page 447: Creating Oscillographic Fault Recordings For Tests

    Mounting and Commissioning 3.3 Commissioning • Make sure that the protective function does not pick up on this current. It may be necessary to use different excitation states. • With the generator running, connect a test resistor (0 - 30 Ω) between generator shaft and earth using a slip- ring in the vicinity of the bearing.
  • Page 448 Mounting and Commissioning 3.3 Commissioning Figure 3-40 Triggering oscillographic recording with DIGSI — Example A test measurement record is immediately started. During recording, an indication is given in the left part of the status bar. Bar segments additionally indicate the progress of the procedure. For display and evaluation of the recording, you require one of the programs SIGRA or ComtradeViewer.

  • Page 449: Final Preparation Of The Device

    Mounting and Commissioning 3.4 Final Preparation of the Device Final Preparation of the Device Firmly tighten all screws. Tighten all terminal screws, including those that are not used. Caution! Inadmissable tightening torques Non–observance of the following measure can result in minor personal injury or property damage. The tightening torques must not be exceeded as the threads and terminal chambers may otherwise be dam- aged! In case service settings were changed, check if they are correct.
  • Page 450 Mounting and Commissioning 3.4 Final Preparation of the Device SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 451: Technical Data

    Technical Data This chapter presents the technical data of the SIPROTEC 4 7UM62 device and its individual functions, includ- ing the limit values that must not be exceeded under any circumstances. The electrical and functional data for devices equipped with all options are followed by the mechanical data with dimensional drawings. General Definite-Time Overcurrent Protection (ANSI 50, 51, 67) Inverse-Time Overcurrent Protection (ANSI 51V)
  • Page 452 Technical Data 4.27 Rotor Earth Fault Protection R, fn (ANSI 64R) 4.28 Sensitive Rotor Earth Fault Protection with 1 to 3 Hz Square Wave Voltage Injection (ANSI 64R - 1 to 3 Hz) 4.29 Motor Starting Time Supervision (ANSI 48) 4.30 Restart Inhibit for Motors (ANSI 66, 49Rotor) 4.31...

  • Page 453: General

    Technical Data 4.1 General General 4.1.1 Analog Inputs/Outputs Current Inputs Rated system frequency 50 Hz or 60 Hz (adjustable) Rated current 1 A or 5 A Earth Current, Sensitive Linear range ≤ 1.6 A Burden per Phase and Earth Path - at I = 1 A Approx.

  • Page 454: Auxiliary Voltage

    Technical Data 4.1 General Analog output (for operational measured values) Nominal Range 0 mA to 20 mA or 4 mA to 20 mA Operating Range 0 mA to 22.5 mA or 4 mA to 22.5 mA Connection for flush-mounted case Rear panel, mounting location "B"...

  • Page 455: Binary Inputs And Outputs

    Technical Data 4.1 General 4.1.3 Binary Inputs and Outputs Binary inputs Variant Number 7UM621*- 7 (configurable) 7UM623*- 7UM622*- 15 (configurable) Rated Voltage Range DC24 V to 250 V, bipolar Current Consumption, Energized Approx. 1.8 mA, independent of the control voltage Switching Thresholds adjustable with jumpers For rated voltages...
  • Page 456 Technical Data 4.1 General Binary Outputs Signalling/trip relays (see also terminal assignments in Appendix A.2)) Number: According to the order variant (allocatable) 7UM621*- 12 (1 NO contact each, 3 optionally as NC contacts) 7UM623*- 7UM622*- 20 (1 NO contact each, 4 optionally as NC contacts) 1 Life contact (NC contact or NO contact, selectable) Make/break capacity CLOSE...

  • Page 457: Communication Interfaces

    Technical Data 4.1 General 4.1.4 Communication Interfaces Operating Interface Connection Front side, non-isolated, RS232, 9-pin DSUB port for connection of a PC Operation With DIGSI Transmission Speed min. 4 800 Bd to 115 200 Bd Factory setting: 38 400 Bd; Parity: 8E1 bridgeable distance 15 m...
  • Page 458 Technical Data 4.1 General RS485 Connection for flush mounted Rear panel, mounting location "B" case 9-pin DSUB port For panel surface-mounted in console housing at case bottom side case Test voltage 500 V; 50 Hz Transmission speed min. 4,800 Bd, max.
  • Page 459 Technical Data 4.1 General Profibus FO (DP) FO connector type ST-connector: single ring / double ring ac- cording to the order for FMS; for DP only double ring available Connection for flush mounted Rear panel, mounting location "B" case For panel surface-mounted Please use version with Profibus RS485 in case the console housing as well as separate...
  • Page 460 Technical Data 4.1 General Analog output module 2 ports with 0 mA to 20 mA (electrical) Connection for flush mounted Rear panel, mounting location "B" and "D" case 9-pin DSUB port For panel surface-mounted in console housing at case bottom side case Test voltage 500 V;...

  • Page 461: Electrical Tests

    Technical Data 4.1 General 4.1.5 Electrical Tests Regulations Standards: IEC 60255 (product standards) IEEE C37.90.0/.1/.2 UL 508 VDE 0435 See also standards for individual tests Insulation Test Standards: IEC 60255-5 and IEC 60870-2-1 High voltage test (routine test) current inputs, 2.5 kV (rms), 50 Hz voltage inputs, output relays High voltage test (routine test)

  • Page 462: Mechanical Stress Tests

    Technical Data 4.1 General Auxiliary voltage Common mode: 2 kV; 12 Ω; 9 µF Diff. mode: 1 kV; 2 Ω; 18 µF Measuring Inputs, Binary Inputs, Relay Common mode: 2 kV; 42 Ω; 0.5 µF Outputs Diff. mode: 1 kV; 42 Ω; 0.5 µF Line conducted HF, amplitude modulated 10 V;...

  • Page 463: Climatic Stress Tests

    On 56 days of the year up to 93% relative humidity. Con- densation must be avoided in operation! Siemens recommends that all devices be installed so that they are not exposed to direct sunlight nor subject to large fluctuations in temperature that may cause condensation to occur.

  • Page 464: Service Conditions

    Technical Data 4.1 General 4.1.8 Service Conditions The protection device is designed for installation in normal relay rooms and plants, so that electromagnetic compatibility (EMC) is ensured if installation is done properly. In addition the following is recommended: • Contactors and relays operating within the same cubicle or on the same relay board with digital protection equipment should always be provided with suitable quenching equipment.

  • Page 465: Definite-Time Overcurrent Protection (Ansi 50, 51 67)

    Technical Data 4.2 Definite-Time Overcurrent Protection (ANSI 50, 51, 67) Definite-Time Overcurrent Protection (ANSI 50, 51, 67) Setting Ranges / Increments Pickup current I> 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 Increments 0.01 A Pickup current I>>...

  • Page 466: Inverse-Time Overcurrent Protection (Ansi 51V)

    Technical Data 4.3 Inverse-Time Overcurrent Protection (ANSI 51V) Inverse-Time Overcurrent Protection (ANSI 51V) Setting Ranges / Increments Pickup current I (phases) for I = 1 A 0.10 A to 4.00 A Increments 0.01 A for I = 5 A 0.50 A to 20.00 A Increments 0.01 A Time Multipliers T for I 0.05 s to 3.20 s...
  • Page 467 Technical Data 4.3 Inverse-Time Overcurrent Protection (ANSI 51V) Figure 4-1 Trip Characteristics of the Inverse-time Overcurrent Protection, acc. to IEC SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...
  • Page 468 Technical Data 4.3 Inverse-Time Overcurrent Protection (ANSI 51V) Trip Time Characteristics according to ANSI As per ANSI/IEEE (see also Figures 4-2 and 4-3) The tripping times for I/I ≥ 20 are identical with those for I/I = 20. Pickup Threshold approx.
  • Page 469 Technical Data 4.3 Inverse-Time Overcurrent Protection (ANSI 51V) Figure 4-2 Trip Time Characteristics of the Inverse-time Overcurrent Protection, acc. to ANSI/IEEE SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...
  • Page 470 Technical Data 4.3 Inverse-Time Overcurrent Protection (ANSI 51V) Figure 4-3 Trip Time Characteristics of the Inverse-time Overcurrent Protection, acc. to ANSI/IEEE SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 471: Thermal Overload Protection (Ansi 49)

    Technical Data 4.4 Thermal Overload Protection (ANSI 49) Thermal Overload Protection (ANSI 49) Setting Ranges / Increments Factor k according to IEC 60255-8 0.10 to 4.00 Increments 0.01 Time constant τ 30 s to 32000 s Increments 1 s Extension of Time Constant at Standstill 1.0 to 10.0 Increments 0.1 Thermal alarm Θ...
  • Page 472 Technical Data 4.4 Thermal Overload Protection (ANSI 49) Influencing Variables referring to k · I Power supply direct voltage in range 0.8 ≤ U ≤ 1.15 ≤ 1 % AusN Temperature in range 23.00 °F (–5 °C) ≤ Θ ≤ 131.00 °F (55 °C) ≤...

  • Page 473: Unbalanced Load (Negative Sequence) Protection (Ansi 46)

    Technical Data 4.5 Unbalanced Load (Negative Sequence) Protection (ANSI 46) Unbalanced Load (Negative Sequence) Protection (ANSI 46) Setting Ranges / Increments Admissible unbalanced load I 3.0 % to 30.0 % Increments 0.1 % 2 perm. (also alarm stage) Unbalanced load tripping stage I >>/I 10 % to 200 % Increments 1 %...
  • Page 474 Technical Data 4.5 Unbalanced Load (Negative Sequence) Protection (ANSI 46) Figure 4-5 Trip times of the Thermal Characteristic for Unbalanced Load Protection SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 475: Startup Overcurrent Protection (Ansi 51)

    Technical Data 4.6 Startup Overcurrent Protection (ANSI 51) Startup Overcurrent Protection (ANSI 51) Setting Ranges / Increments Pickup current I> for I = 1 A 0.10 A to 20.00 A Increments 0.01 A for I = 5 A 0.50 A to 100.00 A Increments 0.01 A Delay times T 0.00 s to 60.00 s...

  • Page 476: Differential Protection (Ansi 87G/87M/87T) For Generators And Motors

    Technical Data 4.7 Differential Protection (ANSI 87G/87M) for Generators and Motors Differential Protection (ANSI 87G/87M) for Generators and Motors Setting Ranges / Increments Differential current I >/I 0.05 to 2.00 Increments 0.01 DIFF N Gen High-current stage I >>/I 0.5 to 12.0 Increments 0.1 DIFF N Gen...
  • Page 477 Technical Data 4.7 Differential Protection (ANSI 87G/87M) for Generators and Motors Influencing Variables for Pickup Values Power supply direct voltage in range 0.8 ≤ U ≤ 1.15 ≤ 1 % AuxN Temperature in range 23.00 °F (–5 °C) ≤ Θ ≤...

  • Page 478: Differential Protection (Ansi 87G/87M/87T) For Transformers

    Technical Data 4.8 Differential Protection (ANSI 87T) for Transformers Differential Protection (ANSI 87T) for Transformers Setting Ranges / Increments Differential current I >/I 0.05 to 2.00 Increments 0.01 DIFF N Transf High-current stage I >>/I 0.5 to 12.0 Increments 0.1 DIFF N Transf or ∞...
  • Page 479 Technical Data 4.8 Differential Protection (ANSI 87T) for Transformers Tolerances With Preset Transformer Parameters - Pickup Characteristic ± 3 % of setpoint (for I < 5 · I - Inrush Restraint ± 3 % of setting value (for I ≥ 15 %) - Additional Delay Times ±...
  • Page 480 Technical Data 4.8 Differential Protection (ANSI 87T) for Transformers Figure 4-10 Restraining Influence of Higher-Order Harmonics Figure 4-11 Influence of Frequency in Transformer Differential Protection where: Differential current = |I DIFF Current at nominal frequency Current at any frequency within specified range SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 481: Earth Current Differential Protection (Ansi 87Gn,Tn)

    Technical Data 4.9 Earth Current Differential Protection (ANSI 87GN,TN) Earth Current Differential Protection (ANSI 87GN,TN) Setting Ranges / Increments Differential current I-REF> I/I 0.05 to 2.00 Increments 0.01 N Obj Characteristic: base point I/I 0.00 to 2.00 Increments 0.01 N Obj. Characteristic: Slope 0.00 to 0.95 Increments 0.01...

  • Page 482: Underexcitation (Loss-Of-Field) Protection (Ansi 40)

    Technical Data 4.10 Underexcitation (Loss-of-Field) Protection (ANSI 40) 4.10 Underexcitation (Loss-of-Field) Protection (ANSI 40) Setting Ranges / Increments Conductance Sections 1/xd Char. 0.20 to 3.00 Increments 0.01 Slope angle α1, α2, α3 50° to 120° Increments 1° Delay times T 0.00 s to 60.00 s or ∞...

  • Page 483: Reverse Power Protection (Ansi 32R)

    Technical Data 4.11 Reverse Power Protection (ANSI 32R) 4.11 Reverse Power Protection (ANSI 32R) Setting Ranges / Increments Reverse power P >/S –0.50 % to –30.00 % Increments 0.01 % reverse Delay times T 0.00 s to 60.00 s Increments 0.01 s or ∞...

  • Page 484: Forward Active Power Supervision (Ansi 32F)

    Technical Data 4.12 Forward Active Power Supervision (ANSI 32F) 4.12 Forward Active Power Supervision (ANSI 32F) Setting Ranges / Increments Forward power P </S 0.5 % to 120.0 % Increments 0.1 % Forward Nenn Forward power P >/S 1.0 % to 120.0 % Increments 0.1 % Forward Delay times T...

  • Page 485: Impedance Protection (Ansi 21)

    Technical Data 4.13 Impedance Protection (ANSI 21) 4.13 Impedance Protection (ANSI 21) Pickup Pickup current IMP I> for I = 1 A 0.10 A to 20.00 A Increments 0.01 A for I = 5 A 0.50 A to 100.00 A Increments 0.05 A Dropout Ratio approx.
  • Page 486 Technical Data 4.13 Impedance Protection (ANSI 21) Influencing Variables for Pickup Values Power supply direct voltage in range 0.8 ≤ U ≤ 1 % ≤ AuxN 1.15 Temperature in range 23.00 °F (–5 °C) ≤ Θ ≤ 131.00 °F ≤ 0.5 % / 10 K (55 °C) Frequency in range 0.95 ≤...

  • Page 487: Out-Of-Step Protection (Ansi 78)

    Technical Data 4.14 Out-of-Step Protection (ANSI 78) 4.14 Out-of-Step Protection (ANSI 78) Pickup Positive sequence current I >/I 20.0 % to 400.0 % Increments 0.1 % Negative sequence current I </I 5.0 % to 100.0 % Increments 0.1 % Dropout ratios >...

  • Page 488: Undervoltage Protection (Ansi 27)

    Technical Data 4.15 Undervoltage Protection (ANSI 27) 4.15 Undervoltage Protection (ANSI 27) Setting Ranges / Increments Measured Quantity Positive Sequence phase-to-earth voltages as phase-to-phase Values Pickup voltages U<, U<<, Up< 10.0 V to 125.0 V Increments 0.1 V Rückfallverhältnis RV U< (nur Stufen U<, U<<) 1.01 to 1.20 Increments 0.01 Time delays T U<, T U<<...
  • Page 489 Technical Data 4.15 Undervoltage Protection (ANSI 27) Influencing Variables Power supply direct voltage in range 0.8 ≤ U ≤ 1.15 ≤ 1 % AuxN Temperature in range 23.00 °F (–5 °C) ≤ Θ ≤ 131.00 °F (55 °C) ≤ 0.5 % / 10 K Frequency in range 0.95 ≤...

  • Page 490: Overvoltage Protection (Ansi 59)

    Technical Data 4.16 Overvoltage Protection (ANSI 59) 4.16 Overvoltage Protection (ANSI 59) Setting Ranges / Increments Measured Quantity Maximum of the phase-to-phase voltages, calculat- ed from the phase-to-earth voltages Pickup thresholds U>, U>> 30.0 V to 170.0 V Increments 0.1V Rückfallverhältnis RV U>...

  • Page 491: Frequency Protection (Ansi 81)

    Technical Data 4.17 Frequency Protection (ANSI 81) 4.17 Frequency Protection (ANSI 81) Setting Ranges / Increments Number of Frequency Elements 4; can be set to f> or f< Pickup Frequency f> or f< 40 Hz to 66.00 Hz Increments 0.01 Hz Delay Times T f1 0.00 s to 600.00 s...

  • Page 492: Overexcitation (Volt/Hertz) Protection (Ansi 24)

    Technical Data 4.18 Overexcitation (Volt/Hertz) Protection (ANSI 24) 4.18 Overexcitation (Volt/Hertz) Protection (ANSI 24) Setting Ranges / Increments Pickup threshold (Alarm Stage) 1.00 to 1.20 Increments 0.01 Pickup threshold of stage characteristic 1.00 to 1.40 Increments 0.01 Time delays T U/f>, T U/f>> 0.00 s to 60.00 s Increments 0.01 s (Alarm and stage characteristic)
  • Page 493 Technical Data 4.18 Overexcitation (Volt/Hertz) Protection (ANSI 24) Influencing Variables Power supply direct voltage in range 0.8 ≤ U ≤ 1.15 ≤ 1 % AuxN Temperature in range 23.00 °F (–5 °C) ≤ Θ ≤ 131.00 °F (55 °C) ≤ 0.5 % / 10 K Harmonics –...

  • Page 494: Rate-Of-Frequency-Change Protection Df/Dt (Ansi 81R)

    Technical Data 4.19 Rate-of-Frequency-Change Protection df/dt (ANSI 81R) 4.19 Rate-of-Frequency-Change Protection df/dt (ANSI 81R) Setting Ranges / Increments Stages, can be +df/dt> or –df/dt Pickup values df/dt 0.1 Hz/s to 10.0 Hz/s Increments 0.1 Hz/s Delay times T 0.00 s to 60.00 s Increments 0.01 s or ∞...

  • Page 495: Jump Of Voltage Vector

    Technical Data 4.20 Jump of Voltage Vector 4.20 Jump of Voltage Vector Setting Ranges / Increments Stufe Δϕ 2° to 30° Increments 1° Delay Time T 0.00 to 60.00 s Increments 0.01 s or ∞ (ineffective) Reset Time T 0.00 to 60.00 s Increments 0.00 s Reset or ∞...

  • Page 496: Stator Earth Fault Protection (Ansi 59N, 64G, 67G)

    Technical Data 4.21 90-%-Stator Earth Fault Protection (ANSI 59N, 64G, 67G) 4.21 90-%-Stator Earth Fault Protection (ANSI 59N, 64G, 67G) Setting Ranges / Increments Displacement voltage U0> 2.0 V to 125.0 V Increments 0.1 V Earth current 3I0> 2 mA to 1000 mA Increments 1 mA Earth current angle criterion 0°...

  • Page 497: Sensitive Earth Fault Protection (Ansi 51Gn, 64R)

    Technical Data 4.22 Sensitive Earth Fault Protection (ANSI 51GN, 64R) 4.22 Sensitive Earth Fault Protection (ANSI 51GN, 64R) Setting Ranges / Increments Pickup current I > 2 mA to 1000 mA Increments 1 mA Delay Time T > 0.00 s to 60.00 s Increments 0.01 s or ∞...

  • Page 498: Stator Earth Fault Protection With 3Rd Harmonics (Ansi 27/59Tn 3Rd Harm.)

    Technical Data 4.23 100-%-Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) 4.23 100-%-Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) Setting Ranges / Increments Pickup value for 3rd harmonic in undervoltage stage 0.2 V to 40.0 V Increments 0.1 V <...

  • Page 499: Stator Earth Fault Protection With 20 Hz Voltage Injection (Ansi 64G - 100%)

    Technical Data 4.24 100-%-Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G - 100%) 4.24 100-%-Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G - 100%) Setting Ranges / Increments Alarm Stage R < 20 Ω to 700 Ω Increments 1 Ω...

  • Page 500: Sensitive Earth Fault Protection B (Ansi 51Gn)

    Technical Data 4.25 Sensitive Earth Fault Protection B (ANSI 51GN) 4.25 Sensitive Earth Fault Protection B (ANSI 51GN) Setting Ranges / Increments Pickup Current I > 0.3 mA to 1000.0 mA Increments 0.1 mA EE-B Delay Time T > 0.00 s to 60.00 s Increments 0.01 s IEE-B or ∞...

  • Page 501: Interturn Protection (Ansi 59N (It))

    Technical Data 4.26 Interturn Protection (ANSI 59N (IT)) 4.26 Interturn Protection (ANSI 59N (IT)) Setting Ranges / Increments Pickup thresholds of displacement voltage Uw> 0.3 V to 130.0 V Increments 0.1 V > 0.00 s to 60.00 s Increments 0.01 s Interturn or ∞...

  • Page 502: Rotor Earth Fault Protection R, Fn (Ansi 64R)

    Technical Data 4.27 Rotor Earth Fault Protection R, fn (ANSI 64R) 4.27 Rotor Earth Fault Protection R, fn (ANSI 64R) Setting Ranges / Increments Alarm Stage R 3.0 kΩ to 30.0 kΩ Increments 0.1 kΩ E ALARM Tripping Stage R 1.0 kΩ...
  • Page 503 Technical Data 4.27 Rotor Earth Fault Protection R, fn (ANSI 64R) Tolerances Alarm Stage, Tripping Stage 5 % for R ≤ 5 kΩ and 0.15 ≤ C /µF≤ 3 10 % for R ≤ 10 kΩ and 0.15 ≤ C /µF≤...

  • Page 504: Sensitive Rotor Earth Fault Protection With 1 To 3 Hz Square Wave Voltage Injection (Ansi 64R - 1 To 3 Hz)

    Technical Data 4.28 Sensitive Rotor Earth Fault Protection with 1 to 3 Hz Square Wave Voltage Injection (ANSI 64R - 1 to 3 Hz) 4.28 Sensitive Rotor Earth Fault Protection with 1 to 3 Hz Square Wave Voltage Injection (ANSI 64R - 1 to 3 Hz) Setting Ranges / Increments Alarm Stage R 5 kΩ...

  • Page 505: Motor Starting Time Supervision (Ansi 48)

    Technical Data 4.29 Motor Starting Time Supervision (ANSI 48) 4.29 Motor Starting Time Supervision (ANSI 48) Setting Ranges / Increments Anlaufstrom des Motors I for I = 1 A 0.10 A to 16.00 A Increments 0.01 A for I = 5 A 0.50 A to 80.00 A Increments 0.01 A Pickup Threshold for Startup Detection...

  • Page 506: Restart Inhibit For Motors (Ansi 66, 49Rotor)

    Technical Data 4.30 Restart Inhibit for Motors (ANSI 66, 49Rotor) 4.30 Restart Inhibit for Motors (ANSI 66, 49Rotor) Setting Ranges / Increments Motor starting current relative to the Nominal Motor Current 1.5 to 10.0 Increments 0.1 StartCurr Mot.Nenn Max. admissable Startup Timen t 3.0 s to 120.0 s Increments 0.1 s Start Max.

  • Page 507: Breaker Failure Protection (Ansi 50Bf)

    Technical Data 4.31 Breaker Failure Protection (ANSI 50BF) 4.31 Breaker Failure Protection (ANSI 50BF) Setting Ranges / Increments Pickup thresholds B/F I> for I = 1 A 0.04 A to 2.00 A Increments 0.01 A for I = 5 A 0.20 A to 10.00 A Increments 0.01 A Delay Time BF-T...

  • Page 508: Inadvertent Energization (Ansi 50, 27)

    Technical Data 4.32 Inadvertent Energization (ANSI 50, 27) 4.32 Inadvertent Energization (ANSI 50, 27) Setting Ranges / Increments Pickup current I >>> for I = 1 A 0.1 A to 20.0 A Increments 0.1 A or ∞ (ineffective) for I = 5 A 0.5 A to 100.0 A Increments 0.1 A...

  • Page 509: Dc Voltage/Current Protection (Ansi 59Ndc/51Ndc)

    Technical Data 4.33 DC Voltage/Current Protection (ANSI 59NDC/51NDC) 4.33 DC Voltage/Current Protection (ANSI 59NDC/51NDC) Setting Ranges / Increments Voltage increase U≥ 0.1 V to 8.5 V Increments 0.1V Voltage Decrease U≤ 0.1 V to 8.5 V Increments 0.1V Current Increase I≥ 0.2 mA to 17.0 mA Increments 0.1 mA Current Decrease I≤...

  • Page 510: Temperature Detection By Thermoboxes

    Technical Data 4.34 Temperature Detection by Thermoboxes 4.34 Temperature Detection by Thermoboxes Temperature Detectors connectable thermoboxes 1 or 2 Number of temperature detectors per thermobox Max. 6 Measuring Method Pt 100 Ω or Ni 100 Ω or Ni 120 Ω Mounting Identification „Oil“...

  • Page 511: Threshold Supervision

    Technical Data 4.35 Threshold supervision 4.35 Threshold supervision Setting Ranges / Increments Threshold MV1> to MV10< –200 % to +200 % Increments 1 % Assignable Measured Values P, Active Power Q, Reactive Power Change of active power ΔP Voltage U Voltage U Voltage U Voltage U...

  • Page 512: User-Defined Functions (Cfc)

    Technical Data 4.36 User-defined Functiones (CFC) 4.36 User-defined Functiones (CFC) Function Modules and Possible Assignments to Task Levels Function Module Explanation Task Level PLC1_ PLC_ SFS_ BEARB BEARB BEARB BEARB ABSVALUE Magnitude Calculation — — — Addition ALARM Alarm clock AND - Gate FLASH Blink block...
  • Page 513 Technical Data 4.36 User-defined Functiones (CFC) Function Module Explanation Task Level PLC1_ PLC_ SFS_ BEARB BEARB BEARB BEARB Multiplication MV_GET_STATUS Decode status of a value MV_SET_STATUS Set status of a value NAND NAND - Gate Negator NOR - Gate OR - Gate REAL_TO_DINT Adaptor REAL_TO_INT...
  • Page 514 Technical Data 4.36 User-defined Functiones (CFC) Device-specific Limits Description Limit Comments Maximum number of synchronous When the limit is exceeded, an error message is output by changes of chart inputs per task level the device. Consequently, the device starts monitoring. The red ERROR-LED lights up.
  • Page 515 Technical Data 4.36 User-defined Functiones (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 Arithmetic ABS_VALUE...
  • Page 516 Technical Data 4.36 User-defined Functiones (CFC) Individual Element Number of TICKS Type converter BOOL_TO_DI BUILD_DI DI_TO_BOOL DM_DECODE DINT_TO_REAL DIST_DECODE UINT_TO_REAL REAL_TO_DINT REAL_TO_UINT Comparison COMPARE LOWER_SETPOINT UPPER_SETPOINT LIVE_ZERO ZERO_POINT Metered value COUNTER Time and clock pulse TIMER TIMER_LONG TIMER_SHORT ALARM FLASH Configurable in Matrix In addition to the defined preassignments, indications and measured values can be freely configured to buff- ers, preconfigurations can be removed.

  • Page 517: Additional Functions

    Technical Data 4.37 Additional Functions 4.37 Additional Functions Operational Measured Values Operational Measured Values for L1, S1 L2, S1 L3, S1 L1, S2 L2, S2 L3, S2 Currents in A (kA) primary and in A secondary or in % I Range 10 % to 200 % I Tolerance...
  • Page 518 Technical Data 4.37 Additional Functions Operational Measurement S, apparent power Values for Power in kVAr (MVAr or GVAr) primary and in % S Range 0 % to 120 % S Tolerance 1 % ±0,25 % S , with SN = √3 · U ·...
  • Page 519 Technical Data 4.37 Additional Functions Amplitude of Rotor Voltage Injec- in V tion Range 0.0 V to 60.0 V Tolerance 0.5 V Rotor Circuit Current in mA N, Gen Range 0.00 mA to 20.00 mA Tolerance 0.05 mA Charge at Polarity Reversal in mAs Range 0.00 mAs to 1.00 mAs...
  • Page 520 Technical Data 4.37 Additional Functions Min / Max Report Report of Measured Values with date and time Reset manual using binary input using keypad using communication Min/Max Values for Current Positive Sequence Components Min/Max Values for Voltage Positive Sequence Components Min/Max Values for 3rd Harmonics in Displacement Voltage Min/Max Values for Power P, Q...
  • Page 521 Technical Data 4.37 Additional Functions Fault Recording Maximum 8 fault records saved by buffer battery also through auxiliary voltage failure Instantaneous Values: Recording Time total 5 s Pre-event and post-event recording and memory time ad- justable Sampling grid for 50 Hz 1 sample/1.25 ms Sampling grid for 60 Hz 1 sample/1.04 ms...
  • Page 522 Technical Data 4.37 Additional Functions Clock Time synchronization DCF 77 / IRIG B Signal (telegram format IRIG-B000) Binary Input Communication Group Switchover of the Function Parameters Number of Available Setting Groups 2 (parameter group A and B) Switchover can be performed using the keypad DIGSI using the operating interface with protocol via system interface...

  • Page 523: Operating Range Of The Protection Functions

    Technical Data 4.38 Operating Range of the Protection Functions 4.38 Operating Range of the Protection Functions Table 4-1 Operating ranges of the protection functions Operational state Operational state 1 Operational state f ≤ 10 Hz 11 Hz < f/Hz ≤ 40 40 Hz ≤ f/Hz ≤ 69 f ≥...
  • Page 524 Technical Data 4.38 Operating Range of the Protection Functions Operational state Operational state 1 Operational state f ≤ 10 Hz 11 Hz < f/Hz ≤ 40 40 Hz ≤ f/Hz ≤ 69 f ≥ 70 Hz Protective Elements Motor Starting Time Supervision inactive inactive active...

  • Page 525: Dimensions

    Technical Data 4.39 Dimensions 4.39 Dimensions 4.39.1 Panel Flush and Cubicle Mounting (Housing Size Figure 4-14 Dimensions of a 7UM621 or a 7UM623 for Panel Flush Mounting or Cubicle Installation (size 1/2) SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 526: Housing For Panel Flush Mounting Or Cubicle Mounting (Size )

    Technical Data 4.39 Dimensions 4.39.2 Housing for Panel Flush Mounting or Cubicle Mounting (Size Figure 4-15 Dimensions of a 7UM622 for Panel Flush Mounting or Cubicle Installation (size 1/1) SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 527: Panel Flush Mounting (Housing Size )

    Technical Data 4.39 Dimensions 4.39.3 Panel Flush Mounting (Housing Size Figure 4-16 Dimensions of a 7UM621 for Panel Surface Mounting (housing size 1/2) 4.39.4 Housing for Panel Surface Mounting (Size Figure 4-17 Dimensions of a 7UM622 for Panel Surface Mounting (housing size 1/1) SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 528: Dimensional Drawing Of Coupling Device 7Xr6100-0Ca0 For Panel Flush Mounting

    Technical Data 4.39 Dimensions 4.39.5 Dimensional Drawing of Coupling Device 7XR6100-0CA0 for Panel Flush Mounting Figure 4-18 Dimensions of Coupling Unit 7XR6100-0CA0 for Panel Flush Mounting SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 529: Dimensions Of Coupling Unit 7Xr6100-0Ba0 For Panel Surface Mounting

    Technical Data 4.39 Dimensions 4.39.6 Dimensions of Coupling Unit 7XR6100-0BA0 for Panel Surface Mounting Figure 4-19 Dimensions of Coupling Unit 7XR6100-0BA0 for Panel Surface Mounting SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 530: Dimensional Drawing Of 3Pp13

    Technical Data 4.39 Dimensions 4.39.7 Dimensional Drawing of 3PP13 Figure 4-20 Dimension Diagrams 3PP13: 3PP132 for voltage divider 3PP1326-0BZ-012009 (20 : 10 : 1) 3PP133 for voltage divider 3PP1336-1CZ-013001 (5 : 2 : 1) for series resistor 3PP1336-0DZ-013002 SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 531: Dimensional Drawing Of Series Device 7Xt7100-0Ba00 For Panel Surface Mounting

    Technical Data 4.39 Dimensions 4.39.8 Dimensional Drawing of Series Device 7XT7100-0BA00 for Panel Surface Mounting Figure 4-21 Dimensions of Series Device 7XT7100-0BA00 for Panel Surface Mounting where: Current connections (terminals 1 to 6) not used in 7XT71 Control connections (terminals 7 to 31) insulated ring-type cable lug: for bolts of 4 mm, max.

  • Page 532: Dimensions Of Series Unit 7Xt7100-0Ea00 For Panel Flash Mounting

    Technical Data 4.39 Dimensions 4.39.9 Dimensions of Series Unit 7XT7100-0EA00 for Panel Flash Mounting Figure 4-22 Dimensions of Series Unit 7XT7100-0EA00 for Panel Flash Mounting where: Current connections (terminals 1 to 6) not used in 7XT71 Control connections (terminals 7 to 31) Screw terminals (ring-type cable lug): for bolts of 4 mm, max.

  • Page 533: Dimensional Drawing Of Resistor Unit 7Xr6004-0Ca00 For Panel Surface Mounting Or Cubicle Flush Mounting

    Technical Data 4.39 Dimensions 4.39.10 Dimensional Drawing of Resistor Unit 7XR6004-0CA00 for Panel Surface Mounting or Cubicle Flush Mounting Figure 4-23 Dimensions of Resistor Unit 7XR6004-0CA00 for Panel Flush or Cubicle Mounting SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 534: Dimensions Of Resistor Unit 7Xr6004-0Ba00 For Panel Surface Mounting

    Technical Data 4.39 Dimensions 4.39.11 Dimensions of Resistor Unit 7XR6004-0BA00 for Panel Surface Mounting Figure 4-24 Dimensions of Resistor Unit 7XR6004-0BA00 for Panel Surface Mounting SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 535: Dimensional Drawing Of 20 Hz Generator 7Xt3300-0Ca00 For Panel Surface Mounting Or Cubicle Flush Mounting

    Technical Data 4.39 Dimensions 4.39.12 Dimensional Drawing of 20 Hz Generator 7XT3300-0CA00 for Panel Surface Mounting or Cubicle Flush Mounting Figure 4-25 Dimensions of 20 Hz Generator 7XT3300-0CA00 for Panel Flash or Cubicle Mounting SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 536: Maßbild 20 Hz-Generator 7Xt3300-0Ca00/Dd Für Schalttafel- Oder Schrankeinbau

    Technical Data 4.39 Dimensions 4.39.13 Dimensional Drawing of 20 Hz-Generator 7XT3300-0CA00/DD for Panel Surface Mounting oe Cubicle Flush Mounting Figure 4-26 Dimensions of a 20-Hz Generator 7XT3300-0CA00/DD for Panel Flush or Cubicle Mounting SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 537: Dimensional Drawing Of 20 Hz Generator 7Xt3300-0Ba00 For Panel Surface Mounting

    Technical Data 4.39 Dimensions 4.39.14 Dimensional Drawing of 20 Hz Generator 7XT3300-0BA00 for Panel Surface Mounting Figure 4-27 Dimensions of 20 Hz Generator 7XT3300-0BA00 for Panel Surface Mounting SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 538: Maßbild 20 Hz-Generator 7Xt3300-0Ba00/Dd Für Schalttafelaufbau

    Technical Data 4.39 Dimensions 4.39.15 Dimensional Drawing of 20 Hz-Generator 7XT3300-0BA00/DD for Panel Surface Mounting Figure 4-28 Dimensions of a 20-Hz-Generator 7XT3300-0BA00/DD for Panel Surface Mounting SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 539: Dimensional Drawing Of 20 Hz Bandpass 7Xt3400-0Ca00 For Panel Surface Mounting Or Cubicle Flush Mounting

    Technical Data 4.39 Dimensions 4.39.16 Dimensional Drawing of 20 Hz Bandpass 7XT3400-0CA00 for Panel Surface Mounting or Cubicle Flush Mounting Figure 4-29 Dimensions of 20-Hz-Band-Pass Filter 7XT3400-0CA00 for Panel Flush or Cubicle Mounting For panel flush mounting, 2 set squares C73165- A63-C201-1 are necessary since the mounting rails of the device housing are not sufficient for the high weight of the 7XT34 device.

  • Page 540: Dimensional Drawing Of 20 Hz Bandpass 7Xt3400-0Ba00 For Panel Surface Mounting

    Technical Data 4.39 Dimensions 4.39.17 Dimensional Drawing of 20 Hz Bandpass 7XT3400-0BA00 for Panel Surface Mounting Figure 4-30 Dimensions of 20 Hz Bandpass Filter 7XT3400-0BA00 for Panel Surface Mounting Two set squares C73165-A63-C201-1 and 4 distance pieces C73165-A63-C203-1 are necessary for panel surface mounting.

  • Page 541: Appendix

    Appendix This appendix is primarily a reference for the experienced user. This section provides ordering information for the models of this device. Connection diagrams for indicating the terminal connections of the models of this device are included. Following the general diagrams are diagrams that show the proper connections of the devices to primary equipment in many typical power system configurations.

  • Page 542: Ordering Information And Accessories

    Appendix A.1 Ordering Information and Accessories Ordering Information and Accessories A.1.1 Ordering Information A.1.1.1 Order Key 10 11 12 13 14 15 17 18 19 — — Multi-Functional Pro- tective Relay with Local Control Housing, Number of Binary Inputs and Outputs Pos.
  • Page 543 Additional device/module for surface-mounted housing Protocol Converter Order No. Remark Module Profibus DP 6GK1502-2CB10 For single ring SIEMENS OLM 6GK1502-3CB10 For double ring Modbus RS485/FO 7XV5651-0BA00 – DNP 3.0 820 nm RS485/FO The OLM converter requires an operating voltage of 24 VDC. If the operating voltage is > 24 VDC the additional power supply 7XV5810-0BA00 is required.
  • Page 544 Appendix A.1 Ordering Information and Accessories Measuring functions Pos. 13 without extended measuring functionality Min/Max Values, Energy Metering Functionality Pos. 14 Generator Basis, comprising: ANSI No. Overcurrent protection with Undervoltage Seal-In I> +U< Overcurrent protection, directed I>>, dir. 50/51/67 Inverse Time Overcurrent Protection t=f(I) +U<...
  • Page 545 Appendix A.1 Ordering Information and Accessories Functionality Pos. 14 Asynchronous Motor, comprising: ANSI No. Basic Generator but without underexcitation protection, overexcitation protection and rotor earth fault protection (fn, R measurement) Transformer, comprising: ANSI No. Basic generator but without underexcitation protection, unbalanced load protection, motor starting time supervision and rotor earth fault protection (fn, R measurement) Functionality/Additional Functions ANSI No.

  • Page 546: Accessories

    Appendix A.1 Ordering Information and Accessories A.1.2 Accessories Replacement modules for interfaces Name Order No. RS232 C73207-A351-D641-1 RS 485 C73207-A351-D642-1 FO 820 nm C73207-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 opt. 820 nm C53207-A351-D623-1 DNP3.0 RS485 C53207-A351-D631-3...
  • Page 547 Appendix A.1 Ordering Information and Accessories Battery Lithium Battery 3 V/1 Ah, Type CR 1/2 AA Order No. VARTA 6127 101 501 Coupling unit Coupling unit for rotor earth fault protection (R, f Order No. Coupling device for panel surface mounting 7XR6100-0CA00 Coupling device for panel flush mounting 7XR6100-0BA00...
  • Page 548 Appendix A.1 Ordering Information and Accessories 20 Hz Bandpass Filter 20 Hz Bandpass Filter Order No. Surface-mounted housing with screw terminals 7XT3400-0BA00 In housing with screw terminals 7XT3400-0CA00 Interface Cable Interface cable between PC and SIPROTEC device Order Number Cable with 9-pole male / female connector 7XV5100-4 SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 549: Terminal Assignments

    Appendix A.2 Terminal Assignments Terminal Assignments A.2.1 Panel Flush Mounting or Cubicle Mounting 7UM621/623*-*D/E Figure A-1 General Diagram for 7UM621/623*-*D/E (panel flush mounting or cubicle mounting) SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...
  • Page 550 Appendix A.2 Terminal Assignments 7UM622*-*D/E Figure A-2 General Diagram for 7UM622*–*D/E (panel flush mounting or cubicle mounting) SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 551: Panel Surface Mounting

    Appendix A.2 Terminal Assignments A.2.2 Panel Surface Mounting 7UM621/623*-*B Figure A-3 General Diagram for 7UM621/623*-*B (panel surface mounting) SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...
  • Page 552 Appendix A.2 Terminal Assignments 7UM622*-*B Figure A-4 General Diagram for 7UM622*-*B (panel surface mounting) SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 553: Connection Examples

    Appendix A.3 Connection Examples Connection Examples A.3.1 7UM62 - Connection Examples Figure A-5 Busbar Connection Current and voltage connections to three transformers (phase-to-ground voltages), and in each case three CTs, earth current from an additional summation current transformer for sensitive earth fault detection;...
  • Page 554 Appendix A.3 Connection Examples Figure A-6 Busbar System with Low-resistance Earthing Transformer connections to three voltage transformers (phase-to-earth voltages) and in each case three CTs - earth fault detection as differential current measuring by two CT sets; detection of displacement voltage at broken delta winding (da–dn) as additional criterion. SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...
  • Page 555 Appendix A.3 Connection Examples Figure A-7 Unit Connection with Isolated Starpoint Transformer connections to three voltage transformers (phase-to-earth voltages) and in each case three current transformers, differential protection function used only for the generator; Detection of displacement voltage at a broken delta winding (da–dn). SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...
  • Page 556 Appendix A.3 Connection Examples Figure A-8 Unit Connection with Neutral Transformer Connections to three voltage transformers (phase-to-earth voltages) and in each case three current transformers, differential protection function connected via generator and unit transformer; Loading resistor connected either directly to starpoint circuit or via matching transformers. SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...
  • Page 557 Appendix A.3 Connection Examples Figure A-9 Startup Earth Fault Protection Connection of DC Voltage Input TD1 with Series-Connected Amplifier 7KG6 for Systems with Startup Converter Figure A-10 Rotor Earth Fault Protection with additional unit 7XR61 for injecting nominal-frequency voltage in the rotor circuit using series resistor 3PP1336 Note 3PP13 is only necessary if more than 0.2 A are flowing permanently;...
  • Page 558 Appendix A.3 Connection Examples Figure A-12 Asynchronous Motor Connection to three voltage transformers (phase-to-earth voltages, usually from the busbar); Displacement voltage detection at broken delta winding, and three current transformers on each side; Earth fault direction detection using toroidal CT(s) SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...
  • Page 559 Appendix A.3 Connection Examples Figure A-13 Voltage Transformer Connections for Two Voltage Transformers in Open Delta Connection (V Connection) Figure A-14 Voltage Transformer Connection with L2 Earthed on the Secondary Side Figure A-15 Rotor Earth Fault Protection 1-3 Hz – with 1- 3-Hz-Generator 7XT71 and resistor device 7XR6004. Note For further examples see manual 7XR6004 SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...
  • Page 560 Appendix A.3 Connection Examples Figure A-16 100 % Stator Earth Fault Protection with 20 Hz generator 7XT33, bandpass 7XT34 and startup earth fault protection – with shunt 10 A/150 mV and measuring transducer 7KG6. The voltage divider is only requred for secondary-side voltages > 200 V. The voltage divider must be connected directly to the load resistor R via two lines.

  • Page 561: Connection Examples For Rtd Box

    Appendix A.3 Connection Examples Figure A-18 Earth Current Differential Protection (Transformer) A.3.2 Connection Examples for RTD Box Figure A-19 Simplex Operation with one RTD Box above: optical design (1 FOs) below: design with RS485 Figure A-20 Semiduplex Operation with one RTD Box above: optical design (2 FOs) below: design with RS485 SIPROTEC, 7UM62, Manual...

  • Page 562: Schematic Diagram Of Accessories

    Appendix A.3 Connection Examples Figure A-21 Semiduplex Operation with two RTD Boxes above: optical design (2 FOs) below: design with RS485 A.3.3 Schematic Diagram of Accessories Figure A-22 Schematic Diagram of Coupling Unit 7XR6100-0*A00 for Rotor Earth Fault Protection Figure A-23 Schematic Diagram of Series Resistor 3PP1336-0DZ-K2Y SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...
  • Page 563 Appendix A.3 Connection Examples Figure A-24 Schematic Diagram of Voltage Divider 5:1; 5:2; 3PP1336-1CZ-K2Y Figure A-25 Schematic Diagram of Voltage Divider 10:1; 20:1; 3PP1326-0BZ-K2Y Figure A-26 General Diagram of Series Device 7XT7100-0*A00 Figure A-27 General Diagram of Resistor Unit 7XR6004-0*A00 SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...
  • Page 564 Appendix A.3 Connection Examples Figure A-28 General Diagram of 20-Hz-Generator 7XT3300-0*A00 Figure A-29 General Diagram of the 20-Hz-Generator 7XT3300-0*A00/DD Figure A-30 General Diagram of 20-Hz Bandpass Filter 7XT3400-0*A00 SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 565: Default Settings

    Appendix A.4 Default Settings Default Settings When the device leaves the factory, a large number of LED indicators, binary inputs and outputs as well as function keys are already preset. They are summarized in the following table. A.4.1 LEDs Table A-2 LED Indication Presettings LEDs Allocated Function...

  • Page 566: Binary Input

    Appendix A.4 Default Settings A.4.2 Binary Input Table A-3 Binary input presettings for all devices and ordering variants Binary Input Allocated Function Function No. Description >SV tripped 5086 >Stop valve tripped >Uexc fail. 5328 >Exc. voltage failure recognized >BLOCK f1 5206 >BLOCK stage f1 >BLOCK U<...

  • Page 567: Function Keys

    Appendix A.4 Default Settings Binary Output Allocated Function Function No. Description I> TRIP 1815 O/C I> TRIP S/E/F TRIP 5193 Stator earth fault protection TRIP U>> TRIP 6573 Overvoltage U>> TRIP f1 TRIP 5236 f1 TRIP f2 TRIP 5237 f2 TRIP Exc<3 TRIP 5343 Underexc.

  • Page 568: Default Display

    Appendix A.4 Default Settings A.4.5 Default Display 4-line Display Table A-6 This selection is available as start page which may be configured. Page 1 Page 2 Page 3 Page 4 Graphic Display Figure A-31 Default displays of a graphical display SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 569: Pre-Defined Cfc Charts

    Appendix A.4 Default Settings Spontaneous Fault Message Display The spontaneous display messages appear automatically in the display, after a general pick-up of the 7UM62. The most important data about a fault can be viewed on the device front in the sequence shown in Figure A-32. Figure A-32 Display of spontaneous messages in the device display Spontaneous Fault Indication of the Graphic Display...

  • Page 570: Protocol-Dependent Functions

    Appendix A.5 Protocol-dependent Functions Protocol-dependent Functions Protocol → IEC 60870-5-103 IEC 61850 Profibus DP DNP3.0 Modbus Additional Ethernet ASCII/RTU Service Inter- Function ↓ (EN-100) face (optional) Operational mea- Yes (fixed values) Yes sured values Metered values Fault Recording No. Only via No.

  • Page 571: 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 FAULT VALUE Disabled Instant. values Fault values Instant. values RMS values O/C PROT. I> Disabled Side 2 Overcurrent Protection I>...
  • Page 572 Appendix A.6 Functional Scope Addr. Parameter Setting Options Default Setting Comments OVEREXC. PROT. Disabled Enabled Overexcitation Protection (U/f) Enabled INV.UNDERVOLT. Disabled Enabled Inverse Undervoltage Protection Enabled Up< df/dt Protect. Disabled 2 df/dt stages Rate-of-frequency-change protec- 2 df/dt stages tion 4 df/dt stages VECTOR JUMP Disabled Enabled...
  • Page 573 Appendix A.6 Functional Scope Addr. Parameter Setting Options Default Setting Comments ANALOGOUTP B1/1 Disabled Disabled Analog Output B1/1 (Port B) I1 [%] I2 [%] IEE1 [%] IEE2 [%] U1 [%] U0 [%] U03H [%] |P| [%] |Q| [%] |S| [%] f [%] U/f [%] PHI [%]...
  • Page 574 Appendix A.6 Functional Scope Addr. Parameter Setting Options Default Setting Comments ANALOGOUTP D1/1 Disabled Disabled Analog Output D1/1 (Port D) I1 [%] I2 [%] IEE1 [%] IEE2 [%] U1 [%] U0 [%] U03H [%] |P| [%] |Q| [%] |S| [%] f [%] U/f [%] PHI [%]...
  • Page 575 Appendix A.6 Functional Scope Addr. Parameter Setting Options Default Setting Comments RTD-BOX INPUT Disabled Disabled External Temperature Input Port C Port D RTD CONNECTION 6 RTD simplex 6 RTD simplex Ext. Temperature Input Connec- 6 RTD HDX tion Type 12 RTD HDX ANALOGOUTP B1/2 Disabled Disabled...

  • Page 576: 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 577 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments BkrClosed I MIN P.System Data 1 0.20 .. 5.00 A 0.20 A Closed Breaker Min. Current Threshold 0.04 .. 1.00 A 0.04 A TRANSDUCER 1 P.System Data 1 10 V 10 V Transducer 1 4-20 mA...
  • Page 578 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 1405 IEC CURVE O/C Prot. Ip Normal Inverse Normal Inverse IEC Curve Very Inverse Extremely Inv. 1406 ANSI CURVE O/C Prot. Ip Very Inverse Very Inverse ANSI Curve Inverse Moderately Inv.
  • Page 579 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 2031 I-DIFF>> Diff. Prot 0.5 .. 12.0 I/InO; ∞ 7.5 I/InO Pickup Value of High Set Trip 2036A T I-DIFF>> Diff. Prot 0.00 .. 60.00 sec; ∞ 0.00 sec T I-DIFF>>...
  • Page 580 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 3101 REVERSE POWER Reverse Power Reverse Power Protection Block relay 3102 P> REVERSE Reverse Power -30.00 .. -0.50 % -1.93 % P> Reverse Pickup 3103 T-SV-OPEN Reverse Power 0.00 .. 60.00 sec; ∞ 10.00 sec Time Delay Long (without Stop Valve)
  • Page 581 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 3507 Zd - Zc Out-of-Step 0.00 .. 26.00 Ω 1.28 Ω Reactance Dif. Char.1 - Char.2 (forward) 0.00 .. 130.00 Ω 6.40 Ω 3508 PHI POLYGON Out-of-Step 60.0 .. 90.0 ° 90.0 °...
  • Page 582 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 4310 t(U/f=1.25) Overexcitation 0 .. 20000 sec 30 sec U/f = 1.25 Time Delay 4311 t(U/f=1.30) Overexcitation 0 .. 20000 sec 19 sec U/f = 1.30 Time Delay 4312 t(U/f=1.35) Overexcitation 0 ..
  • Page 583 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 5003 3I0> Stator E Fault 2 .. 1000 mA 5 mA 3I0> Pickup 5004 DIR. ANGLE Stator E Fault 0 .. 360 ° 15 ° Angle for Direction Determination 5005 T S/E/F Stator E Fault...
  • Page 584 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 6002 RE< WARN Rotor E/F 3.0 .. 30.0 kΩ 10.0 kΩ Pickup Value of Warning Stage Re< 6003 RE<< TRIP Rotor E/F 1.0 .. 5.0 kΩ 2.0 kΩ Pickup Value of Tripping Stage Re<<...
  • Page 585 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 7101 INADVERT. EN. Inadvert. En. Inadvertent Energisation Block relay 7102 I STAGE Inadvert. En. 0.5 .. 100.0 A; ∞ 1.5 A I Stage Pickup 0.1 .. 20.0 A; ∞ 0.3 A 7103 RELEASE U1<...
  • Page 586 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 8102 BALANCE U-LIMIT Measurem.Superv 10 .. 100 V 50 V Voltage Threshold for Balance Monitoring 8103 BAL. FACTOR U Measurem.Superv 0.58 .. 0.90 0.75 Balance Factor for Voltage Monitor 8104 BAL.
  • Page 587 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 8505 MEAS. VALUE 3> Threshold Disabled Disabled Measured Value for Threshold MV3> Delta P UL1E UL2E UL3E UE3h IEE1 IEE2 Transducer 1 8506 THRESHOLD MV3> Threshold -200 .. 200 % 100 % Pickup Value of Measured Value MV3>...
  • Page 588 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 8511 MEAS. VALUE 6< Threshold Disabled Disabled Measured Value for Threshold MV6< Delta P UL1E UL2E UL3E UE3h IEE1 IEE2 Transducer 1 8512 THRESHOLD MV6< Threshold -200 .. 200 % 100 % Pickup Value of Measured Value MV6<...
  • Page 589 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 8517 MEAS. VALUE 9> Threshold Disabled Disabled Measured Value for Threshold MV9> Delta P UL1E UL2E UL3E UE3h IEE1 IEE2 Transducer 1 8518 THRESHOLD MV9> Threshold -200 .. 200 % 100 % Threshold of Measured Value MV9>...
  • Page 590 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 9015 RTD 1 STAGE 2 RTD-Box -50 .. 250 °C; ∞ 120 °C RTD 1: Temperature Stage 2 Pickup 9016 RTD 1 STAGE 2 RTD-Box -58 .. 482 °F; ∞ 248 °F RTD 1: Temperature Stage 2 Pickup...
  • Page 591 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 9055 RTD 5 STAGE 2 RTD-Box -50 .. 250 °C; ∞ 120 °C RTD 5: Temperature Stage 2 Pickup 9056 RTD 5 STAGE 2 RTD-Box -58 .. 482 °F; ∞ 248 °F RTD 5: Temperature Stage 2 Pickup...
  • Page 592 Appendix A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 9095 RTD 9 STAGE 2 RTD-Box -50 .. 250 °C; ∞ 120 °C RTD 9: Temperature Stage 2 Pickup 9096 RTD 9 STAGE 2 RTD-Box -58 .. 482 °F; ∞ 248 °F RTD 9: Temperature Stage 2 Pickup...

  • Page 593: 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. New user-defined indications or such newly allocated to IEC 60 870-5-103 are set to ON / OFF and subjected to general interrogation if the information type is not a spontaneous event („.._Ev“).
  • Page 594 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio Control Authority (Cntrl Auth) Cntrl Authority IntSP Controlmode LOCAL (ModeLO- Cntrl Authority IntSP CAL) Reset Minimum and Maximum Min/Max meter IntSP LED BI counter (ResMinMax) Reset meter (Meter res) Energy...
  • Page 595 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio Error Power Supply (Error Pwr- Supervision Supply) Alarm Summary Event (Alarm Supervision Sum Event) Failure: General Current Supervi- Measurem.Superv sion (Fail I Superv.) Failure: General Voltage Supervi- Measurem.Superv sion (Fail U Superv.)
  • Page 596 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio Failure: Phase Sequence I side 2 Measurem.Superv (FailPh.Seq I S2) Failure: RTD-Box 2 (Fail: RTD- Supervision Box 2) Set Point Operating Hours (SP. SetPoint(Stat) Op Hours>) Set Point I<...
  • Page 597 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio Primary fault current IL3 Side2 P.System Data 2 (IL3 S2:) Increment of active energy Energy (WpΔ=) Increment of reactive energy Energy (WqΔ=) 1020 Counter of operating hours Statistics...
  • Page 598 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 1508 >Failure temperature input Therm. Overload LED BI (>Fail.Temp.inp) 1511 Thermal Overload Protection Therm. Overload OFF (Th.Overload OFF) 1512 Thermal Overload Protection Therm.
  • Page 599 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 1897 O/C fault detection Ip phase L2 O/C Prot. Ip on off (O/C Ip Fault L2) 1898 O/C fault detection Ip phase L3 O/C Prot.
  • Page 600 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 4531 External trip 1 is switched OFF External Trips (Ext 1 OFF) 4532 External trip 1 is BLOCKED (Ext External Trips on off 1 BLOCKED) 4533 External trip 1 is ACTIVE (Ext 1...
  • Page 601 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 4824 Restart inhibit motor is switched Restart Motor OFF (Re. Inhibit OFF) 4825 Restart inhibit motor is Restart Motor BLOCKED (Re. Inhibit BLK) 4826 Restart inhibit motor is ACTIVE Restart Motor...
  • Page 602 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 5091 Reverse power prot. is switched Reverse Power OFF (Pr OFF) 5092 Reverse power protection is Reverse Power on off BLOCKED (Pr BLOCKED) 5093 Reverse power protection is Reverse Power...
  • Page 603 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 5165 I2> picked up (I2> picked up) Unbalance Load on off 5173 >BLOCK stator earth fault protec- Stator E Fault LED BI tion (>S/E/F BLOCK) 5176 >Switch off earth current de-...
  • Page 604 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 5293 >BLOCK DC protection DC Protection LED BI (>BLOCK DC Prot.) 5301 DC protection is switched OFF DC Protection (DC Prot. OFF) 5302 DC protection is BLOCKED (DC DC Protection...
  • Page 605 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 5369 Reset memory of thermal replica Overexcitation U/f (RM th.rep. U/f) 5370 Overexc. prot.: U/f> picked up Overexcitation on off (U/f> picked up) 5371 Overexc.
  • Page 606 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 5411 REF (1-3Hz) 2 Measuring circuits REF 1-3Hz open (2 Cir. open) 5413 >BLOCK interturn fault protection Interturn Prot. LED BI (>I/T BLOCK) 5421 Interturn fault prot.
  • Page 607 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 5519 Stage df4/dt picked up (df4/dt df/dt Protect. on off pickup) 5520 Stage df1/dt TRIP (df1/dt TRIP) df/dt Protect. 5521 Stage df2/dt TRIP (df2/dt TRIP) df/dt Protect.
  • Page 608 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 5584 Vector Jump is ACTIVE (VEC Vector Jump JUMP ACTIVE) 5585 Vector Jump not in measurement Vector Jump range (VEC JUMP Range) 5586 Vector Jump picked up (VEC Vector Jump...
  • Page 609 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 5671 Differential protection TRIP (Diff Diff. Prot TRIP) 5672 Differential protection: TRIP L1 Diff. Prot (Diff TRIP L1) 5673 Differential protection: TRIP L2 Diff.
  • Page 610 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 5821 REF protection TRIP (REF TRIP) REF 5833 REF adaptation factor CT starpnt. wind. (REF CTstar:) 5836 REF adverse Adaption factor CT (REF Adap.fact.) 5837 REF adaptation factor CT side 1...
  • Page 611 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 6537 Undervoltage U<< picked up Undervoltage on off (U<< picked up) 6539 Undervoltage U< TRIP (U< TRIP) Undervoltage 6540 Undervoltage U<< TRIP (U<< Undervoltage TRIP) 6565...
  • Page 612 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 7961 Measured Value MV2< picked up Threshold (Meas. Value2<) 7962 Measured Value MV3> picked up Threshold (Meas. Value3>) 7963 Measured Value MV4< picked up Threshold (Meas.
  • Page 613 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 14182 RTD 8 Temperature stage 1 RTD-Box picked up (RTD 8 St.1 p.up) 14183 RTD 8 Temperature stage 2 RTD-Box picked up (RTD 8 St.2 p.up) 14191 Fail: RTD 9 (broken wire/shorted) RTD-Box...
  • Page 614 Appendix A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 30609 Accumulation of interrupted curr. Statistics L3 S1 (ΣIL3 S1:) 30610 Accumulation of interrupted curr. Statistics L1 S2 (ΣIL1 S2:) 30611 Accumulation of interrupted curr. Statistics L2 S2 (ΣIL2 S2:) 30612...

  • Page 615: Group Alarms

    Appendix A.9 Group Alarms Group Alarms Description Function No. Description Error Sum Alarm Error A/D-conv. Error Offset Fail: RTD-Box 1 Fail: RTD-Box 2 Alarm Sum Event Fail I Superv. Fail U Superv. Fail Ph. Seq. Error PwrSupply 6575 VT Fuse Failure Alarm NO calibr Fail Battery Fail I Superv.

  • Page 616: Measured Values

    Appendix A.10 Measured Values A.10 Measured Values Description Function IEC 60870-5-103 Configurable in Matrix IL< under current (IL<) Set Points(MV) Number of TRIPs (#of TRIPs=) Statistics Operating hours greater than (OpHour>) SetPoint(Stat) I1 (positive sequence) (I1 =) Measurement I2 (negative sequence) (I2 =) Measurement U L1-E (UL1E=) Measurement...
  • Page 617 Appendix A.10 Measured Values Description Function IEC 60870-5-103 Configurable in Matrix REF(1-3Hz): Volt. of square-wave gen. Measurement (Ugen =) REF(1-3Hz): Curr. of rotor meas. circuit Measurement (Imeas. =) REF(1-3 Hz): Charge at polarity rev.(Qc) (Qc Measurement SEF100%: Prim. stator earth resistance Measurement (RSEFp=) REF(1-3Hz): Fault Resistance (R earth) (R...
  • Page 618 Appendix A.10 Measured Values Description Function IEC 60870-5-103 Configurable in Matrix Calculated rotor temp. (unbal. load) (Therm- Meas. Thermal Rep.=) Cooling medium temperature (AMB.TEMP =) Meas. Thermal Wp Forward (WpForward) Energy Wq Forward (WqForward) Energy Wp Reverse (WpReverse) Energy Wq Reverse (WqReverse) Energy SEF100%: Phase angle in stator circuit (ϕ...

  • Page 619: Literature

    Literature SIPROTEC 4 System Description; E50417-H1176-C151-A9 SIPROTEC DIGSI, Start Up; E50417-G1176-C152-A3 DIGSI CFC, Manual; E50417-H1176-C098-A9 SIPROTEC SIGRA 4, Manual; E50417-H1176-C070-A4 Planning Machine Protection Systems, E50400-U0089-U412-A1-7600. SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...
  • Page 620 Literature SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 621: 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 622 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 623 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 624 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 625 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 626 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 627 Glossary 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 628 Glossary Object Each element of a project structure is called an object in DIGSI. Object properties Each object has properties. These might be general properties that are common to several objects. An object can also have specific properties. Off-line In offline mode a connection to a SIPROTEC 4 device is not required. You work with data which are stored in files.
  • Page 629 Glossary Project Content-wise, a project is the image of a real power supply system. Graphically, a project is represented as a number of objects which are integrated in a hierarchical structure. Physically, a project consists of a number of directories and files containing project data. Protection devices All devices with a protective function and no control display.
  • Page 630 Glossary with basic and optional packages. SICAM PAS is a purely distributed system: the process interface is imple- mented by the use of bay units / remote terminal units. SICAM Station Unit The SICAM Station Unit with its special hardware (no fan, no rotating parts) and its Windows XP Embedded operating system is the basis for SICAM PAS.
  • Page 631 Glossary 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. This area is called the tree view. TxTap → Transformer Tap Indication User address A user address comprises the name of the user, the national code, the area code and the user-specific phone number.
  • Page 632 Glossary SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

  • Page 633: Index

    Index Directional function of the overcurrent time protection 446 Adaptation of Sampling Frequency 23 Interturn fault protection 441 Add-on stabilization during current transformer saturation Check: Analog Output 406 Check: Circuit Breaker Failure Protection 406 Additional Functions 517 Check: Switching states of binary inputs and outputs 403 Adjustment Factor Uph/Udelta 56 Check: Tripping/Closing for the Configured Operating Alternating Voltage 454...
  • Page 634 Index Forward active power supervision 149 Forward Power Monitoring 29, 484 D-subminiature socket Frequency Change Protection 30 RJ45 socket 391 Frequency Protection 81 O/U 30, 181, 491 Date/Clock Management 346 Frequency-change Protection 494 DC Current Protection 509 Front Elements 24 DC Voltage 454 Front Interface 26 DC Voltage / DC Current Protection 32...
  • Page 635 Index Inverse-time overcurrent protection 75 Nominal values of CTs and VTs 54 Inversion of Phase Sequence 32 Non-interlocked switching 352 IRIG B 346 Operating Hours Counter 331, 521 LEDs 396 Operating Interface 457 Life Status Contact 365 Operating mode 58 Local Measured Values Monitoring 520 Operating Range of the Protection Functions 417, 523 Logic Functions 33...
  • Page 636 Index Startup Overcurrent Protection 28, 98, 475 Statistics 331, 331, 521 Rack mounting 388 Stator earth fault protection 213 Rate-of-frequency-change protection 193 Stator earth fault protection (100 %) with 20 Hz bias Rear Interfaces 26 voltage 31 Reassembly of Device 386 Stator earth fault protection (100 %) with 3rd harmonic 30 Reference Voltages 282 Stator earth fault protection (90 %) 30, 203...
  • Page 637 Index Unabhängiger Überstromzeitschutz 465 Unbalanced load protection 91 Under-excitation Protection 482 Underexcitation Protection 28 Underexcitation protection 136 Undervoltage blocking 138 Undervoltage detection 75 Undervoltage Protection 27 29, 175, 396, 488 Undervoltage seal-in 65, 152 Unit connection 37 Values of the differential protection 340 Vector Jump 30, 199, 495 Vibration and Shock Stress During Stationary Operation 462...
  • Page 638 Index SIPROTEC, 7UM62, Manual C53000-G1176-C149-7, Release date 03.2010...

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