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Siemens Siprotec 7UM62 Manual

Multifunction generator, motor and transformer protection relay
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SIPROTEC
Multifunction Generator,
Motor and Transformer
Protection Relay
7UM62
V4.1
Manual
C53000-G1176-C149-3
Preface
Table of Contents
Introduction
Functions
Installation and Commissioning
Technical Data
Appendix
Index
1
2
3
4
A

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  Summary of Contents for Siemens Siprotec 7UM62

  • Page 1 Preface Table of Contents Introduction Functions SIPROTEC Installation and Commissioning Multifunction Generator, Technical Data Motor and Transformer Protection Relay Appendix 7UM62 Index V4.1 Manual C53000-G1176-C149-3...
  • Page 2 Liability Statement Copyright We have checked the text of this manual against the Copyright © Siemens AG 2002. All rights reserved. hardware and software described. Exclusions and de- Dissemination or reproduction of this document, or evalu- viations cannot be ruled out; we accept no liability for ation and communication of its contents, is not authorized lack of total agreement.
  • Page 3 (EMC Council Directive 89/336/EEC) and concerning electrical equipment for use within certain voltage limits (Low-voltage Directive 73/23/EEC). This conformity is proved by tests conducted by Siemens AG in accordance with Article 10 of the Council Directive in agreement with the generic standards EN 50081 and EN 50082 for EMC directive, and with the standard EN 60255–6 for the low-...
  • Page 4 4 devices, please contact your Siemens representative. Training Courses Individual course offerings may be found in our Training Catalog, or questions can be directed to our training center. Please contact your Siemens representative. Instructions and The following indicators and standard definitions are used: Warnings...
  • Page 5 Preface Typographic and The following text formats are used to identify concepts giving device information Graphical described by the text flow: Conventions Parameter names, or identifiers for configuration or function parameters that appear ® in the device display or on the screen of a PC (with DIGSI 4) are shown in mono- script (same point size) bold text.
  • Page 6 Preface Exclusive–OR gate: output is active, if only one of the inputs is active Coincidence gate: output is active, if both inputs are active simultaneously Input signals of dynamic quantity Formation of one output signal from a number of analog inputs 1706 I2>>...
  • Page 7: Table Of Contents

    Table of Contents Introduction............................1 Overall Operation ........................2 Applications ..........................5 Features ..........................7 Functions............................13 Introduction, Reference Power System ................16 Functional Scope........................18 2.2.1 Description ........................... 18 2.2.2 Setting Hints ......................... 18 2.2.2.1 Settings ..........................23 Power System Data 1......................27 2.3.1 Functional Description ......................
  • Page 8 Table of Contents 2.7.2 Setting Hints ......................... 44 2.7.2.1 Settings for the I>> Stage of the Definite-Time Overcurrent Protection ....... 47 2.7.2.2 Information for the I>> stage of the Definite-Time Overcurrent Protection ......47 Inverse-Time Overcurrent Protection (ANSI 51V) ..............48 2.8.1 Functional Description ......................
  • Page 9 Table of Contents 2.15.2.1 Settings of the Reverse Power Protection................117 2.15.2.2 Information for the Reverse Power Protection..............118 2.16 Forward Active Power Supervision (ANSI 32F)..............119 2.16.1 Functional Description ......................119 2.16.2 Setting Hints ........................120 2.16.2.1 Settings of the Forward Active Power Supervision............. 120 2.16.2.2 Information for the Forward Power Supervision ..............
  • Page 10 Table of Contents 2.23.1 Functional Description ......................164 2.23.2 Setting Hints ........................165 2.23.2.1 Settings of the Inverse Undervoltage Protection ..............166 2.23.2.2 Information for the Inverse Undervoltage Protection ............166 2.24 Rate-of-Frequency-Change Protection df/dt (ANSI 81R) ........... 167 2.24.1 Functional Description ......................
  • Page 11 Table of Contents 2.31.2.2 Information for the Sensitive Earth Fault Protection ............212 2.32 Motor Starting Time Supervision (ANSI 48) ............... 213 2.32.1 Functional Description ......................213 2.32.2 Setting Hints ........................215 2.32.2.1 Settings of the Motor Starting Time Supervision ..............216 2.32.2.2 Information for the Motor Starting Time Supervision ............
  • Page 12 Table of Contents 2.39.2.2 Information.......................... 260 2.40 Threshold Supervision ......................261 2.40.1 Functional Description ......................261 2.40.2 Setting Hints ........................263 2.40.2.1 Settings of the Threshold Supervision ................264 2.40.2.2 Information for the Threshold Supervision................266 2.41 External Trip Coupling ......................267 2.41.1 Functional Description ......................
  • Page 13 Table of Contents 2.45.6 Setting Hints ........................295 2.45.6.1 Settings for Oscillographic Fault Recording ............... 296 2.45.6.2 Information for the Oscillographic Fault Recording ............296 2.45.6.3 Information for Minimum and Maximum Values ..............297 2.46 Breaker Control ........................298 2.46.1 Types of Commands ......................
  • Page 14 Table of Contents 3.4.6 Checking the Stator Earth Fault Protection ................ 374 3.4.6.1 Unit Connection ........................375 3.4.6.2 Busbar Connection ......................378 3.4.7 Testing the 100–% Stator Earth Fault Protection ............... 382 3.4.8 Checking the Sensitive Earth Fault Protection when Used for Rotor Earth Fault Protection ..................
  • Page 15 Table of Contents 4.13 Impedance Protection (ANSI 21)..................426 4.14 Out-of-Step Protection (ANSI 78) ..................427 4.15 Undervoltage Protection (ANSI 27) ..................428 4.16 Overvoltage Protection (ANSI 59) ..................430 4.17 Frequency Protection (ANSI 81)..................431 4.18 Overexcitation (Volt/Hertz) Protection (ANSI 24) .............. 432 4.19 Rate-of-Frequency-Change Protection (ANSI 81R) ............
  • Page 16 Table of Contents Connection Examples......................488 A.4.1 Connection Examples for RTD-Box..................498 100–% Stator Earth Fault Protection with Primary Load Resistor ........499 A.5.1 Protection Settings......................500 A.5.2 Commissioning ........................500 Definition of the Active Power Measurement..............502 Current Transformer Requirements..................504 Overview of the Masking Features of the User Defined Information ........
  • Page 17: Introduction

    Introduction ® The SIPROTEC 4 7UM62 devices are introduced in this section. An overview of the devices is presented in their application, characteristics, and scope of functions. Overall Operation Applications Features 7UM62 Manual C53000-G1176-C149-3...
  • Page 18: Overall Operation

    1 Introduction Overall Operation ® The SIPROTEC 4 7UM62 is a numerical, multi-functional, protective and control device equipped with a powerful microprocessor. All tasks, such as the acquisition of the measured quantities, issuing of commands to circuit breakers and other primary power system equipment, are processed in a completely digital way.
  • Page 19: C53000-G1176-C149

    1.1 Overall Operation equipped with sensitive input transformers (I ) and can measure secondary currents in the mA range. A voltage measuring input is provided for each phase-earth voltage (connection to phase-to-phase voltages and voltage transformers in V connection is possible as well).
  • Page 20 1 Introduction Integrated control and numeric keys in conjunction with the LCD facilitate local interaction with the 7UM62. All information of the device can be accessed using the integrated control and numeric keys. The information includes protective and control ® settings, operating and fault messages, and metering values (see also SIPROTEC 4–System Manual).
  • Page 21: Applications

    1.2 Applications Applications ® SIPROTEC 7UM62 is a numerical machine protection unit from the “7UM6 Numerical Protection series”. It provides all functions that are necessary for the protection of generators, motors and transformers. As the scope of functions of the 7UM62 can be customized, it is suited for small, medium-sized and large generators.
  • Page 22 1 Introduction Messages and A series of operating messages provides information about conditions in the power Measured Values; system and the 7UM62 itself. Measurement quantities and values that are calculated Storage of Data for can be displayed locally and communicated via the serial interfaces. Fault Recordings Messages of the 7UM62 can be indicated by a number of programmable LEDs on the front panel, externally processed through programmable output contacts, and...
  • Page 23: Features

    1.3 Features Features • Powerful 32-bit microprocessor system. General Features • Complete digital processing of measured values and control, from the sampling of the analog input quantities to the initiation of outputs for, as an example, tripping circuit breakers or other switch-gear devices. •...
  • Page 24 1 Introduction • Evaluation of negative sequence component of the three phase currents; Unbalanced Load Protection • Alarm stage when a set unbalanced load is exceeded; • Thermal replica for rotor temperature rise with adjustable negative sequence factor K and adjustable time for cool down; •...
  • Page 25 1.3 Features • Phase selective overcurrent fault detection with undervoltage seal-in (for Impedance Protection synchronous machines which take their excitation voltage from the terminal voltage); • 2 impedance zones, 1 overreach zone for zone extension (controlled via binary input), 4 time stages; •...
  • Page 26 1 Introduction • Measurement of displacement voltage at the machine via the neutral transformers or earthing transformer or by calculation from phase-to-earth voltages; • Highly sensitive earth current detection, optional with or without directional determination with zero sequence components (I •...
  • Page 27 1.3 Features • Different prolongation of cool-down time constants for rest/operation period is taken into consideration; • Disabling of the start inhibit is possible if an emergency start-up is required. • Breaker failure condition determined by current flow after a trip signal has been Breaker Failure Protection issued, or the breaker position indication (binary input) can be evaluated;...
  • Page 28 1 Introduction • Circuit breakers can be opened and closed via the programmable function keys on Breaker Control the front panel, through the SCADA, or through the front operator interface using a ® personal computer with DIGSI • Circuit breakers are monitored via the breaker auxiliary contacts; •...
  • Page 29: Functions

    Functions ® This chapter describes the numerous functions available on the SIPROTEC 7UM62 relay. The setting options for each function are explained, including instructions to determine setting values and formulae where required. Introduction, Reference Power System Functional Scope Power System Data 1 Setting Groups Power System Data 2 Definite-Time Overcurrent Protection (I>, ANSI 50/51) with Undervoltage...
  • Page 30 Functions 2.26 90–%–Stator Earth Fault Protection (ANSI 59N, 64G, 67G) 2.27 Sensitive Earth Fault Protection (ANSI 51GN, 64R) 2.28 100–%–Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) 2.29 100–% Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G - 100%) 2.30 Rotor Earth Fault Protection R, fn (ANSI 64R)
  • Page 31 ® Regionalization The SIPROTEC 7UM62 protective relays are offered in regional versions. The user should purchase only the functional scope that is needed. The prepared functions are adapted to the technical requirements of the regions. Table 2-1 Regionalization Function Region DE Region Worldwide Region US Germany...
  • Page 32: Introduction, Reference Power System

    Functions Introduction, Reference Power System The following chapters explain the individual protective and additional functions and provide information about on the setting values. Generator The calculation examples are based on two reference power systems with the two typical basic connections, i.e. the busbar connection and the unit connection (see Figure 2-1).
  • Page 33 Introduction, Reference Power System Technical Data of Generator: = 5.27 MVA N, G the Reference = 6.3 kV N, G Power Systems = 483 A N, G cos ϕ = 0.8 Current transformer: = 500 A; = 1 A N,prim N, sec Toroidal current transformer I = 60 A;...
  • Page 34: Functional Scope

    Functions Functional Scope 2.2.1 Description General The 7UM62 has numerous protective and additional functions. The hardware and firmware 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 U and I respectively.
  • Page 35 Functional Scope Parameter 0104 FAULT VALUE is used to specify whether the oscillographic fault recording should record Instantaneous values or RMS values. If RMS values are recorded, the available recording time increases by the factor 16. For some protective functions you can also choose the measuring inputs of the relay to which they will be allocated (side 1 or side 2);...
  • Page 36 Functions Table 2-2 Allocation of Device Inputs to Protection Functions Side 1 Side 2 Protection Function ANSI L1S1 L2S1 L1S2 L2S2 L3S1 L3S2 Impedance Protection ANSI 21 Fixed Fixed Out-of-Step Protection ANSI 78 Fixed Fixed Undervoltage Protection ANSI 27 Fixed Overvoltage Protection ANSI 59 Fixed...
  • Page 37 Functional Scope For the differential protection, address 0120 DIFF. PROT. allows to specify the type of protected object (Generator/Motor or 3-phase Transformer); the function can be excluded altogether by setting Disabled. Side 2 Side 1 3∼ Address 0120 DIFF. PROT. = Generator/Motor 7UM62 Figure 2-2...
  • Page 38 Functions For the following application, the differential protection of device A must be set to Generator/Motor, and that of device B to 3-phase Transformer. Also, the settings of the generator data under Power System Data 1 must be same as for the transformer data of side: (A) Side 2 (A) Side 1...
  • Page 39: Settings

    Functional Scope 2.2.2.1 Settings Addr. Setting Title Setting Options Default Setting Comments Grp Chge OPTION Disabled Disabled Setting Group Change Option Enabled FAULT VALUE Disabled Instantaneous Fault values Instantaneous values values RMS values DIFF. PROT. Disabled Enabled Differential Protection Enabled PROT.
  • Page 40 Functions Addr. Setting Title Setting Options Default Setting Comments IMPEDANCE Disabled Enabled Impedance Protection PROT. Enabled OUT-OF-STEP Disabled Enabled Out-of-Step Protection Enabled UNDERVOLTAGE Disabled Enabled Undervoltage Protection Enabled OVERVOLTAGE Disabled Enabled Overvoltage Protection Enabled FREQUENCY Prot. Disabled Enabled Over / Underfrequency Protec- Enabled tion OVEREXC.
  • Page 41 Functional Scope Addr. Setting Title Setting Options Default Setting Comments ANALOGOUTPUT Disabled Disabled Analog Output B1 (Port B) Positive Sequence Current I1 [%] Negative Sequence Current I2 [%] Positive Sequence Voltage U1 [%] Active Power |P| [%] Reactive Power |Q| [%] Frequency f [%] |Power Factor| [%] p.u.
  • Page 42 Functions Addr. Setting Title Setting Options Default Setting Comments ANALOGOUTPUT Disabled Disabled Analog Output D2 (Port D) Positive Sequence Current I1 [%] Negative Sequence Current I2 [%] Positive Sequence Voltage U1 [%] Active Power |P| [%] Reactive Power |Q| [%] Frequency f [%] |Power Factor| [%] p.u.
  • Page 43: Power System Data 1

    Power System Data 1 Power System Data 1 2.3.1 Functional Description General The device requires certain basic data regarding the protected equipment, so that the device will be compatible with its desired application. These may be, for instance, rated power system and transformer data, measured quantity polarities and their physical connections, breaker properties etc.
  • Page 44 Functions Figure 2-7 shows an example. Although the starpoints of both CT sets are turned to- wards the protected object, “side 2” is set to the opposite: 210 STRPNT->OBJ S2 = “Side 2“ “Side 1“ 0210 STRPNT–>OBJ S2 0201 STRPNT–>OBJ S1 = YES = NO Figure 2-7 Current Transformer Starpoints in Transverse Differential Protection - Example...
  • Page 45 Power System Data 1 At addresses 0221 Unom PRIMARY and 0222 Unom SECONDARY, information is Nominal Values of Voltage entered regarding the primary nominal voltage and secondary nominal voltages Transformers (phase-to-phase) of the connected voltage transformers. At address 0223 UE CONNECTION the user specifies to the device which type of volt- Voltage Connection age is connected to the U input.
  • Page 46 Functions The address 0225A serves to communicate the adaptation factor between the phase Uph/Uen Adaption Factor voltage and the displacement voltage to the device. This information is relevant for measured-quantity monitoring. If the voltage transformer set has broken delta windings and if these windings are input), this must be specified accordingly in address 0223 connected to the device (V (see below at side title ”Voltage Connection U...
  • Page 47 Power System Data 1 Setting parameters: 0249 SN TRANSFORMER N,Transf 0241 UN-PRI SIDE 1 N, S1 0252 SN GEN/MOTOR N, Generator 0251 UN GEN/MOTOR N, Generator These normalizing factors apply for transformer protection and overall protection (see Figures 2-3 and 2-4). Protected Object: Regardless of the configuration and intended use of the differential protection, the generator/motor ratings must be specified.
  • Page 48 Functions Parameter 0274A ATEX100 allows compliance with PTB requirements (special ATEX100 requirements for Germany) for thermal replicas. If this parameter is set to YES, all thermal replicas of the 7UM62 are stored in case of a power supply failure. As soon as the supply voltage returns, the thermal replicas continue operating with the stored values.
  • Page 49: Settings 1

    Power System Data 1 2.3.2.1 Settings 1 Addr. Setting Title Setting Options Default Setting Comments Rated Frequency 50 Hz 50 Hz Rated Frequency 60 Hz PHASE SEQ. L1 L2 L3 L1 L2 L3 Phase Sequence L1 L3 L2 SCHEME Direct connected to busbar Direct connected Scheme Configuration Unit transformer connected...
  • Page 50: List Of Information

    Functions Addr. Setting Title Setting Options Default Setting Comments Unom PRIMARY 0.10..400.00 kV 6.30 kV Rated Primary Voltage Unom SECON- 100..125 V 100 V Rated Secondary Voltage (Ph- DARY UE CONNECTION UE connected to neutral UE connected to UE Connection transformer neutral transformer UE connected to broken...
  • Page 51: Setting Groups

    Setting Groups Setting Groups 2.4.1 Functional Description Purpose of Setting Two independent groups of parameters can be set for the device functions. The user Groups can switch back and forward between setting groups locally, via binary inputs (if so configured), via the operator or service interface using a personal computer, or via the system interface.
  • Page 52: Power System Data 2

    Functions Power System Data 2 2.5.1 Functional Description General protective data (P.SYSTEM DATA2) includes settings associated with all functions rather than a specific protective or monitoring function. In contrast to the P.SYSTEM DATA1 as discussed in Sub-section 2.3, these settings can be changed over with the setting groups.
  • Page 53 Power System Data 2 F.No. Alarm Comments 05017 f: Frequency at trip 7UM62 Manual C53000-G1176-C149-3...
  • Page 54: Definite-Time Overcurrent Protection (I>, Ansi 50/51) With Undervoltage Seal-In38

    Functions Definite-Time Overcurrent Protection (I>, ANSI 50/51) with Undervoltage Seal-In General The overcurrent protection is used as backup protection for the short-circuit protection of the protected object. It also provides backup protection for downstream network faults which are not promptly disconnected and thus may endanger the protected object.
  • Page 55: Setting Hints

    Definite-Time Overcurrent Protection (I>, ANSI 50/51) with Undervoltage Seal-In Figure 2-10 shows the logic diagram of the overcurrent time protection I> with undervoltage seal-in. FNo. 01722 FNo. 01966 I> BLOCKED >BLOCK I> FNo. 01970 U< seal in Tripping FNo. 01811 matrix &...
  • Page 56: Settings For The Definite-Time Overcurrent Protection (Stage I>)

    Functions The 1205 U< undervoltage stage (positive-sequence voltage) is set to a value below Undervoltage Seal–In the lowest phase-to-phase voltage permissible 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> time delay. The dropout ratio r = I of the overcurrent pickup I>...
  • Page 57: Information From Definite-Time Overcurrent Protection (Stage I>)

    Definite-Time Overcurrent Protection (I>, ANSI 50/51) with Undervoltage Seal-In 2.6.2.2 Information from Definite-Time Overcurrent Protection (Stage I>) F.No. Alarm Comments 01722 >BLOCK I> >BLOCK I> 01950 >Useal-in BLK >O/C prot. : BLOCK undervoltage seal-in 01965 I> OFF O/C prot. stage I> is switched OFF 01966 I>...
  • Page 58: Definite-Time Overcurrent Protection (I>>, Ansi 50, 51, 67) With Direction Detection

    Functions Definite-Time Overcurrent Protection (I>>, ANSI 50, 51, 67) with Direction Detection The overcurrent protection is used as backup protection for the short-circuit protection of the protected object. It also provides backup protection for downstream network faults which are not promptly disconnected and thus may endanger the protected object.
  • Page 59 Definite-Time Overcurrent Protection (I>>, ANSI 50, 51, 67) with Direction Detection typically used as the cross-polarized voltage (Figure 2-12). This is considered during the calculation of the directional vector in the clockwise rotating phase sequence by way of a rotation by +90° and in the anti-clockwise and in the anti-clockwise rotating phase by way of a rotation by –90°.
  • Page 60: Setting Hints

    Functions period (2 cycles), the detected direction is stored, as long as no sufficient measuring voltage is available. If a short circuit already exists at generator startup (or, in case of motors or transformers, during connection), so that no voltage is present in the memory and no direction can be determined, a trip is issued.
  • Page 61 Definite-Time Overcurrent Protection (I>>, ANSI 50, 51, 67) with Direction Detection Address 1301 O/C I>> is used to switch the definite time I>> stage for phase I>>Time- currents ON or OFF, or to block only the trip command (Block Relay). The high- Overcurrent Stage current stage I>>...
  • Page 62 Functions Line ϕ LINE ANGLE Direction straight line 1304 Phase Direction 1305 LINE Figure 2-14 Definition of the Parameters ANGLE The setting value of the direction straight line results from the short-circuit angle of the feeding network. As a rule, it will be > 60°. The current pick-up value results from the short-circuit current calculation.
  • Page 63: Settings For The I>> Stage Of The Definite-Time Overcurrent Protection

    Definite-Time Overcurrent Protection (I>>, ANSI 50, 51, 67) with Direction Detection 2.7.2.1 Settings for the I>> Stage of the Definite-Time Overcurrent Protection The following list indicates the setting ranges and the default settings of a I = 1 A secondary nominal current. For a secondary nominal current of I = 5 A, these values must be multiplied by 5.
  • Page 64: Inverse-Time Overcurrent Protection (Ansi 51V)

    Functions Inverse-Time Overcurrent Protection (ANSI 51V) 2.8.1 Functional Description General The overcurrent time protection represents the short-circuit protection for small or low- voltage machines. For larger machines it is used as back-up protection for the machine short-circuit protection (differential protection and/or impedance protection). It provides back-up protection for network faults which are not promptly disconnected and thus may endanger the machine.
  • Page 65 Inverse-Time Overcurrent Protection (ANSI 51V) Factor ⋅ ≤ ≤ ∞ ------------- 1.00 for 1.00 pickup 0.75 ⋅ ≤ ≤ ------------- - for 0.25 ------------- 1.00 pickup 0.25 ⋅ ≤ ≤ ------------- 0.25 for 0.00 0.25 pickup 0.25 0.75 ⁄ – Generator nominal voltage = parameter 0251 UN GEN/MOTOR where I(U) –...
  • Page 66 Functions FNo. 01899 O/C Ip pick.up FNo. 01896 O/C Ip Fault L1 1403 T Ip Pickup IL1 & FNo. 01900 FNo. 01897 Tripping matrix O/C Ip TRIP O/C Ip Fault L2 1403 T Ip (Pickup) & TMin FNo. 01898 TRIP CMD O/C Ip Fault L3 1403 T Ip (Pickup)
  • Page 67 Inverse-Time Overcurrent Protection (ANSI 51V) FNo. 01899 O/C Ip pick.up FNo. 01896 O/C Ip Fault L1 1402 Ip 1403 T Ip & FNo. 01897 FNo. 01900 Tripping O/C Ip Fault L2 1402 Ip O/C Ip TRIP matrix 1403 T Ip &...
  • Page 68: Setting Hints

    Functions FNo. 01899 O/C Ip pick.up FNo. 01896 O/C Ip Fault L1 1402 Ip 1403 T Ip & FNo. 01897 FNo. 01900 Tripping O/C Ip Fault L2 1402 Ip matrix O/C Ip TRIP 1403 T Ip & TMin FNo. 01898 TRIP CMD O/C Ip Fault L3 1402 Ip...
  • Page 69: Settings Of The Inverse O/C Time Protection

    Inverse-Time Overcurrent Protection (ANSI 51V) times of the setting value is present. The function will reset as soon as the value falls below 95 % of the pick-up value. The current is set at address1402 Ip. The maximum operating current is of primary importance for the setting.
  • Page 70: Information For The Inverse-Time Overcurrent Protection

    Functions Addr. Setting Title Setting Options Default Setting Comments 1406 ANSI CURVE Very Inverse Very Inverse ANSI Curve Inverse Moderately Inverse Extremely Inverse Definite Inverse 1407 VOLT. INFLUENCE without without Voltage Influence Voltage controlled Voltage restraint 1408 U< 10.0..125.0 V 75.0 V U<...
  • Page 71: Thermal Overload Protection (Ansi 49)

    Thermal Overload Protection (ANSI 49) Thermal Overload Protection (ANSI 49) 2.9.1 Functional Description General The thermal overload protection feature of the 7UM61 is designed to prevent overloads from damaging the protected equipment. The device is capable of projecting excessive operating temperatures for the protected equipment in accordance with a thermal model, based on the following differential equation: dΘ...
  • Page 72 Functions Coolant The thermal model of the 7UM62 considers an external temperature value. Depending Temperature/ on the application, this temperature can be the coolant or ambient temperature or, in Ambient the case of gas turbines, the entry temperature of the cold gas. The temperature to be Temperature considered can be fed in by one of the following: −...
  • Page 73 Thermal Overload Protection (ANSI 49) the tripping signal via a binary input (”>Emer.Start O/L”). Since the calculated operating temperature may be higher than the maximum allowable operating temperature after drop out of the binary input has taken place, the thermal overload protection function features a programmable run-on time interval run-on time interval (T EMERGENCY) which is started when the binary input drops out.
  • Page 74 Functions CB closed BkrClosed I MIN 0281 I> 1615A I MAX THERM. 1612A Kt-FACTOR Θ τ kτ 1610A 1602 I ALARM K-FACTOR FNo. 01515 1603 TIME CONSTANT & O/L I Alarm 1604 Q ALARM FNo. 01516 dΘ -- - Θ ⋅...
  • Page 75: Setting Hints

    Thermal Overload Protection (ANSI 49) 2.9.2 Setting Hints Thermal overload protection is only effective and accessible if address 0116 General Therm.Overload was set to Enabled. Set Disabled if the function is not required. Transformers and generators are prone to damage by overloads which last for an extended period of time.
  • Page 76 Functions Time Constant τ The thermal overload protection element tracks excessive temperature progression, employing a thermal differential equation that uses an exponential function. The TIME CONSTANT τ (address 1603) is used in the calculation to determine the operating temperature. If the overload characteristic of the generator to be protected is pre-determined, the user must select the protection trip characteristic in a way that it covers the overload characteristic to a large extent, at least with small overloads.
  • Page 77 Thermal Overload Protection (ANSI 49) despite increasing current values. The limit value must be specified at a value ensuring that, even for the highest possible short-circuit current, the trip times of the overload protection exceed the trip times of the short-circuit protective relays (differential protection, impedance protection, time overcurrent protection).
  • Page 78 Functions If the temperature input is used, the trip times change if the coolant temperature deviates from the internal reference temperature of 40 °C. The following formula can be used to calculate the trip time: Θ – 40 °C æ ö...
  • Page 79: Thermal Overload Protection Settings

    Thermal Overload Protection (ANSI 49) The following trip times result for different ambient temperatures Θ with a supposed load current of I = 1.5 ⋅ I and a preload I N, device æ ö æ ö 40 °C 40 °C –...
  • Page 80: Information List For The Thermal Overload Protection

    Functions Addr. Setting Title Setting Options Default Setting Comments 1607 TEMP. INPUT Disabled Disabled Temperature Input 4-20 mA Fieldbus Temp. of RTD 1 40..300 °C 100 °C 1608 TEMP. SCAL. Temperature for Scaling 104..572 °F 212 °F 1609 TEMP. SCAL. Temperature for Scaling 2.9.2.2 Information List for the Thermal Overload Protection...
  • Page 81: Unbalanced Load (Negative Sequence) Protection (Ansi 46)

    Unbalanced Load (Negative Sequence) Protection (ANSI 46) 2.10 Unbalanced Load (Negative Sequence) Protection (ANSI 46) General Unbalanced load protection detects unbalanced loads. The negative sequence currents associated with unbalanced loads create reverse fields in three-phase induction machines, which act on the rotor at double frequency. Eddy currents are induced at the rotor surface, and local overheating of the rotor end zones and the slot wedges begins to take place.
  • Page 82 Functions Definite-Time High negative phase-sequence currents can only be caused by a two-pole power Trip Stage system short circuit which must be covered in accordance with the network grading plan. For this reason, the thermal characteristic is cut by a selectable, definite-time, negative phase-sequence current stage (address 1706 I2>>...
  • Page 83: Setting Hints

    Unbalanced Load (Negative Sequence) Protection (ANSI 46) Logic Figure 2-22 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 model are cleared. The binary input ”>RM th.rep.
  • Page 84 Functions Conversion to The factor K can be derived from the unbalanced load characteristic according to Figure 2-23 by reading the time corresponding to the FACTOR K at the point I Secondary Values = 1. Example: = 20 s for I perm The constant K = 20 s determined in this way is valid for the machine side...
  • Page 85: Settings Of The Unbalanced Load Protection

    Unbalanced Load (Negative Sequence) Protection (ANSI 46) The parameter 1705 T COOL DOWN is defined as the time required by the thermal Time for Cool Down image to cool down from 100 % to 0 %. If the machine manufacturer does not provide this information, the setting value can be calculated by assuming an equal value for the cool-down time and the heating time of the object to be protected.
  • Page 86: Information For The Unbalanced Load Protection

    Functions Addr. Setting Title Setting Options Default Setting Comments 0.00..60.00 sec; ∞ 1703 T WARN 20.00 sec Warning Stage Time Delay 2.0..100.0 sec; ∞ 1704 FACTOR K 18.7 sec Negativ Sequence Factor K 1705 T COOL DOWN 0..50000 sec 1650 sec Time for Cooling Down 1706 I2>>...
  • Page 87: Startup Overcurrent Protection (Ansi 51)

    Startup Overcurrent Protection (ANSI 51) 2.11 Startup Overcurrent Protection (ANSI 51) General Gas turbines can be started by means of a frequency starting converter. A switched- mode converter feeds a current into the generator and creates a rotating field whose frequency gradually increases.
  • Page 88: Functional Description

    Functions The function is also active above 70 Hz because at that frequency the protection is again in operational condition 0. 2.11.1 Functional Description Measuring At frequencies below 10 Hz, the protection works in operating condition 0, with the Principle sampling frequency automatically set to nominal conditions (f = 800 Hz for 50 Hz net- works and 960 Hz for 60 Hz networks).
  • Page 89 Startup Overcurrent Protection (ANSI 51) f/fn Figure 2-26 Short-Circuit Currents in the Generator during the Startup (Generator: 300 MVA, 15.75 kV, 50 Hz) Delay Times Since the generator circuit breaker is open during startup, there is no need to coordi- nate the delay time with the network.
  • Page 90: Settings Of The Startup Overcurrent Protection

    Functions f/fn Idiff I>> O/C START Figure 2-27 Operating Range and Possible Pickup Threshold of Short-Circuit Protection Functions 2.11.2.1 Settings of the Startup Overcurrent Protection Addr. Setting Title Setting Options Default Setting Comments 1801 O/C STARTUP Startup O/C protection Block relay for trip com- mands 1802 STARTUP I>...
  • Page 91: Differential Protection (Ansi 87G/87M/87T)

    Differential Protection (ANSI 87G/87M/87T) 2.12 Differential Protection (ANSI 87G/87M/87T) General The numerical current differential protection of the 7UM62 is a fast and selective short- circuit protection for generators, motors and transformers. The individual application can be configured, which ensures optimum matching to the protected object. The protected zone is selectively limited by the CTs at its ends.
  • Page 92 Functions The stabilizing quantity is derived from the arithmetical sum of the absolute values of | + |I |. The following definitions apply: The differential current = |I diff and the stabilization or restraining current = |I | + |I stab is derived from the fundamental frequency current and produces the tripping effect diff...
  • Page 93: Protected Object Generator Or Motor: Particularities

    Differential Protection (ANSI 87G/87M/87T) This result shows that for internal fault and under ideal conditions I diff stab Consequently, the characteristic of internal faults is a straight line with a upward slope of 45° (dot-and-dash line in Figure 2-30). The currents I and I are compared by the differential protection with the diff...
  • Page 94: Protected Object Transformer: Particularities

    Functions Due to their predominantly inductive component, faults in the proximity of the generator have relatively high short-circuit time constants that cause a magnetization of the current transformers. The CTs should be designed accordingly (see Appendix A.7). Figure 2-31 Definition of Current Direction for Longitudinal Differential Protection For use as a transverse differential protection, there is a particularity.
  • Page 95 Differential Protection (ANSI 87G/87M/87T) Mismatching of 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. Voltage Control by Voltage control tap changers (usually in-phase regulators) change the transformation Tap Changers ratio and the rated current of the transformer.
  • Page 96 Functions The higher voltage side has a wye connection and the lower voltage side a delta connection. The phase rotation is n ⋅ 30° (i.e. 5 ⋅ 30° = 150°). Side 1 (higher voltage side) is the reference system. The vector group correction feature transforms the currents flowing from side 2 to side 1.
  • Page 97: Evaluation Of Measured Quantities

    Differential Protection (ANSI 87G/87M/87T) Side 1 Side 2 √3 ⋅ I – – – ⋅ ⋅ ⋅ ⋅ -- - ------ - – – – – – – Figure 2-34 Vector Group Matching for Y(N) d5 (with Earthed Starpoint) In Figure 2-35 on the left-hand side, a zero sequence current will occur in case of e.g. an external fault;...
  • Page 98 Functions The stabilizing quantity is calculated from the arithmetic average of a rectified quantity, so that the filter effect is less for it. As a result, the stabilization component in interference components, especially aperiodic DC components, will be higher than their differential current.
  • Page 99 Differential Protection (ANSI 87G/87M/87T) High-Speed Trip The high-speed trip stage I >> clears high-current internal faults instantaneously. Diff Stage I >> As soon as the differential current rises above the threshold I >> (branch d), a trip Diff Diff signal is issued regardless of the magnitude of the stabilizing current. This stage can operate even when, for example, a considerable second harmonic is present in the differential current, which is caused by current transformer saturation by a DC component in the short-circuit current, and which could be interpreted by the...
  • Page 100 Functions Immediately after the fault (A), the short-circuit currents rise strongly, causing a equally high stabilizing current (2xthrough-flowing current). Saturation occurring on one side (B) now causes a differential current and reduces the stabilizing current, so that the operating point I may move into the tripping area (C).
  • Page 101 Differential Protection (ANSI 87G/87M/87T) Unwanted differential currents may also be cause by parallel connection of transformers or by transformer overexcitation due to excessive voltage. The inrush current can amount to a multiple of the rated current and is characterized by a considerable 2nd harmonic content (double rated frequency) which is practically absent in the case of a short-circuit.
  • Page 102 Functions condition lasts, i.e. cross-blocking is possible only once after a fault has occurred, and only for the set cross-block time. The further harmonic stabilizations operate individually per phase. However, it is also possible – as it is for the inrush stabilization – to set the protection such that not only the phase with harmonics content in excess to the permissible value is stabilized but also the other phases of the differential stage I-DIFF>...
  • Page 103 Differential Protection (ANSI 87G/87M/87T) diff --------------- - NObj Pickup Steady-state characteristic I–DIFF> Beginning of 0.85 · I–DIFF> add-on stabilization EXF–STAB 0.85 stab --------------- - NObj Figure 2-41 Pickup of the Differential Protection If stabilization by higher-order harmonics is activated, the system first performs a harmonics analysis (for about 1 period) to check the stabilization conditions, if required.
  • Page 104 Functions FNo 05631 Diff picked up & Characteristic Diff> L1 Diff> L2 2026A T I-DIFF> Diff> L3 Inrush stabilization FNo 05691 (2nd harm.)*) Diff> TRIP Diff TRIP Diff TRIP Harmonic stabilization Diff TRIP (3rd or 5th)*) Tripping matrix Add-on TMin stabilization TRIP CMD (ext.
  • Page 105: Setting Hints

    Differential Protection (ANSI 87G/87M/87T) 2.12.2 Setting Hints General The differential protection is only effective and accessible if the type of protected object for this function was set within the framework of the protective function configuration (Section 2.2, address 0120, DIFF. PROT. = Generator/Motor or Three-phase trans.).
  • Page 106 Functions The parameters for the tripping characteristic are set at the addresses 2021 through Tripping 2044A. The meaning of the parameters is shown in Figure 2-43. The numerical values Characteristic at the branches are the parameter addresses. Address 2021 I-DIFF> is the pickup value for the differential current. The pickup value is referred to the nominal current of the generator or motor.
  • Page 107: Differential Protection For Transformers

    Differential Protection (ANSI 87G/87M/87T) Add-on Where very high currents flow through the protected object during external short- circuits, an add-on stabilization takes effect that is set at address 2056A I-ADD ON Stabilization During STAB. (stabilization in case of saturation). Please note that the stabilizing current is Current Trans- former Saturation the arithmetical sum of the currents entering and leaving the protected zone, i.e.
  • Page 108 Functions − Rated current of the current transformer set in A (see above). Winding 1 is defined as the reference winding and therefore needs no numeral; the other windings are referred to winding 1. The reference winding is normally that of the higher voltage. If not the higher voltage side is used as reference winding, it must be considered that the vector group changes: e.g.
  • Page 109 Differential Protection (ANSI 87G/87M/87T) Cross-Blocking The inrush restraint can be extended by the so-called ”cross-block” function. This means that not only the phase with inrush current exhibiting harmonics content in excess of the permissible value is stabilized but also the other phases of the differential stage IDIFF>...
  • Page 110 Functions the parameter 2042A BASE POINT 1. This branch considers current-proportional error currents. These are mainly transformation errors of the main CTs and, especially, the differential currents which may occur in the final tap changer positions due to the transformer regulation range. This branch of the characteristic limits the stabilization area.
  • Page 111: Settings Of The Differential Protection

    Differential Protection (ANSI 87G/87M/87T) for each differential protection level and each phase. The dropout delay is linked to the minimum trip command duration that is valid for all protection functions. All setting times are additional time delays which do not include the operating times (measuring time, drop-out time) of the protective function.
  • Page 112: Information For The Differential Protection

    Functions Addr. Setting Title Setting Options Default Setting Comments 2073A IDIFFmax n.HM 0.5..12.0 I/InO 1.5 I/InO Limit IDIFFmax of n-th Harm.Restraint 2.12.2.4 Information for the Differential Protection F.No. Alarm Comments 05603 >Diff BLOCK >BLOCK differential protection 05615 Diff OFF Differential protection is switched OFF 05616 Diff BLOCKED Differential protection is BLOCKED 05617 Diff ACTIVE...
  • Page 113 Differential Protection (ANSI 87G/87M/87T) F.No. Alarm Comments 05692 Diff>> TRIP Differential prot.: TRIP by IDIFF>> 05620 Diff Adap.fact. Diff: adverse Adaption factor CT 05713 Diff CT-S1: Diff. prot: Adaptation factor CT side 1 05714 Diff CT-S2: Diff. prot: Adaptation factor CT side 2 05701 Diff L1: Diff.
  • Page 114: Earth Current Differential Protection (Ansi 87Gn, Tn)

    For applications such as auto-transformers, starpoint earthing transformers and shunt reactors, Siemens recommends to use the 7UT612 protective relay instead. For high-ohmic earthing of generators, the earth fault protection function (Section 2.26) is used.
  • Page 115 Earth Current Differential Protection (ANSI 87GN, TN) Protected object: Generator L1S1 L1S2 L2S1 L2S2 L3S1 L3S2 Figure 2-46 Connection Scheme and Definition of Current Vectors In both measuring principles, there is a vector addition of the phase currents on the line side (always side 1 in the 7UM62), which yields the zero sequence current.
  • Page 116 Functions When an external non-earthed fault causes a heavy current to flow through the pro- tected zone, differences in the magnetic characteristics of the phase current trans- formers under conditions of saturation may cause a significant summation current which may simulate an earth current flowing into the protected zone. Measures must be taken to prevent this current from causing a trip.
  • Page 117 Earth Current Differential Protection (ANSI 87GN, TN) In applications with direct measurement of the starpoint current (e.g. earth current dif- ferential protection for transformers), the starpoint current is queried to the evaluation of the characteristics. This provides additional restraint against CT problems such as wrong zero sequence current modeling of the phase current transformers on side 1.
  • Page 118 Functions • Phase current monitoring To preclude 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. To do so, the phase currents of side 1 are monitored. As soon as one phase current exceeds the threshold, the blocking takes effect.
  • Page 119: Setting Hints

    Earth Current Differential Protection (ANSI 87GN, TN) 5812 REF BLOCKED 5803 >BLOCK REF 2102 REF I> BLOCK 5817 5821 REF picked up REF TRIP L1Sm 5840 2112 T I-REF> REF I> blocked Tripping matrix & L2Sm & Tmin TRIP L3Sm 5841 2103 REF U0>RELEASE REF U0>...
  • Page 120 Functions Address 2101 REF PROT. is used to switch the function ON or OFF, or to block only the trip command (Block relay). Note: When the device is delivered, the earth current differential protection is set to OFF. This is because this protection must not be used before at least the allocation and po- larity of the CTs have been correctly set.
  • Page 121: Settings Of The Earth Current Differential Protection

    Earth Current Differential Protection (ANSI 87GN, TN) 2.13.2.1 Settings of the Earth Current Differential Protection Addr. Setting Title Setting Options Default Setting Comments 2101 REF PROT. Restricted Earth Fault Protection Block relay for trip com- mands 2102 REF I> BLOCK 1.0..2.5 I/InO 1.5 I/InO REF Pickup of Phase Current...
  • Page 122: Underexcitation (Loss-Of-Field) Protection (Ansi 40)

    Functions 2.14 Underexcitation (Loss-of-Field) Protection (ANSI 40) General The underexcitation or loss of field protection protects a synchronous generator/motor from asynchronous operation in the event of a malfunction in the excitation system and from local overheating of the rotor. Furthermore, it ensures that the network sta- bility is not endangered due to the underexcitation of large synchronous generators.
  • Page 123 Note: The generator diagram can be visualized in more than one way. Figure 2-51 shows a form that is quite common at Siemens Power Generation, with a rotation of 90° and mirroring at the active power axis. The 7UM62 underexcitation protection provides three independent characteristics which can be freely combined.
  • Page 124 Functions Excitation Voltage In case of a faulty voltage regulator or a failure of the excitation voltage, it is possible to switch up with a short delay (time stage T SHRT Uex<, e.g. 1.5 s). To do so, the Request device must either be informed via a binary input of the excitation voltage failure, or the excitation voltage must be fed in via measuring transducer TD3 and a voltage divider, provided that at address 3012 EXCIT.
  • Page 125: Setting Hints

    Underexcitation (Loss-of-Field) Protection (ANSI 40) 3002 1/xd CHAR. 1 3003 ANGLE 1 3004 T CHAR. 1 FNo. 05344 Exc<1 TRIP & FNo. 05329 >Char. 1 BLK. 3005 1/xd CHAR. 2 Tripping 3006 ANGLE 2 3007 T CHAR. 2 FNo. 05345 matrix Exc<2 TRIP &...
  • Page 126 Functions The trip characteristics of the underexcitation protection in the admittance value diagram are composed of straight lines which are respectively defined by their α conductance section 1/xd (=coordinate distance) and their inclination angle . The α α straight lines (1/xd CHAR.1)/ 1 (characteristic 1) and (1/xd CHAR.2)/ (characteristic 2) form the static underexcitation limit (see figure 2-54).
  • Page 127 Underexcitation (Loss-of-Field) Protection (ANSI 40) = 6300 V U = U I = I = 5270 kVA = 50.0 Hz = 1500 RPM cos ϕ = 0.800 Limit of the stator = 2.470 winding heating = 1.400 Measuring point Limit of the stator Phase winding heating angle...
  • Page 128 Functions Voltage transformer: U = 6.3 kV N VT prim 483 A 6300 V ⋅ ⋅ ------------ - ---------- - ------------------ - ------------------ - 0.39 2.47 6300 V 500 A dsec Multiplied by a safety factor of about 1.05, the setting value 1/xd CHAR. 1 at address 3002 results.
  • Page 129: Settings Of The Underexcitation (Loss-Of-Field) Protection

    Underexcitation (Loss-of-Field) Protection (ANSI 40) This feature is set at address 3011 T SHRT Uex<. The following messages and trip commands are typically assigned: Table 2-6 Setting the Underexcitation Protection Characteristic 1 and 2 static not delayed Annunciation: Err < PU stability Characteristic 1 and 2 static long-time delayed...
  • Page 130: Information For The Underexcitation (Loss-Of-Field) Protection

    Functions Addr. Setting Title Setting Options Default Setting Comments 3012 EXCIT. VOLT. State of Excitation Volt. Supervi- sion 3013 Uexcit. < 0.50..8.00 V 2.00 V Excitation Voltage Superv. Pik- 3014A Umin 10.0..125.0 V 25.0 V Undervoltage blocking Pickup 3002 1/xd CHAR. 1 0.25..3.00 0.41 Conductance Intersect Charac-...
  • Page 131: Reverse Power Protection (Ansi 32R)

    Reverse Power Protection (ANSI 32R) 2.15 Reverse Power Protection (ANSI 32R) General Reverse power protection is used to protect a turbo-generator unit in case of failure of energy to the prime mover. In this case the synchronous generator runs as a motor and drives the turbine, taking the required motoring energy from the network.
  • Page 132: Setting Hints

    Functions FNo. 05096 Pr picked up 3105A T-HOLD 3102 P> REVERSE 3103 T-SV-OPEN & FNo. 05097 Tripping Pr TRIP matrix 3104 T-SV-CLOSED & FNo. 05098 Pr+SV TRIP TMin FNo.05083 FNo. 05092 TRIP CMD >Pr BLOCK Pr BLOCKED FNo.05086 >SV tripped Figure 2-57 Logic Diagram of the Reverse Power Protection 2.15.2 Setting Hints...
  • Page 133: Settings Of The Reverse Power Protection

    Reverse Power Protection (ANSI 32R) = √3 ⋅ U ⋅ I . If the primary motoring energy is known, it must be converted Nsec Nsec Nsec to secondary quantities using the following formula: mach N mach N mach ⋅ ⋅ Setting -------------- - ------------------- -...
  • Page 134: Information For The Reverse Power Protection

    Functions 2.15.2.2 Information for the Reverse Power Protection F.No. Alarm Comments 05083 >Pr BLOCK >BLOCK reverse power protection 05086 >SV tripped >Stop valve tripped 05091 Pr OFF Reverse power prot. is switched OFF 05092 Pr BLOCKED Reverse power protection is BLOCKED 05093 Pr ACTIVE Reverse power protection is ACTIVE 05096 Pr picked up...
  • Page 135: Forward Active Power Supervision (Ansi 32F)

    Forward Active Power Supervision (ANSI 32F) 2.16 Forward Active Power Supervision (ANSI 32F) General The machine protection 7UM62 includes an active power supervision which monitors whether the active power falls below one set threshold, and whether a separate second set threshold is exceeded. Each of these functions can initiate different control functions.
  • Page 136: Setting Hints

    Functions 2.16.2 Setting Hints General The forward active power protection is only effective and accessible if this function was set within the framework of the protective function configuration (section 2.2, 0132, FORWARD POWER = Enabled. Set Disabled if the function is not address required.
  • Page 137: Information For The Forward Power Supervision

    Forward Active Power Supervision (ANSI 32F) 2.16.2.2 Information for the Forward Power Supervision F.No. Alarm Comments 05113 >Pf BLOCK >BLOCK forward power supervision 05116 >Pf< BLOCK >BLOCK forw. power superv. Pf< stage 05117 >Pf> BLOCK >BLOCK forw. power superv. Pf> stage 05121 Pf OFF Forward power supervis.
  • Page 138: Impedance Protection (Ansi 21)

    Functions 2.17 Impedance Protection (ANSI 21) General The machine impedance protection is used as a selective time graded protection to provide shortest possible tripping times for short-circuits in the synchronous machine, on the terminal leads as well as in the lower voltage winding of the unit transformer. It thus provides a fast back-up protection to the generator and transformer differential relays.
  • Page 139: Determination Of The Short-Circuit Impedance

    Impedance Protection (ANSI 21) 2.17.1.2 Determination of the Short–Circuit Impedance For calculation of the fault impedance, the currents and voltages of the faulty loop are decisive. The phase selective fault detector determines the faulted loop and releases the corresponding measurement values for impedance calculation (see Table 2-7). −...
  • Page 140 Functions Table 2-8 Fault Modeling and Measuring Errors on the Generator Side in Case of System Faults System Fault Fault Model on the Loop selection Measuring Errors Generator Side 3–pole short 3–pole short circuit Phase-earth Always correct circuit measuring 2–pole short 3–pole short circuit Phase-earth loop Always correct...
  • Page 141: Tripping Characteristic

    Impedance Protection (ANSI 21) FNo. 03967 Imp. Fault L1 FNo. 03968 Pickup I > Imp. Fault L2 & FNo. 03969 Imp. Fault L3 Pickup I > FNo. 03966 & Imp. picked up Pickup I > & FNo. 03953 FNo. 03962 >Imp.
  • Page 142: Tripping Logic

    Functions The protected zones can be chosen such that the first stage (ZONE Z1, T-Z1) covers faults in the generator and the lower voltage side of the unit transformer, whereas the second stage (ZONE Z2, ZONE2 T2) measures into the network. It should be noted that faults in the system cause impedance measurement errors due to the connection group (star-delta) of the unit transformer (see subsection 2.17.1.2).
  • Page 143 Impedance Protection (ANSI 21) A drop-out can only be caused by a drop-out of the overcurrent pickup and not by leaving the tripping polygon. Figure 2-61 illustrates the logic diagram of the impedance protection. FNo. 03966 3312 T END Imp. picked up 3310 ZONE Z2 3311 ZONE2 T2 &...
  • Page 144: Setting Hints

    Functions 2.17.2 Setting Hints General The machine impedance detection is only effective and accessible if it was previously set within the framework of project configuration (Section 2.2) at address 0133, IMPEDANCE PROT. = Enabled. Set Disabled if the function is not required. Address 3301 IMPEDANCE PROT.
  • Page 145 Impedance Protection (ANSI 21) with its operating time or with a slight time delay (undelayed tripping). A 0.1 s time delay is preferred. For ZONE Z2 the reach could be set to about 100 % of the transformer reactance, or in addition to a network impedance.
  • Page 146 Functions Consequently, the secondary side setting value of zone 1 at address 3306 ZONE Z1 ⁄ 500 A 1 A ----------------------------------- - 0.3669 Ω ⋅ 2.91 Ω ⁄ secondary 6.3 kV 100 V Note: The following ratio would result from the connection of a 5 A device to a 5 A transformer: ⁄...
  • Page 147: Power Swing Blocking

    Impedance Protection (ANSI 21) The Z1B zone is usually switched effective with an open high-voltage circuit breaker. In this case, every impedance protection pickup can only be due to a fault in the protection zone of the block, as the power system is disconnected from the block. Consequently, the undelayed tripping zone can be extended to 100 % to 120 % of the protection zone without any loss of selectivity.
  • Page 148: Setting Hints

    Functions polygon P/SPOL and the trip polygon TPOL, and the rate of change ∆Z/∆t are matched to one another in such a way that power swings are reliably detected and the desired impedance zone (Z1 or Z1 & Z2) of the impedance protection is blocked. The blocking remains effective until the measured impedance vector has left again the trip polygon / power swing polygon, the impedance changes faster than the change rate, or asymmetrical power conditions rule out the possibility of a power swing.
  • Page 149 Impedance Protection (ANSI 21) The following relation allows to estimate the rate of change: dZ t ( ) dR t ( ) Xπf Xπf Ω ≈ ------------- - -------------- ---------------------------- - ---------------------- - in --- - δ πf æ ö 2sin 2sin -- -...
  • Page 150 Functions ⋅ 47 24 Ω ------------------------------ - L min ⋅ ⋅ 3 1 1 )∆/t 43 20 Ω/20 ms 2160 Ω/s ------ - – L min 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).
  • Page 151: Settings Of The Impedance Protection

    Impedance Protection (ANSI 21) 2.17.3.2 Settings of the Impedance Protection Addr. Setting Title Setting Options Default Setting Comments 3301 IMPEDANCE Impedance Protection PROT. Block relay for trip com- mands 3302 IMP I> 0.10..20.00 A 1.35 A Fault Detection I> Pickup 3303 U<...
  • Page 152 Functions F.No. Alarm Comments 03967 Imp. Fault L1 Imp.: Fault detection , phase L1 03968 Imp. Fault L2 Imp.: Fault detection , phase L2 03969 Imp. Fault L3 Imp.: Fault detection , phase L3 03977 Imp.Z1< TRIP Imp.: Z1< TRIP 03978 Imp.Z1B<...
  • Page 153: Out-Of-Step Protection (Ansi 78)

    Out-of-Step Protection (ANSI 78) 2.18 Out-of-Step Protection (ANSI 78) General In extensive high-voltage networks, short-circuits which are not disconnected quickly enough, or disconnection of coupling links which may result in an increasing of the coupling reactance, may lead to system swings. These consist of power swings which endanger the stability of the power transmission.
  • Page 154 Functions The current I is independent of the location of the measurement: – I(m) --------------------- - The voltage U at the location of measurement m is: ⋅ ⋅ U(m) – Thus results with: j δ j δ ⋅ ⋅ δ δ...
  • Page 155: Out-Of-Step Logic

    Out-of-Step Protection (ANSI 78) Im(Z) δ =0° -------- - = 0.8 -------- - (1–m)Z δ =180° (0.5–m)Z ϕ Re(Z) -------- - = 1.0 δ =180° –mZ = 1.3 -------- - δ =0° -------- - = 1.2 Figure 2-66 Impedances at the Measurement Location m 2.18.1.2 Out-of-Step Logic Figure 2-67 shows, more detailed, the power swing detection characteristic.
  • Page 156 Functions Im(Z) Œ –Z Characteristic 2 Z=R +jX  Characteristic 1 ϕ Re(Z Ž  Figure 2-67 Polygonal Out-of-Step Characteristic and Typical Power Swing Occurrences An out-of-step condition requires, additionally, that the impedance vector enters a power swing characteristic at one side and leaves it at the other side (loss of synchronism, cases Œ...
  • Page 157 Out-of-Step Protection (ANSI 78) Figure 2-68 shows the logic diagram of the out-of-step protection. The feature has two stages and can be blocked by a binary input. 3512 T-SIGNAL FNo. 05067 O/S char. 1 3511 T-HOLDING FNo. 05069 Release O/S det. char.1 Reset FNo.
  • Page 158: Setting Hints

    Functions 2.18.2 Setting Hints General The out-of-step protection is only effective and accessible if this function has been set during the configuration of the protective functions (Section 2.2, address 0135, OUT- OF-STEP = Enabled. Set Disabled if the function is not required. Address 3501 OUT-OF-STEP is used to switch the function ON or OFF, or to block only the trip command (Block Relay).
  • Page 159 Out-of-Step Protection (ANSI 78) ' can be calculated from the per unit reactance x ' as follows: ü N, Gen ⋅ ⋅ ---------------------------- - x ------ - ⋅ ü N, Gen where X – Transient reactance of the machine – Transient per unit reactance –...
  • Page 160 Functions The setting Z is decisive for the width of the power swing polygon. This setting value 3504 Za is determined by the total impedance Z and can be derived from the equation in Figure 2-70. Z can be calculated from the sum of Z and Z ;...
  • Page 161 Out-of-Step Protection (ANSI 78) The inclination angle ϕ of the power swing polygon can be set at address 3508 PHI POLYGON and thus matched to the conditions. Calculation Example: Generator data: ' = 0.20 = 6.3 kV = 483 A Transformer data: = 7 % = 5.3 MVA...
  • Page 162: Settings Of The Out-Of-Step Protection

    Functions Address 3509 REP. CHAR. 1 determines the number of out-of-step periods for Number of Power Swings characteristic 1 which will lead to trip, i.e.the number of times this characteristic must have been passed through. For characteristic 1, 1 or 2 passes are normally adequate as out-of-step conditions with the electrical centre within the power station unit should not be tolerated too long, and the power swing frequency tends to accelerate during an out-of-step condition, so that the electrical and dynamic stress of the machine...
  • Page 163: Information For The Out-Of-Step Protection

    Out-of-Step Protection (ANSI 78) Addr. Setting Title Setting Options Default Setting Comments 3510 REP. CHAR. 2 1..8 Number of Power Swing: Cha- racteristic 2 3511 T-HOLDING 0.20..60.00 sec 20.00 sec Holding Time of Fault Detection 3512 T-SIGNAL 0.02..0.15 sec 0.05 sec Min.
  • Page 164: Undervoltage Protection (Ansi 27)

    Functions 2.19 Undervoltage Protection (ANSI 27) General Undervoltage protection detects and reports abnormally low voltage conditions, some of which could be related to system stability problems (voltage collapse, etc.). Two-pole short circuits or earth faults cause an asymmetrical voltage collapse. Compared with three monophase measuring systems, the detection of the positive phase-sequence system is not influenced by these procedures and is advantageous especially with regard to the judgement of stability problems.
  • Page 165: Setting Hints

    Undervoltage Protection (ANSI 27) FNo. 06533 U< picked up 4002 U< 4003 T U< & Tripping FNo. 06539 matrix FNo. 06506 U< TRIP >BLOCK U< FNo. 06537 U<< picked up 4004 U<< 4005 T U<< & TMin TRIP CMD FNo. 06540 FNo.
  • Page 166: Settings Of The Undervoltage Protection

    Functions 2.19.2.1 Settings of the Undervoltage Protection Addr. Setting Title Setting Options Default Setting Comments 4001 UNDERVOLTAGE Undervoltage Protection Block relay for trip com- mands 4002 U< 10.0..125.0 V 75.0 V U< Pickup 0.00..60.00 sec; ∞ 4003 T U< 3.00 sec T U<...
  • Page 167: Overvoltage Protection (Ansi 59)

    Overvoltage Protection (ANSI 59) 2.20 Overvoltage Protection (ANSI 59) General Overvoltage protection serves to protect the electrical machine, and the associated electrical plant connected to it, from the effects of impermissible 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 168: Settings Of The Overvoltage Protection

    Functions Address 4107A VALUES U> serves to specify the measured quantities used by the Setting Values protection feature. The default setting (normal case) is specified for phase-to-phase voltages (= U-ph-ph). The phase-earth-voltages should be selected for low-voltage machines with grounded neutral conductor (= U-ph-e). It should be noted that even if phase-earth voltages are selected as measured quantities, the setting values of the protection functions are referred to phase-to-phase voltages.
  • Page 169 Overvoltage Protection (ANSI 59) F.No. Alarm Comments 06516 >BLOCK U> >BLOCK overvoltage protection U> 06517 >BLOCK U>> >BLOCK overvoltage protection U>> 06565 Overvolt. OFF Overvoltage protection switched OFF 06566 Overvolt. BLK Overvoltage protection is BLOCKED 06567 Overvolt. ACT Overvoltage protection is ACTIVE 06568 U>...
  • Page 170: Frequency Protection (Ansi 81)

    Functions 2.21 Frequency Protection (ANSI 81) General The frequency protection function detects abnormally high and low frequencies in the system. If the frequency lies outside the allowable range, appropriate actions are initiated, such as separating a generator from the system. A decrease in system frequency occurs when the system experiences an increase in the real power demand, or when a malfunction occurs with a generator governor or automatic generation control (AGC) system.
  • Page 171: Setting Hints

    Frequency Protection (ANSI 81) Figure 2-73 shows the logic diagram for the frequency protection function. f1 picked up FNo. 05232... >BLOCK f1 FNo. 05206... & 4202 f1 PICKUP 4204 T f1 f1 TRIP FNo. 05236... 4215 Umin U>Umin Measurement/ Logic FNo.
  • Page 172 Functions If underfrequency protection is used for load shedding purposes, then the frequency settings relative to other feeder relays are generally based on the priority of the customers served by the protective relay. Normally a graded load shedding is required that takes into account the importance of the consumers or consumer groups.
  • Page 173: Settings For The Frequency Protection

    Frequency Protection (ANSI 81) 2.21.2.1 Settings for the Frequency Protection Addr. Setting Title Setting Options Default Setting Comments 4201 O/U FREQUENCY Over / Under Frequency Protec- tion Block relay for trip com- mands 4202 f1 PICKUP 40.00..65.00 Hz 48.00 Hz f1 Pickup 4203 f1 PICKUP...
  • Page 174 Functions F.No. Alarm Comments 05233 f2 picked up f2 picked up 05234 f3 picked up f3 picked up 05235 f4 picked up f4 picked up 05236 f1 TRIP f1 TRIP 05237 f2 TRIP f2 TRIP 05238 f3 TRIP f3 TRIP 05239 f4 TRIP f4 TRIP 7UM62 Manual...
  • Page 175: Overexcitation (Volt/Hertz) Protection (Ansi 24)

    Overexcitation (Volt/Hertz) Protection (ANSI 24) 2.22 Overexcitation (Volt/Hertz) Protection (ANSI 24) General The overexcitation protection is used to detect impermissible overexcitation conditions which can endanger generators and transformers. The overexcitation protection must pick up when the induction admissible for the protected object (e.g. power station unit transformer) is exceeded.
  • Page 176 Functions The thermal characteristic is prespecified by 8 value pairs concerning the U/f overexcitation (related to nominal values) and the t trip time. In most cases, the specified characteristic related to standard transformers provides for sufficient protection. If this characteristic does not correspond to the actual thermal behavior of the object to be protected, each desired characteristic can be implemented by entering customer-specific trip times for the specified U/f overexcitation values.
  • Page 177: Setting Hints

    Overexcitation (Volt/Hertz) Protection (ANSI 24) Figure 2-75 illustrates the logic diagram of the overexcitation protection. The counter can be reset to zero by means of a blocking input or a reset input. FNo. 05370 U/f> picked up 4302 U/f > 4303 T U/f >...
  • Page 178 Figure 2-76 Tripping Time Characteristic of the Overexcitation Protection – Presettings The characteristic of a Siemens standard transformer was selected as a presetting for the parameters 4306 to 4313. If the manufacturer of the object to be protected did not include any instructions on this subject, the preset standard characteristic should be used.
  • Page 179: Settings Of The Overexcitation Protection

    Overexcitation (Volt/Hertz) Protection (ANSI 24) Voltage A perhaps existing deviation between the primary nominal voltage of the voltage Transformer transformers and the object to be protected is compensated by means of the internal Adaptation correction factor (U ). As a prerequisite, however, the incoming power N prim N mach system parameters 0221 Unom PRIMARY and 0251 UN GEN/MOTOR must have...
  • Page 180: Inverse-Time Undervoltage Protection (Ansi 27)

    Functions 2.23 Inverse-Time Undervoltage Protection (ANSI 27) General The inverse-time undervoltage protection mainly protects consumers (induction machines) from the consequences of dangerous voltage drops in island networks and prevents impermissible operating conditions and possible loss of stability. It can also be used as a criterion for load shedding in interconnected networks.
  • Page 181: Setting Hints

    Inverse-Time Undervoltage Protection (ANSI 27) The pickup/dropout ratio is 101 % or 0.5 V absolute of the threshold set at address 4402 Up< PICKUP. The integral action of the tripping time determination is “frozen“ between the pickup and the dropout value. Figure 2-77 shows the logic diagram of the inverse undervoltage protection.
  • Page 182: Settings Of The Inverse Undervoltage Protection

    Functions 2.23.2.1 Settings of the Inverse Undervoltage Protection Addr. Setting Title Setting Options Default Setting Comments 4401 INV. UNDERVOLT. Inverse Undervoltage Protec- tion Up< Block relay for trip com- mands 4402 Up< PICKUP 10.0..125.0 V 75.0 V Up< Pickup 4403 T MUL 0.10..5.00 sec;...
  • Page 183: Rate-Of-Frequency-Change Protection Df/Dt (Ansi 81R)

    Rate-of-Frequency-Change Protection df/dt (ANSI 81R) 2.24 Rate-of-Frequency-Change Protection df/dt (ANSI 81R) General With the rate-of-frequency-change protection, frequency changes can be quickly de- tected. This allows a prompt response to frequency dips or frequency rises. A trip com- mand can be issued even before the pickup threshold of the frequency protection (see Section 2.21) is reached.
  • Page 184: Setting Hints

    Functions 5516 df1/dt pickup 5517 df2/dt pickup 5518 df3/dt pickup & "1" 5519 df4/dt pickup 4505 df1/dt & f1 5520 5232 df1/dt TRIP f1 picked up 5521 df2/dt TRIP -df/dt< 5522 df3/dt TRIP +df/dt> "1" 5523 df4/dt TRIP 4504 T df1/dt 4502 df1/dt >/<...
  • Page 185 Rate-of-Frequency-Change Protection df/dt (ANSI 81R) The following relations can be used as an example for estimation of the pickup value. They apply for the change rate at the beginning of a frequency change (approx. 1 sec- ond). ∆P ⋅ ---- - --------- - ------- - –...
  • Page 186: Settings Of The Rate-Of-Frequency-Change Protection

    Functions Table 2-12 Setting Value df/dt HYSTERESIS dfx/dt M WINDOW stage dfn/dt (Addr. 4519A, 4521A) (Addr. 4520A, 4522A) ≈ 0,05 0.1...0.5 Hz/s 25...10 ≈ 0,1 0.5...1 Hz/s 10...5 ≈ 0,2 1...5 Hz/s 10...5 ≈ 0,5 5...20 Hz/s 5...1 Address 4518 U MIN is used to set the minimum voltage below which the frequency Minimum Voltage change protection will be blocked.
  • Page 187: Information For The Rate-Of-Frequency-Change Protection

    Rate-of-Frequency-Change Protection df/dt (ANSI 81R) Addr. Setting Title Setting Options Default Setting Comments 4509 df2/dt & f2 AND logic with pickup of stage f2 4510 df3/dt >/< -df/dt< negative rate of freq. -df/dt< negative Mode of Threshold (df3/dt >/<) change rate of freq.
  • Page 188: Jump Of Voltage Vector

    Functions 2.25 Jump of Voltage Vector General It is not uncommon that consumers with their own generating plant feed power directly into a network. The incoming feeder is usually the ownership boundary between the utility and these consumers/producers. A failure of the input line, e.g. because of a three-pole automatic reclosure, can cause a deviation of the voltage or frequency at the feeding generator which is a function of the overall output.
  • Page 189: Functional Description

    Jump of Voltage Vector 2.25.1 Functional Description Measuring The vector of the positive sequence system voltage is calculated from the phase-to- Principle 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 is an indicator for an abrupt change of the current flow.
  • Page 190: Setting Hints

    Functions The vector jump function becomes ineffective on leaving the permissible frequency band. The same is true for the voltage, for which the limiting parameters are U MIN and U MAX. On violation of the frequency or voltage band, the logic generates a logical “1”, and the reset input is continuously active.
  • Page 191: Settings Of The Vector Jump Detection

    Jump of Voltage Vector The value to be set for the vector jump (address 4602 DELTA PHI) depends on the Pickup Values feeding and load conditions. Abrupt load changes in the active power cause a jump of the voltage vector. The value to be set must be specifically determined for the power system considered.
  • Page 192: Information For The Vector Jump Detection

    Functions 2.25.2.2 Information for the Vector Jump Detection F.No. Alarm Comments 05581 >VEC JUMP block >BLOCK Vector Jump 05582 VEC JUMP OFF Vector Jump is switched OFF 05583 VEC JMP BLOCKED Vector Jump is BLOCKED 05584 VEC JUMP ACTIVE Vector Jump is ACTIVE 05585 VEC JUMP Range Vector Jump not in measurement range 05586 VEC JUMP pickup...
  • Page 193: Stator Earth Fault Protection (Ansi 59N, 64G, 67G)

    90–%–Stator Earth Fault Protection (ANSI 59N, 64G, 67G) 2.26 90–%–Stator Earth Fault Protection (ANSI 59N, 64G, 67G) General 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 194 Functions 7UM62 – Loading resistor – Generator earth capacitance – Voltage divider – Line earth capacitance – Displacement voltage – Unit transformer earth capacitance – Coupling capacitance of unit transformer Figure 2-82 Unit Connected Generator with Neutral Earthing Transformer – Loading resistor –...
  • Page 195 90–%–Stator Earth Fault Protection (ANSI 59N, 64G, 67G) L3 L2 L1 7UM62 Figure 2-84 Earth Fault Direction Detection with Busbar Connection Consequently, the loading resistor must be situated on the other side of the measurement location (current transformer, toroidal current transformer) when viewed from the machine.
  • Page 196 Functions On the occurrence of earth fault in the machine zone, the disconnection of the machine is initiated after a set delay time. When the earth current is not decisive to detect an earth fault, e.g. because the circuit breaker is open, the earth current detection can be switched off by a control signal via a binary input of the relay.
  • Page 197: Setting Hints

    90–%–Stator Earth Fault Protection (ANSI 59N, 64G, 67G) Determination of In addition to this, a supplementary function serves to determine the faulty phase. As the Faulty Phase the phase-earth-voltage in the faulty phase is less than in the two remaining phases and as the voltage even increases in the latter ones, the faulty phase can be determined by determining the smallest phase-earth voltage in order to generate a corresponding result as fault message.
  • Page 198 Functions For machines in unit connection, the pickup value has to be chosen such that displacements during network earth faults which are transferred via the coupling capacitances of the unit transformer to the stator circuit, do not lead to pickup. The damping effect of the loading resistor must also be considered in this case.
  • Page 199: Settings Of The 90% Stator Earth Fault Protection

    90–%–Stator Earth Fault Protection (ANSI 59N, 64G, 67G) Voltage divider 500 V / 100 V Toroidal c.t. 60 A/1 A Protected zone 90 % With full neutral displacement voltage, the load resistor supplies: 500 V -------------- - 50 A 10 Ω Referred to the 6.3 kV side, this results in: 500 3 ⁄...
  • Page 200: Information For The 90% Stator Earth Fault Protection

    Functions 2.26.2.2 Information for the 90% Stator Earth Fault Protection F.No. Alarm Comments 05173 >S/E/F BLOCK >BLOCK stator earth fault protection 05176 >S/E/F Iee off >Switch off earth current detec.(S/E/F) 05181 S/E/F OFF Stator earth fault prot. is switch OFF 05182 S/E/F BLOCKED Stator earth fault protection is BLOCK.
  • Page 201: Sensitive Earth Fault Protection (Ansi 51Gn, 64R)

    Sensitive Earth Fault Protection (ANSI 51GN, 64R) 2.27 Sensitive Earth Fault Protection (ANSI 51GN, 64R) 2.27.1 Functional Description General The highly sensitive earth fault protection has the task to detect earth fault in systems with isolated or high-impedance earthed star-point. The pick-up criterion is the magnitude of the (residual) earth current.
  • Page 202 Functions Figure 2-89 shows the logic diagram of sensitive earth fault detection. 3PP13 7UM62 7XR61 Figure 2-88 Application Example as Rotor Short Circuit to Earth Protection (7XR61 – series device for the rotor short circuit to earth protection; 3PP13 – from UPU > 150 V, resistors in the 7XR61 must be shorted!) FNo.
  • Page 203: Setting Hints

    Sensitive Earth Fault Protection (ANSI 51GN, 64R) 2.27.2 Setting Hints General The sensitive earth fault detection is only effective and accessible if it has been set during the configuration of the protective functions at address 0151 O/C PROT. Iee> = with Iee1 or with Iee2. If one of the options with current evaluation was selected during the configuration of the 90–%–stator earth fault protection (0150 S/ E/F PROT., see Section 2.2) the sensitive current measuring input of the 7UM62 is assigned to this feature.
  • Page 204: Settings Of The Sensitive Earth Fault Protection

    Functions Use as Earth Short- For low-voltage machines with neutral conductor incorporated in cables or machines Circuit Protection with low-impedance earthed starpoint, the time-overcurrent protection of the phase branches already is a short-circuit to earth protection, as the short-circuit to earth current also flows through the faulty phase.
  • Page 205: Stator Earth Fault Protection With 3Rd Harmonics (Ansi 27/59Tn 3Rd Harm.)

    100–%–Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) 2.28 100–%–Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) 2.28.1 Functional Description General As described in section 2.26, the measuring procedure based on the fundamental wave of the displacement voltage serves to protect maximally 90 % to 95 % of the stator winding.
  • Page 206 Functions 1. Ue connected to neutral transformer: Connection of the U input to the voltage transformer in the machine starpoint 2. Ue connected to broken delta winding: Connection of the U input to the broken delta winding 3. Not connected: Calculation of the displacement voltage by means of the three phase-earth-voltages, if the U input is not connected 4.
  • Page 207: Setting Hints

    100–%–Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) FNo. 05567 5202 U0 3.HARM< U(3.H.) SEF 3H pick.up neutral transformer 5204 T SEF 3. HARM. Tripping matrix & 5203 U0 3.HARM> FNo. 05568 SEF 3H TRIP not connected broken delta winding 5205 P min >...
  • Page 208: Settings Of The 100-%-Stator Earth Fault Protection With 3Rd Harmonics

    Functions Pickup Value for Depending on the selection of the connection type, only one of the two setting parameters 5202 or 5203 is accessible. The setting values can only be determined 3rd Harmonics within the framework of a primary test. The following principle is generally valid: −...
  • Page 209: Information For The 100-% Stator Earth Fault Protection With 3Rd Harmonics

    100–%–Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) 2.28.2.2 Information for the 100–% Stator Earth Fault Protection with 3rd Harmonics F.No. Alarm Comments 05553 >SEF 3H BLOCK >BLOCK SEF with 3.Harmonic 05561 SEF 3H OFF SEF with 3.Harm. is switched OFF 05562 SEF 3H BLOCK SEF with 3.Harm.
  • Page 210: Stator Earth Fault Protection With 20 Hz Voltage Injection (Ansi 64G - 100%)

    Functions 2.29 100–% Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G - 100%) General The 100-% stator earth fault protection detects earth faults in the stator windings of generators which are connected with the network via a unit transformer. This protec- tion function, which works with an injected 20 Hz voltage, is independent of the sys- tem-frequency displacement voltage appearing in earth faults, and detects earth faults in all windings including the machine starpoint.
  • Page 211 100–% Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G - 100%) The driving 20 Hz voltage is picked up directly at the loading resistor via a voltage di- vider. In addition, the 20 Hz current flow is measured via a miniature CT. Both quanti- ties (U and I ) are fed to the protection device.
  • Page 212 Functions In addition to the determination of the earth resistance, the protection function features an earth current stage which processes the current r.m.s. value and thus takes into account all frequencies. It is used as a backup stage and covers approx. 80 to 90 % of the protection zone.
  • Page 213: Setting Hints

    100–% Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G - 100%) 2.29.2 Setting Hints General The 100-% stator earth fault protection is only effective and accessible if it has been set to Enabled at address 0153 100% SEF-PROT. during the configuration of the protection functions.
  • Page 214 Functions The conversion factor of the earth resistance is set as FACTOR R SEF at address 0275 in Power System Data 1. The general formula for calculation (R ) is: Eprim Esec ü Divider ⋅ FACTOR R SEF ü ------------------- - Transf ü...
  • Page 215: Settings Of The 100-% Stator Earth Fault Protection

    100–% Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G - 100%) The parameter PHI I SEF (default setting 0°) of address 5309 is used to compen- Correction Angle, Contact Resistance sate the angle error of the CTs and angle distortions caused by a less than ideal earth- ing or neutral transformer.
  • Page 216: Information For The 100-% Stator Earth Fault Protection

    Functions 2.29.2.2 Information for the 100-% Stator Earth Fault Protection F.No. Alarm Comments 05473 >SEF100 BLOCK >BLOCK Stator earth fault protection 05476 >U20 failure >Failure 20Hz bias voltage (S/E/F) 05481 SEF100 OFF S/E/F 100% protection is switched OFF 05482 SEF100 BLOCKED Stator earth flt.
  • Page 217: Rotor Earth Fault Protection R, Fn (Ansi 64R)

    Rotor Earth Fault Protection R, fn (ANSI 64R) 2.30 Rotor Earth Fault Protection R, fn (ANSI 64R) General Rotor earth fault protection is used to detect earth faults in the excitation circuit of synchronous machines. One earth fault in the rotor winding does not cause immediate damage;...
  • Page 218 Functions The rotor earth fault calculation calculates the complex earth impedance from the aux- iliary AC voltage U and the current I . The earth resistance R of the excitation circuit is then calculated from the earth impedance. The device also considers the cou- pling capacitance of the coupling unit C , the series (e.g.
  • Page 219: Setting Hints

    Rotor Earth Fault Protection R, fn (ANSI 64R) 2.30.2 Setting Hints General The rotor earth fault protection is only effective and accessible if it has been set during the configuration of the protective functions at address 0160 ROTOR E/F = Enabled. Set Disabled if the function is not required.
  • Page 220: Settings Of The Rotor Earth Fault Protection

    Functions The series resistors R for the protection of the coupling capacitors can be considered with the total series resistance (address 6007) since the brush resistance and the series resistance are connected in series in the measurement circuit. The resultant resistance applies for R SERIES, i.e. the parallel connection in each case of the series resistors R and for the resistance of the two brushes.
  • Page 221: Information For The Rotor Earth Fault Protection

    Rotor Earth Fault Protection R, fn (ANSI 64R) Addr. Setting Title Setting Options Default Setting Comments 6006 X COUPLING -100..800 Ohm 398 Ohm Coupling Reactance 6007 R SERIES 0..999 Ohm 50 Ohm Series Resistance (e.g. Meas. Brushes) 6008 I RE< 1.0..50.0 mA;...
  • Page 222: Sensitive Rotor Earth Fault Protection With 1 To 3 Hz Square Wave Voltage Injection (Ansi 64R - 1 To 3 Hz)

    Functions 2.31 Sensitive Rotor Earth Fault Protection with 1 to 3 Hz Square Wave Voltage Injection (ANSI 64R - 1 to 3 Hz) General The rotor earth fault protection has the task to detect high- or low-resistance earth faults in the excitation circuit of synchronous generators. Although an earth fault in the excitation winding does not cause immediate damage, a second earth fault will lead to a turn-to-turn fault in the excitation winding.
  • Page 223 Sensitive Rotor Earth Fault Protection with 1 to 3 Hz Square Wave Voltage Injection (ANSI 64R - 1 to 3 Hz) 7XR6003 7XR6004 7XT71 7UM62x : 0.5 Hz to 4.0 Hz Galvanic lg (t) isolation 40 k Ω Control (MU1) Control = 1/6 +/-50 V...
  • Page 224 Functions 50 V 2 ⋅ U Displacement voltage U 50 V Meas ∞ 5 mA 5 mA Meas = 5 k Ω 2 ⋅ U 2 ⋅ I , with R << R 2 ⋅ I = 2 ⋅ I offset = Interference offset...
  • Page 225 Sensitive Rotor Earth Fault Protection with 1 to 3 Hz Square Wave Voltage Injection (ANSI 64R - 1 to 3 Hz) Test mode 100 kΩ 20 kΩ (Series resistor = R 6107 TEST RESISTOR 5411 & 2 Cir. open RE> &...
  • Page 226 Functions 10 V 4-20 mA 20 mA "1" 295 TRANSDUCER 1 & 10 V 4-20 mA "1" 20 mA 296 TRANSDUCER 2 Edge detector 5401 T Edge Fail REF 1-3Hz & 6106 Qc < òdt 5395 T Interference & REF 1-3Hz open 10 s 6102 RE<...
  • Page 227: Setting Hints

    Sensitive Rotor Earth Fault Protection with 1 to 3 Hz Square Wave Voltage Injection (ANSI 64R - 1 to 3 Hz) 2.31.2 Setting Hints General The sensitive rotor earth fault protection is only effective and accessible if it has been set to Enabled at address 0161 REF 1-3Hz during the configuration of the protection functions.
  • Page 228: Settings Of The Sensitive Rotor Earth Fault Protection

    Functions 2.31.2.1 Settings of the Sensitive Rotor Earth Fault Protection Addr. Setting Title Setting Options Default Setting Comments 6101 REF 1-3Hz Rotor Earth Fault Protection (1- 3Hz) Block relay for trip com- mands 6102 RE< WARN 5.0..80.0 kOhm 40.0 kOhm Pickup Value of Warning Stage Re<...
  • Page 229: Motor Starting Time Supervision (Ansi 48)

    Motor Starting Time Supervision (ANSI 48) 2.32 Motor Starting Time Supervision (ANSI 48) General When the 7UM62 relay is used to protect a motor, the starting time monitoring feature supplements the overload protection described in Section 2.9 by protecting the motor against the potential damage that might result from frequent starting or extended starting durations.
  • Page 230 Functions Therefore, if the starting current I actually measured is smaller (or larger) than the entered at address START. CURRENT), the actual tripping nominal starting current I time t is lengthened (or shortened) accordingly (see also Figure 2-102). trip Definite-Time During motor starting, the definite time characteristic is designed to initiate a trip if the Overcurrent motor starting time exceeds the maximum allowable blocked rotor time t...
  • Page 231: Setting Hints

    Motor Starting Time Supervision (ANSI 48) 2.32.2 Setting Hints The motor starting time supervision is only effective and accessible if address 0165 General STARTUP MOTOR has been set to Enabled during the configuration of the protective functions. Set Disabled if the function is not required. Address 6501 STARTUP MOTOR is used to switch the function ON or OFF, or to block only the trip command (Block Relay).
  • Page 232: Settings Of The Motor Starting Time Supervision

    Functions æ ö StartCurr. ⋅ --------------------- - è ø Trip Startmax Under nominal conditions, the tripping time is the maximum starting time T . For Startmax ratios deviating from nominal conditions, the motor tripping time changes. At 80 % of nominal voltage (which corresponds to 80% of nominal starting current), the tripping time can be: æ...
  • Page 233: Restart Inhibit For Motors (Ansi 66, 49Rotor)

    Restart Inhibit for Motors (ANSI 66, 49Rotor) 2.33 Restart Inhibit for Motors (ANSI 66, 49Rotor) General The rotor temperature of a motor generally remains well below its maximum allowable temperature during normal operation and even during severe loading conditions. However, during motor starting, the rotor can heat up quickly. If multiple starting attempts are made in a short duration of time, the rotor could suffer thermal damage.
  • Page 234 Functions Although the heat distribution at the rotor cage bars can range widely during motor starting, the different maximum temperatures in the rotor do not necessarily affect the motor restart inhibit (see Figure 2-104). It is much more important to establish a thermal profile, after a complete motor start, that is appropriate for the protection of the motor’s thermal condition.
  • Page 235 Restart Inhibit for Motors (ANSI 66, 49Rotor) Extending the In order to properly account for the reduced heat exchange when a self-ventilated Cooling Time motor is stopped, the cooling time constants can be increased relative to the time constants for a running machine by the factor Kt at STOP (address 6608). A stopped Constant motor is defined by current below an adjustable current flow monitoring threshold BkrClosed I MIN, assuming that the motor idle current is greater than this...
  • Page 236: Setting Hints

    Functions 6609 Kt at RUNNING τ kτ at Running x 6602 IStart/IMOTnom 6608 Kt at STOP 6603 T START MAX τ 6606 MAX.WARM STARTS kτ at Stop x 6607 #COLD-#WARM 6604 T EQUAL 0281 BkrClosed I MIN Θ (t) Calculator Θ...
  • Page 237 Restart Inhibit for Motors (ANSI 66, 49Rotor) RESTART INHIBIT is used to switch the function ON or OFF, or to block only the trip command (Block Relay). Necessary The user communicates to the protective relay the characteristic motor values Characteristic supplied by the manufacturer, which are necessary for calculation of the rotor Values temperature.
  • Page 238 Functions For the rotor temperature equilibrium time, a setting of. T EQUAL = 1 min has proven to be a good value. The value for the minimum inhibit time T MIN. INHIBIT depends of the requirements made by the motor manufacturer, or by the system conditions. It must in any case be higher than T EQUAL.
  • Page 239: Settings Of The Restart Inhibit For Motors

    Restart Inhibit for Motors (ANSI 66, 49Rotor) In Figure 2-107, 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 current. After the shutdown following the first starting attempt, the thermal profile is “frozen”.
  • Page 240: Information For The Motor Restart Inhibit

    Functions Addr. Setting Title Setting Options Default Setting Comments 6608 Kτ at STOP 1.0..100.0 Extension of Time Constant at Stop 6609 Kτ at RUNNING 1.0..100.0 Extension of Time Constant at Running 6610 T MIN. INHIBIT 0.2..120.0 min 6.0 min Minimum Restart Inhibit Time 2.33.2.2 Information for the Motor Restart Inhibit F.No.
  • Page 241: Breaker Failure Protection (Ansi 50Bf)

    Breaker Failure Protection (ANSI 50BF) 2.34 Breaker Failure Protection (ANSI 50BF) 2.34.1 Functional Description General The breaker failure protection can be assigned to the current inputs of side 1 or side 2 during the configuration of the protective functions (see Section 2.2). The breaker failure protection function monitors the reaction of a circuit breaker to a trip signal.
  • Page 242 Functions The current criterion is fulfilled if at least one of the three phase currents exceeds a parameterized threshold value (CIRC. BR. I>). The dropout is performed if all three phase currents fall below 95 % of the pickup threshold value. If the binary input of the circuit breaker auxiliary contact is inactive, only the current criterion is effective and the breaker failure protection cannot become active with a tripping signal if the current is below the CIRC.
  • Page 243: Setting Hints

    Breaker Failure Protection (ANSI 50BF) Device-internal protective functions I >TRIP HW model of relays U>>TRIP BO 12 binary output (Relay R12), potential-free Masking f<TRIP FNo. 01442 (via CFC) >int. start B/F FNo. 01441 >ext.start2 B/F 7002 TRIP INTERN ”0” FNo. 01471 BrkFailure TRIP FNo.
  • Page 244: Settings For Breaker Failure Protection

    Functions The pickup threshold 7003 CIRC. BR. I> setting of the current criterion refers to all three phases. The user must select a value ensuring that the function still picks up even for the lowest operating current to be expected. For this reason, the value should be set at least 10% below the minimum operating current.
  • Page 245: Information For The Breaker Failure Protection

    Breaker Failure Protection (ANSI 50BF) 2.34.2.2 Information for the Breaker Failure Protection F.No. Alarm Comments 01403 >BLOCK BkrFail >BLOCK breaker failure 01422 >Break. Contact >Breaker contacts 01423 >ext.start1 B/F >ext. start 1 breaker failure prot. 01441 >ext.start2 B/F >ext. start 2 breaker failure prot. 01442 >int.
  • Page 246: Inadvertent Energization (Ansi 50, 27)

    Functions 2.35 Inadvertent Energization (ANSI 50, 27) General The inadvertent energizing protection serves to limit damages by accidental connection of the standing or already started, but not yet synchronized generator by a fast actuation of the mains breaker. A connection to a standing machine corresponds to the connection to an inductivity.
  • Page 247: Setting Hints

    Inadvertent Energization (ANSI 50, 27) 7104 PICK UP T U1< no meas. quant. 7105 DROP OUT T U1< (operational condition 0) FNo. 05546 I.En. release 7103 RELEASE U1< & FNo. 05547 I.En. picked up Fuse Failure Tripping matrix & 7102 I STAGE FNo.
  • Page 248: Settings Of The Inadvertent Energizing Protection

    Functions Figure 2-112 illustrates the course of events during an unwanted connection in case of a machine standstill and, contrary to this, during a voltage collapse in case of a short circuit close to generator terminals. Start T U1 Pickup <...
  • Page 249 Inadvertent Energization (ANSI 50, 27) F.No. Alarm Comments 05543 I.En. ACTIVE Inadvert. Energ. prot. is ACTIVE 05546 I.En. release Release of the current stage 05547 I.En. picked up Inadvert. Energ. prot.: picked up 05548 I.En. TRIP Inadvert. Energ. prot.: TRIP 7UM62 Manual C53000-G1176-C149-3...
  • Page 250: Dc Voltage/Dc Current Protection (Ansi 59Ndc/51Ndc)

    Functions 2.36 DC Voltage/DC Current Protection (ANSI 59NDC/51NDC) General To detect DC voltages, DC currents and small AC quantities, the 7UM62 is equipped with a measuring transducer input (TD1) that can be used either for voltages (± 10 V) or currents (± 20 mA). Higher DC voltages are connected via an external voltage divider.
  • Page 251 DC Voltage/DC Current Protection (ANSI 59NDC/51NDC) Earth Fault If an earth fault occurs in the startup converter circuit, a current flows through all Detection in the earthed parts of the system because of the DC voltage. As earthing and neutral Startup Converter transformers have a lower ohmic resistance than voltage transformers, the thermal load is the highest on them.
  • Page 252: Setting Hints

    Functions 7204 U DC >< FNo. 05306 7205 I DC >< DC Prot.pick.up 7202 MEAS.METHOD 7203 DC >/< FNo. 05307 DC Prot. TRIP 7206 T DC mean mean value absolute Tripping Mean formation value & matrix or . U∼ I∼ r.m.s.
  • Page 253 DC Voltage/DC Current Protection (ANSI 59NDC/51NDC) The DC voltage/DC current protection can be set to operate for overvoltage or undervoltage (address 7203 DC >/<). Depending on the whether current or voltage input has been set at address 0295 Pickup Thresholds TRANSDUCER 1, one of the following parameters is available, whereas the other is masked out: −...
  • Page 254: Settings Of The Dc Voltage Protection

    Functions 2.36.2.1 Settings of the DC Voltage Protection Addr. Setting Title Setting Options Default Setting Comments 7201 DC PROTECTION DC Voltage/Current Protection Block relay for trip com- mands 7202 MEAS.METHOD Mean Value Mean Value Measurement Method (MEAN/ Root Mean Square RMS Values) 7203 DC >/<...
  • Page 255: Analog Outputs

    Analog Outputs 2.37 Analog Outputs 2.37.1 Functional Description Depending on the variant ordered, the 7UM62 machine protection can have up to four analog outputs (plug-in modules on ports B and D). The values to be transmitted via these interfaces have been specified during the configuration of the scope of protection functions (see Section 2.2).
  • Page 256: Settings Of The Analog Outputs

    Functions For analog output B1 at location”B” (port B1): At address 7301 20 mA (B1) = the percent value to be displayed at 20 mA, At address 7302 MIN VALUE (B1) the smallest valid value. For analog output B2 at location”B” (port B2): At address 7303 20 mA (B2) = the percent value to be displayed at 20 mA, At address 7304 MIN VALUE (B2) the smallest valid value.
  • Page 257: Measured Value Monitoring Functions

    Measured Value Monitoring Functions 2.38 Measured Value 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.
  • Page 258 Functions Measured Value In the current path, there are three input transformers each on side 1 and side 2; the Acquisition - digitized sum of the outputs of these on one side must be almost zero for generators Currents with isolated starpoint and earth-fault-free operation. A current circuit fault is detected | >...
  • Page 259: Software Monitoring

    Measured Value Monitoring Functions Note: Voltage sum (phase-earth) monitoring is only operative if an externally formed displacement voltage s connected to the residual voltage input of the relay and if this was communicated to the device via the parameter 0223 UE CONNECTION. Voltage sum (phase-earth) monitoring can operate properly only if the matching factor Uph / Udelta at address 0225A has been correctly configured (see Section 2.3.2).
  • Page 260 Functions Current Symmetry The currents fed in at the current inputs of side 1 and side 2 are monitored for symmetry. During normal system operation (i.e. the absence of a short-circuit fault), symmetry among the input currents is expected. This symmetry is checked by the device, using a quantity monitor.
  • Page 261: Fuse Failure Monitoring

    Measured Value Monitoring Functions Slope: BAL. FACTOR U BALANCE I LIMIT Figure 2-119 Voltage Symmetry Monitoring Current and To detect swapped phase connections in the voltage and current input circuits, the Voltage Phase phase sequence of the phase-to-phase measured voltages and the phase currents Sequence are checked by the monitoring.
  • Page 262 Functions If fuses are used instead of a secondary miniature circuit breaker with connected auxiliary contacts, then the fuse failure monitoring can detect problems in the voltage transformer secondary circuit. Of course, supervision of the miniature circuit breaker and the fuse failure monitor can be used at the same time. This function uses the current of side 2.
  • Page 263: Malfunction Responses Of The Monitoring Functions

    Measured Value Monitoring Functions Figure 2-120 illustrates the logic diagram of the measuring voltage failure detection feature. Voltage at U Input Depending on how U is connected, it may be necessary to block the voltage mea- surement of this input. A blocking can be generated with the CFC tool and linked by the annunciation “Fuse Failure“.
  • Page 264 Functions Table 2-13 Overview of Error Reactions by the Protection Relay Monitoring Possible Cause Reaction Annunciation Output Supply voltage failure External (power supply) Relay goes out of service all LEDs go dark ) drops internal (converter) Internal supply- Internal (converter) or Relay goes out of service ”ERROR”...
  • Page 265: Setting Hints

    Measured Value Monitoring Functions Table 2-13 Overview of Error Reactions by the Protection Relay Monitoring Possible Cause Reaction Annunciation Output ”Fail. Isym 2” Current symmetry External (power system or Annunciation as masked Side 2 current transformer) (FNo. 000572) Voltage sum Internal (measured value Annunciation ”Fail S U Ph-E”...
  • Page 266: Settings

    Functions Address 8108 SUM.thres. U determines the voltage threshold above which the summation voltage monitoring picks (see Figure 2-117) (absolute component, referred only to U ). The relative component for pickup of the summation voltage monitoring (Figure 2-117) is set at address 8109 SUM.Fact. U. Note: In the power system data 1, the voltage earth path and its matching factor Uph / Udelta have been specified.
  • Page 267: Information Of The Monitoring Functions

    Measured Value Monitoring Functions Addr. Setting Title Setting Options Default Setting Comments 8109 SUM.Fact. U 0.60..0.95; 0 0.75 Factor for Volt. Sum. Monitoring ΣI THRESHOLD S1 0.05..2.00 A 8110 0.10 A Summated Cur. Mon. Threshold on Side 1 ΣI FACTOR S1 8111 0.00..0.95 0.10...
  • Page 268: Sum Events Of The Monitoring Functions

    Functions F.No. Alarm Comments 00194 Error neutralCT Error: Neutral CT different from MLFB 00212 Err. TD1 jumper Err: TD1 jumper different from setting 00213 Err. TD2 jumper Err: TD2 jumper different from setting 00214 Err. TD3 jumper Err: TD3 jumper different from setting 00191 Error Offset Error: Offset 00264 Fail: RTD-Box 1...
  • Page 269 Measured Value Monitoring Functions Table 2-14 Sum Events Sum events Content Designation Designation Meaning 0210 Err1A/ 5AwrongS1 0211 Err1A/ 5AwrongS2 0194 Error neutralCT 0212 Err. TD1 Jumper 0213 Err. TD2 Jumper 0181 Failure measured val. 0214 Err. TD3 Jumper 0140 Alarm sum event (Live status contace drops out/ 0190 Error BG0 = C–CPU–2...
  • Page 270: Trip Circuit Supervision

    Functions 2.39 Trip Circuit Supervision 2.39.1 Functional Description The Multifunctional Protection 7UM62 is equipped with an integrated trip circuit monitor. Depending on the number of available binary inputs, monitoring with one or two binary inputs can be selected. If the configuration of the binary inputs needed for this does not match the selected monitoring type, then a message to this effect (”TripC ProgFail”) is sent.
  • Page 271 Trip Circuit Supervision Table 2-15 Condition Table for Binary Inputs, depending on RTC and CB Position Trip Contact Circuit AuxCont 1 AuxCont 2 BI 1 BI 2 Breaker Open CLOSED Closed Open Open OPEN Open Closed Closed Closed CLOSED Open Closed OPEN Open...
  • Page 272 Functions Depending on the conditions of the trip contact and the circuit breaker, the binary inputs are activated (logical condition ”H” in Table 2-16), or not activated (logical condition ”L”). Table 2-16 Condition Table for Binary Inputs, Depending on RTC and CB Position Trip Contact Circuit AuxCont 1...
  • Page 273 Trip Circuit Supervision 7UM62 FNo. 06852 >TripC trip rel 7UM62 Legend: — Relay trip contact — Circuit breaker — Circuit breaker trip coil AuxCont1 — Circuit breaker auxiliary contact (NO contact) AuxCont2 — Circuit breaker auxiliary contact (NC contact) — Equivalent resistor AuxCont 2 —...
  • Page 274: Setting Hints

    Functions 0182 Trip Cir. Sup. Disabled with 2 Bin. Inp. ”1” with 1 Bin. Inp. & FNo. 06864 FNo. & TripC ProgFail 06852 Configured >TripC trip rel & FNo. 06853 Configured >TripC brk rel. FNo. 06861 TripC OFF 8201 TRIP Cir. SUP. FNo.
  • Page 275 Trip Circuit Supervision contact (AuxCont2), to facilitate the detection of a malfunction when the circuit breaker auxiliary contact (AuxCont1) open and the trip contact has dropped out (see Figure 2- 124). This resistor must be sized such that the circuit breaker trip coil is no longer energized when the circuit breaker is open (which means AuxCont1 is open and AuxCont2 is closed).
  • Page 276: Settings For The Trip Circuit Supervision

    Functions æ 110 V 19 V ö – 500 Ω --------------------------------- - 50.1 kΩ – è ø 1.8 mA æ 110 V 2 V ö – 500 Ω ⋅ ----------------------------- - 27 kΩ è ø ------------------------------- - 38.6 kΩ The closest standard value of 39 kΩ is selected; the power is: æ...
  • Page 277: Threshold Supervision

    Threshold Supervision 2.40 Threshold Supervision General This function monitors the thresholds of selected measured values, checking whether the values exceed or drop below these thresholds. The processing speed of this func- tion is so high that it can be used for protection applications. The necessary logical can be implemented by means of CFC.
  • Page 278 Functions Table 2-17 Measured Values Measured Value Scaling Comments ⋅ 100 % I0/I The zero sequence current is determined from N,S2,sec (Zero sequence the phase currents on the basis of the definition (normalized with addr. 212) current system equation for symmetrical components. The side 2) calculation is perfomed once per cycle.
  • Page 279: Setting Hints

    Threshold Supervision Disabled Delta Pa 8502 THRESHOLD MV1> 7960 Meas. Value1> 8501 MEAS. VALUE 1> Disabled Delta Pa 8512 THRESHOLD MV6< 7965 Meas. Value6< 8511 MEAS. VALUE 6< Figure 2-127 Logic Diagram of the Threshold Supervision The figure shows that the measured values can be freely allocated to the threshold supervision blocks.
  • Page 280: Settings Of The Threshold Supervision

    Functions The measured values for power P, Q and ∆P, as well as the phase angle, can be either positive or negative. Where the monitoring is for a negative threshold value, the num- ber line definition applies (–10 is smaller than –5). Example: The measured quantity P (active power) is allocated to MV1>...
  • Page 281 Threshold Supervision Addr. Setting Title Setting Options Default Setting Comments 8503 MEAS. VALUE 2< Disabled Disabled Measured Value for Threshold Active Power P MV2< Reactive Power Q Change of Active Power Delta P Positive Sequence Voltage Negative Sequence Voltage Zero Sequence Current I0 Positive Sequence Current Negative Sequence Current Power Angle PHI...
  • Page 282: Information For The Threshold Supervision

    Functions Addr. Setting Title Setting Options Default Setting Comments 8509 MEAS. VALUE 5> Disabled Disabled Measured Value for Threshold Active Power P MV5> Reactive Power Q Change of Active Power Delta P Positive Sequence Voltage Negative Sequence Voltage Zero Sequence Current I0 Positive Sequence Current Negative Sequence Current Power Angle PHI...
  • Page 283: External Trip Coupling

    External Trip Coupling 2.41 External Trip Coupling 2.41.1 Functional Description Up to four desired signal from external protection or supervision units can be incorporated into the processing of 7UM62. The signals are coupled as ”External signal” via binary inputs. Like the internal protection and supervision signals, they can be annunciated, time delayed, transmitted to the trip matrix, and blocked.
  • Page 284: Settings

    Functions 2.41.2.1 Settings Addr. Setting Title Setting Options Default Setting Comments 8601 EXTERN TRIP 1 External Trip Function 1 Block relay for trip com- mands 0.00..60.00 sec; ∞ 8602 T DELAY 1.00 sec Ext. Trip 1 Time Delay 8701 EXTERN TRIP 2 External Trip Function 2 Block relay for trip com- mands...
  • Page 285 External Trip Coupling F.No. Alarm Comments 04571 Ext 3 OFF External trip 3 is switched OFF 04572 Ext 3 BLOCKED External trip 3 is BLOCKED 04573 Ext 3 ACTIVE External trip 3 is ACTIVE 04576 Ext 3 picked up External trip 3: General picked up 04577 Ext 3 Gen.TRP External trip 3: General TRIP 04583 >BLOCK Ext 4...
  • Page 286: Temperature Detection By Thermoboxes

    Functions 2.42 Temperature Detection by Thermoboxes Up to 2 thermoboxes with a total of 12 measuring points can be used for temperature detection and evaluated by the protection device. They are particularly useful for mon- itoring the thermal condition of motors, generators and transformers. In rotating ma- chines, they also check the bearing temperatures for violation of limit values.
  • Page 287: Setting Hints

    Temperature Detection by Thermoboxes 9011A RTD 1 TYPE 9013 RTD 1 STAGE 1 Temperature Non-linear- RTD 1 St.1 p.up calculation ized values 14112 FNo. 9015 RTD 1 STAGE 2 RTD 1 St.2 p.up 14113 FNo. Monitoring Fail: RTD 1 14111 FNo.
  • Page 288 Functions The location RTD1 is communicated to the device at address 9012A RTD 1 LOCA- TION. Setting options are Oil, Ambient, Winding, Bearing and Other. This set- ® ting is only possible with DIGSI 4 under “Advanced Parameters”. You can also set an alarm temperature and a tripping temperature. Depending on the temperature unit selected in the power system data (Section 2.3 at address 0276 TEMP.
  • Page 289: Settings Of The Temperature Detection Function

    Temperature Detection by Thermoboxes 2.42.2.1 Settings of the Temperature Detection Function Addr. Setting Title Setting Options Default Setting Comments 9011A RTD 1 TYPE not connected Pt 100 Ohm RTD 1: Type Pt 100 Ohm Ni 120 Ohm Ni 100 Ohm 9012A RTD 1 LOCATION Winding...
  • Page 290 Functions Addr. Setting Title Setting Options Default Setting Comments -50..250 °C; ∞ 120 °C 9035 RTD 3 STAGE 2 RTD 3: Temperature Stage 2 Pickup -58..482 °F; ∞ 248 °F 9036 RTD 3 STAGE 2 RTD 3: Temperature Stage 2 Pickup 9041A RTD 4 TYPE...
  • Page 291 Temperature Detection by Thermoboxes Addr. Setting Title Setting Options Default Setting Comments -50..250 °C; ∞ 100 °C 9063 RTD 6 STAGE 1 RTD 6: Temperature Stage 1 Pickup -58..482 °F; ∞ 212 °F 9064 RTD 6 STAGE 1 RTD 6: Temperature Stage 1 Pickup -50..250 °C;...
  • Page 292 Functions Addr. Setting Title Setting Options Default Setting Comments 9092A RTD 9 LOCATION Other RTD 9: Location Ambient Winding Bearing Other -50..250 °C; ∞ 100 °C 9093 RTD 9 STAGE 1 RTD 9: Temperature Stage 1 Pickup -58..482 °F; ∞ 212 °F 9094 RTD 9 STAGE 1...
  • Page 293: Information For The Temperature Detection Function

    Temperature Detection by Thermoboxes Addr. Setting Title Setting Options Default Setting Comments 9121A RTD12 TYPE not connected not connected RTD12: Type Pt 100 Ohm Ni 120 Ohm Ni 100 Ohm 9122A RTD12 LOCATION Other RTD12: Location Ambient Winding Bearing Other -50..250 °C;...
  • Page 294 Functions F.No. Alarm Comments 14172 RTD 7 St.1 p.up RTD 7 Temperature stage 1 picked up 14173 RTD 7 St.2 p.up RTD 7 Temperature stage 2 picked up 14181 Fail: RTD 8 Fail: RTD 8 (broken wire/shorted) 14182 RTD 8 St.1 p.up RTD 8 Temperature stage 1 picked up 14183 RTD 8 St.2 p.up RTD 8 Temperature stage 2 picked up...
  • Page 295: Inversion Of Phase Sequence (Phase Sequence Reversal)

    Inversion of Phase Sequence (Phase Sequence Reversal) 2.43 Inversion of Phase Sequence (Phase Sequence Reversal) 2.43.1 Functional Description General A phase rotation feature via binary input and parameter is implemented in the 7UM62, thus ensuring that all protective and monitoring functions operate correctly when the phase rotation is reversed.
  • Page 296: Setting Hint

    Functions Influence on The swapping of phases directly impacts the calculation of positive and negative Protective sequence quantities, as well as phase-to-phase voltages via the subtraction of one Functions phase-to-ground voltage from another. Therefore, this function is vital so that phase detection messages, fault values, and operating measurement values are not falsified.
  • Page 297: Protection Function Logic

    Protection Function Logic 2.44 Protection Function Logic The function logic is the heart of the device. It coordinates the sequence of both the protective and auxiliary functions, processes functional decisions, and processes data received from the system. In particular, the function logic is responsible for the following: •...
  • Page 298: Processing Tripping Logic

    Functions 2.44.2 Processing Tripping Logic 2.44.2.1 Functional Description General trip The tripping signals for all protective functions are connected by ”OR” and generate a message ”General TRIP” indicating that the device has initiated a trip signal. This annunciation, like individual trip indications, can be allocated to an LED or an output relay.
  • Page 299: Settings For The Tripping Logic

    Protection Function Logic that can initiate trip signals, as well as for trip signals that are initiated using the device function controller. Addr. Parameter Setting Default Settings Comment 0280 TMin TRIP CMD. 0.01 .. 32.00 s 0.15 s Minimum duration of the trip command 2.44.3 Fault Display on the LEDs/LCD 2.44.3.1 Principle of Function...
  • Page 300: Statistical Counters

    Functions 2.44.4 Statistical Counters 2.44.4.1 Functional Description Number of Trips The number of trips initiated by the 7UM62 is counted, as long as the position of the circuit breaker is monitored via breaker auxiliary contacts and binary inputs. To use this function, the internal pulse counter ”Trip Count”...
  • Page 301: Information For The Statistical Counter

    Protection Function Logic 2.44.4.3 Information for the Statistical Counter F.No. Alarm Comments 00003 >Time Synch >Synchronize Internal Real Time Clock 00005 >Reset LED >Reset LED 00060 Reset LED Reset LED 00015 >Test mode >Test mode Test mode Test mode 00016 >DataStop >Stop data transmission DataStop Stop data transmission...
  • Page 302: Auxiliary Functions

    Functions 2.45 Auxiliary Functions The auxiliary functions of the 7UM62 relay include: • processing of messages, • processing of operational measured values, • storage of fault record data. • Commissioning aids. 2.45.1 Processing of Messages After the occurrence of a system fault, data regarding the response of the protective relay and the measured quantities should be saved for future analysis.
  • Page 303: Operational Annunciations

    Auxiliary Functions annunciations have been acknowledged, the initial display is shown again. Acknowledgement can be performed by pressing the LED button on the front panel. The relay is also equipped with several event buffers, for operational messages, circuit breaker statistics, etc., which are protected against loss of the auxiliary voltage by a buffer battery.
  • Page 304: General Interrogation

    Functions U0> picked up Protective Function that picked up first; S/E/F TRIP Protective Function that dropped out last; PU Time 440ms Running time from general pickup to dropout; TRIP Time 301ms Running time from general pickup to the first trip command Figure 2-133 Display of Spontaneous Messages on the Device Front Retrieved The messages for the last eight network faults can be retrieved.
  • Page 305: Measurements

    Auxiliary Functions 2.45.2 Measurements Display of A series of measured values and the values derived from them are constantly Measured Values available for call up on site, or for data transfer (See Table 2-19, as well as the following list). The operational measured values listed in Table 2-19 can be read out as secondary, primary or percent values.
  • Page 306 Functions Table 2-19 Conversion Formulae between Secondary Values and Primary/Percentage Values Measured Val. Secondary Primary measured: E sec. E prim. ⋅ ⋅ FACTOR UE --------------------------------------------------------------------- - 100 U E sec ⁄ UN–GEN PRIMARY calculated: UN – VT PRIMARY ⋅ ------------------------------------------------------------- - U E sec UN –...
  • Page 307 Auxiliary Functions where Parameter Address Parameter Address Unom PRIMARY 0221 0205 FACTOR IEE1 Unom SECONDARY 0222 0213 FACTOR IEE2 IN-PRI I-SIDE1 0202 0224 FACTOR UE IN-SEC I-SIDE1 0203 0251 UN GEN/MOTOR IN-PRI I-SIDE2 0211 0252 SN GEN/MOTOR IN-SEC I-SIDE2 0212 0225A Uph / Udelta UN-PRI SIDE 1...
  • Page 308: Oscillographic Fault Recording (Waveform Capture)

    Functions − U/f th. Overtemperature caused by an overexcitation, in % of the tripping overtemperature, − Coolant temperature (or ambient temperature) In addition, the following may be available: − Minimum and maximum values for the positive-sequence components I Min/Max Values 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 309: Date And Time Stamping

    Auxiliary Functions and u L1 S1 L2 S1 L3 S1 L1 S2 L2 S2 L3 S2 or i of the three measuring transducers are sampled at intervals of 1.25 ms (for 50 Hz) or 1.04 ms (for 60 Hz), and stored in a circulating buffer (16 samples per cycle).
  • Page 310: Commissioning Aids

    Functions Here you may select the time standard for internal time stamping by selecting from the following modes: Operating Mode Explanations Internal Internal synchronization using RTC (pre-set) IEC 60870–5–103 External synchronization using the system interface and the IEC 60870–5–103 protocol PROFIBUS DP External synchronization using PROFIBUS interface IRIG B Time signal External synchronization using IRIG B...
  • Page 311: Testing The States Of The Binary Inputs/Outputs

    Auxiliary Functions A dialog box displays the texts of all annunciations that have been masked to the system interface in the matrix. In another column of the dialog box you can specify a value for the annunciations that you want to test (e.g. coming/ going) to generate an annunciation as soon as you have entered password no.
  • Page 312: Settings For Oscillographic Fault Recording

    Functions SETTINGS menu. Waveform capture makes a distinction between the trigger for an oscillographic record and the criterion to save the record (address 0401 WAVEFORMTRIGGER). Normally the trigger is the pickup of a protective element, i.e. when a protective element picks up the time is 0. The criterion for saving can be the pickup as well (Save w.
  • Page 313: Information For Minimum And Maximum Values

    Auxiliary Functions F.No. Alarm Comments 00203 Wave. deleted Waveform data deleted FltRecSta Fault Recording Start 2.45.6.3 Information for Minimum and Maximum Values F.No. Alarm Comments 00396 >I1 MiMaReset >I1 MIN/MAX Buffer Reset 00399 >U1 MiMa Reset >U1 MIN/MAX Buffer Reset 00400 >P MiMa Reset >P MIN/MAX Buffer Reset 00402 >Q MiMa Reset...
  • Page 314: Breaker Control

    Functions 2.46 Breaker Control General In addition to the protective functions described thus far, a control command process ® is integrated in the SIPROTEC 7UM62 to coordinate the operation of circuit breakers and other equipment in the power system. Control commands can originate from four command sources: −...
  • Page 315: Types Of Commands

    Breaker Control ® Operation using Control commands for switchgear can also be entered in DIGSI 4 with a PC that is ® DIGSI connected to the operator interface. The procedure to do so is described in the ® SIPROTEC 4 System Manual (Control of Switchgear). Operation using the Control commands for switchgear can also be entered through the serial SCADA SCADA Interface...
  • Page 316: Interlocking

    Functions • Command Entry (e.g. using the keypad on the local user interface of the device) Check Sequence − Check password → Access rights − Check Switching Mode (interlocking activated/deactivated→ Selection of Deactivated Interlocking Recognition • User configurable Interlocking checks −...
  • Page 317: Interlocked / Non-Interlocked Switching

    Breaker Control The extent of the interlocking checks is determined by the configuration of the relay. Circuit breakers (or other equipment) that require system interlocking in a central control system (Substation Controller) must be configured in their specific commands object properties box for the specific control device. For all commands, operation with interlocking (normal mode) or without interlocking (test mode) can be selected: −...
  • Page 318 Functions EVENT LOG --------------------- 19.06.01 11:52:05,625 CO+ close 19.06.01 11:52:06,134 FB+ close Figure 2-134 Example of an Operational Annunciation for Switching Circuit Breaker Q0 Standard The following is a list of Standard Interlocking Conditions that can be selected for each Interlocking controllable device.
  • Page 319 Breaker Control Switching Authority Switching Mode Device with source of command = ON/OFF LOCAL Local & REMOTE & Local DIGSI AUTO & & Rem. Switching Authority (LOCAL/REMOTE) DIGSI & DIGSI Switch Authority DIGSI: Rem. & Switch mode LOCAL: Non-interlocked (interlocked/non-interl.) SCHED.
  • Page 320 Functions ® Figure 2-136 DIGSI 4 Dialog Box for Setting the Interlocking Conditions The display shows the configured interlocking reasons. The are marked by letters ex- plained in the following Table 2-21: Table 2-21 Interlocking Commands Interlocking Commands Abbreviation Message Switching Authority System Interlock Zone Controlled...
  • Page 321 Breaker Control Control Logic using For Zone Controlled (field interlocking), control logic can be developed, using the CFC. Via specific release conditions the information “released” or “zone controlled” is available. Switching Switching authority configures the relay to perform Local/Remote Supervisory Authority functions.
  • Page 322 Functions In detail, the following interlocking logic is derived when using default configuration settings: Current Switching Switching Command Issued Command Issued Command Issued from Authority Status Authority Locally from SAS or SCADA DIGSI DIGSI LOCAL Not checked Allowed Interlocked *2) Interlocked - switching authority ”DIGSI not...
  • Page 323 Breaker Control Interlocking conditions can be programmed separately, for each switching device, for device control CLOSE and/or OPEN. Processing of the status of the release condition for an operation switching device can be based on information acquired: − directly, using a single point or double point indication (binary inputs), key-switch, or internal indication (marking), or −...
  • Page 324: Recording And Acknowledgement Of Commands

    Functions 2.46.4 Recording and Acknowledgement of Commands 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 message cause indication. The messag- es are entered in the event list.
  • Page 325: Installation And Commissioning

    Installation and Commissioning This section is primarily for personnel who are experienced in installing, testing, and commissioning protective and control systems, and are familiar with applicable safety rules, safety regulations, and the operation of a power system. Installation of the 7UM62 is described in this section. Connections for the device are discussed.
  • Page 326: Installation And Connections

    3 Installation and Commissioning Installation and Connections Warning! ® Trouble free and safe use of this SIPROTEC 4 device depends on proper transport, storage, installation, and application of the device according to the warnings in this instruction manual. Of particular importance are the general installation and safety regulations for work in a high-voltage environment (for example, ANSI, IEC, EN, DIN, or other national and international regulations.) These regulations must be observed.
  • Page 327 3.1 Installation and Connections Elongated SIPROTEC Holes SIEMENS ERROR 7UM621 MAIN MENU 01/04 Annunciations Measured values MENU ENTER Annunciations Measured values Alarm Figure 3-1 Panel Mounting of a 7UM621 with Size Housing Elongated Holes SIPROTEC SIEMENS ERROR 7UM622 MAIN MENU...
  • Page 328 Furthermore, the cross-sectional area of the ground wire must be at least AWG 13. Mounting Bracket SIPROTEC SIEMENS ERROR 7UM621 TRIP PICKUP...
  • Page 329 3.1 Installation and Connections SIPROTEC SIEMENS ERROR 7UM622 MAIN MENU 01/04 Annunciations Measured values MENU ENTER Annunciations Masured values Alarm Figure 3-4 Installing a 7UM621 ( Size Housing) in a Rack or Cubicle Connect the plug terminals and/or the threaded terminals on the rear side of the device according to the elementary diagram for the rack.
  • Page 330: Connections

    3 Installation and Commissioning 3.1.2 Connections Overview diagrams are shown in Appendix A.2. CT and VT connections for a 7UM62 are shown in the Appendix, Section A.4. Make sure that the settings of the Power System Data 1 (Section 2.3) match the connections. Currents/Voltages Overview diagrams are shown in the Appendix.
  • Page 331 3.1 Installation and Connections The resulting factor between the secondary windings is 3/√3 = 1.73. For situations where the displacement voltage is measured by the device and other types of voltage transformer connections are utilized, the setting of address 0225A should be modified accordingly.
  • Page 332: Hardware Modifications

    3 Installation and Commissioning Changing Setting If binary inputs are used to switch setting groups, please observe the following: Groups with Binary • If the configuration is performed from the operator panel or using DIGSI ® 4, the Inputs address 0302 CHANGE must be set to the option Binary Input. •...
  • Page 333 3.1 Installation and Connections Nominal Currents The rating of the current input transformers of the device can be changed to 1 A or 5 A with jumper settings that determine the secondary loading of the transformers. When the device is delivered, these jumpers are set according to the name-plate sticker. The physical arrangements of these jumpers that correspond to the different current ratings are described below, Subsection 3.1.3.3 “C-I/O–2 Input/Output Board”...
  • Page 334: Disassembling The Device

    3 Installation and Commissioning Caution! If the jumpers are set to “current” input, connection of a voltage may destroy the board! For measuring transducer TD 3 (detects e.g. the excitation voltage for the underexcitation protection) an analog low-pass can be activated or deactivated; the choice is made by jumpers.
  • Page 335 3.1 Installation and Connections Caution! Jumper-setting changes that affect nominal values of the device render the ordering number and the corresponding nominal values on the nameplate sticker invalid. If such changes are necessary, the changes should be clearly and fully noted on the device.
  • Page 336 3 Installation and Commissioning C-CPU-2 Processor p.c.b. C-I/O-2 Input/Output p.c.b. C-I/O-6 Input/Output p.c.b. Slot 5 Slot 19 Slot 33 BI1 to BI6 and Binary Inputs (BI) Figure 3-5 7UM621: Front View ( Size Housing) after Removing the Front Cover (Simplified and Reduced) C-CPU-2 Processor p.c.b.
  • Page 337: Switching Elements On Printed Circuit Boards

    3.1 Installation and Connections 3.1.3.3 Switching Elements on Printed Circuit Boards Processor Printed The layout of the p.c.b for the C–CPU–2 processor module is shown in Figure 3-7. Circuit Board Check the provided nominal voltage of the integrated power supply according to Table C–CPU–2 3-1, the non-energized position of the live status contact (jumper X40 according to Table 3-2), the selected pickup voltages of the binary inputs BI1 through BI5 according...
  • Page 338 3 Installation and Commissioning Table 3-1 Jumper Settings for the Nominal Voltage of the Integrated Power Supply on the C–CPU–2 Board Jumper Nominal Voltage 60/110/125 VDC 110/125/220/250 VDC 24/48 VDC 115 VAC 1–2 2–3 Jumpers X51, 1–2 and 3-4 2–3 X52, X53 and X55 1–2 2–3...
  • Page 339 3.1 Installation and Connections With jumper X111, CTS is activated which is necessary for the communication with the modem. Table 3-5 Jumper setting of CTS (Clear-To-Send) on the processor printed circuit board C-CPU-2 Jumper /CTS of interface RS232 /CTS controlled by /RTS X111 1–2 2–3 *)
  • Page 340 3 Installation and Commissioning +5 V 390 Ω A/A´ 220 Ω B/B´ 390 Ω Figure 3-8 Terminating Resistors (External) 7UM62 Manual C53000-G1176-C149-3...
  • Page 341 3.1 Installation and Connections C–I/O–1 Input/ The layout of the p.c.b for the C–I/O–1 board is shown in Figure 3-9. Output Board (AD2) (AD1) (AD0) Figure 3-9 Jumpers on the C–I/O–1 Board for the Binary Inputs BI8 to BI15 (Simplified) 7UM62 Manual C53000-G1176-C149-3...
  • Page 342 3 Installation and Commissioning In the version 7UM622, the contact type can be changed for one specific relay (BO13) from normally open to normally closed (see overview diagrams in section A.2 of the Appendix). Table 3-7 Jumper Settings for the Contact of Relay R13 (Binary Output BO 13) Jumper Non-Energized Position Open Non-Energized Position Closed Factory Setting...
  • Page 343 3.1 Installation and Connections C–I/O–2 Input/ The layout of the p.c.b for the C–I/O–2 board is shown in Figure 3-10. Output Board (AD0) (AD1) (AD2) Figure 3-10 C–I/O–2 board Showing the Jumpers Settings to be Checked For one specific relay (BO 6) the contact type can be changed from normally open to normally closed (see overview diagrams in section A.2 of the Appendix): Table 3-10 Jumper Settings for Choosing the Contact Type of Binary Output BO 6 on the...
  • Page 344 3 Installation and Commissioning The rated current settings of the input current transformers are checked on the C–I/O–2 board. All jumpers must be in the same position, i.e. there must be one jumper each (X61 to X64) for each of the input transformers, and the common jumper X60.
  • Page 345 3.1 Installation and Connections C–I/O–6 Input/ The layout of the p.c.b for the C–I/O–6 board is shown in Figure 3-11. Output Board (AD2) (AD1) (AD0) Figure 3-11 C–I/O–6 board Showing the Jumpers Settings to be Checked Factory Jumper Settings for the Pickup Voltages of the Binary Inputs Table 3-12 BI 6 and BI 7 on the C–I/O–6 board Binary Input...
  • Page 346 3 Installation and Commissioning For two specific relays (BO 11 and BO 12) the contact type can be changed from normally open to normally closed (see overview diagrams in section A.2 of the Appendix): Table 3-13 Jumper Settings for Choosing the Contact Type of Binary Outputs BO 11 and BO 12 on the C–I/O–6 Board Binary Output Jumper...
  • Page 347 3.1 Installation and Connections Note: The jumper settings must correspond to the mode set at addresses 0295, 0296 (volt- age or current input) and 0297 (with/without filter). If they do not, the device is blocked and outputs an alarm. After any changes to the jumper settings, you should therefore ®...
  • Page 348: Interface Modules

    3 Installation and Commissioning 3.1.3.4 Interface Modules Exchanging The interface modules are located on the C–CPU–2 board (Œ in Figure 3-5 and 3-6). Interface Modules Figure 3-12 shows the p.c.b. with the location of the modules. Mounting position (rear of housing) Analog output System interface or analog output...
  • Page 349 3.1 Installation and Connections Table 3-18 Exchange Interface Modules Interface Location Exchange Module RS232 RS485 FO 820 nm Profibus DP RS485 System Interface Profibus DP twin ring Modbus RS485 Modbus 820 nm DNP3.0, RS485 DNP3.0, 820 nm Analog Interface 2 x 0 to 20 mA RS232 Service InterfaceT RS485...
  • Page 350 3 Installation and Commissioning Terminating Resistors Jumper Connected Disconnected 2–3 1–2 2–3 1–2 Factory Set C53207- A324-B180 Figure 3-13 Location of the Jumpers for Configuring the Terminating Resistors of the Interface C53207-A322- 2 3 4 B100 B101 Terminating Resistors Jumper Connected Disconnected 1–2...
  • Page 351: To Reassemble The Device

    3.1 Installation and Connections Analog Output The AN20 analog output board (see Figure 3-15) has 2 floating channels with a current range of 0 to 20 mA (unipolar, max. 350 Ω). The location on the C–CPU–2 board is “B” or/and “D” depending on the variant ordered (see Figure 3-12).
  • Page 352: Checking Connections And System (Plant) Integration

    3 Installation and Commissioning Checking Connections and System (Plant) Integration 3.2.1 Checking the Data Connections of Serial Interfaces The following tables shows the pin-assignments for the various serial interfaces and for the time synchronization interface of the device. Operator Interface When the recommended communication cable is used, correct connection between ®...
  • Page 353 3.2 Checking Connections and System (Plant) Integration Table 3-20 Installation of the D-Subminiature Ports Pin No. PC Interface at RS 232 RS 485 Profibus DP Slave, RS 485 DNP3.0, Modbus, RS485 Front Screen (with screen ends electrically connected) – – –...
  • Page 354: Checking The Device Connections

    3 Installation and Commissioning Time Either 5 VDC, 12 VDC or 24 VDC time synchronization signals can be processed if the Synchronization connections are made as indicated in Table 3-22 Interface Table 3-22 Pin Assignments for the D-Subminiature Port of the Time Synchronization Interface Pin No.
  • Page 355 3.2 Checking Connections and System (Plant) Integration Note: If a redundant supply is used, there must be a permanent, i.e. uninterruptible connection between the minus polarity connectors of system 1 and system 2 of the d.c. voltage supply (no switching device, no fuse), because otherwise there is a risk of voltage doubling in case of a double earth fault.
  • Page 356 3 Installation and Commissioning Secondary Test of A test set with 6 current outputs is recommended for secondary testing. This section the Differential gives you hints how to proceed if less current sources are available. The test current Protection can be injected individually for each winding, thus simulating each time a transformer fault with single-ended infeed.
  • Page 357 3.2 Checking Connections and System (Plant) Integration Table 3-23 Correction Factor k Depending on Vector Group and Fault Type Type of Fault Reference Winding Even VG Numeral Odd VG Numeral (High Voltage Side) (0, 2, 4,6, 8, 10) (1, 3, 5, 7, 9, 11) Three-phase √3/2 = 0.866 Two-Phase...
  • Page 358 3 Installation and Commissioning When testing this winding, the pickup value (referred to the rated relay current) will amount to: 1316 A N Transf N Transf ⋅ ⋅ ⋅ ⋅ ------------------ - k ------------------- - --------------------------------- k IDIFF> IDIFF> 1500 A N Relay N CT (primary) ⋅...
  • Page 359: Checking The Integration In The Plant

    3.2 Checking Connections and System (Plant) Integration 3.2.3 Checking the Integration in the Plant 3.2.3.1 General Hints Warning! The following procedures are carried out with dangerous voltages present. Therefore, only qualified people who are familiar with and adhere to the safety procedures and precautionary measures shall perform the procedures.
  • Page 360 3 Installation and Commissioning Inventory of the In order to check the protection configuration (masking and setting values) for Technical Plant conformity with the plant requirements, it is necessary to make an inventory of the Data technical data for the individual components of the primary plant. These components include, among others, the generator or motor, the unit transformer (step-up transformer) and the voltage and current transformers.
  • Page 361 3.2 Checking Connections and System (Plant) Integration When the voltage on the binary input connected to this auxiliary contact is removed, the message “>FAIL:Feeder VT ON” should appear in the Event Log. When the voltage is restored, the message “>FAIL:Feeder VT OFF” should occur. If one of these messages does not appear, then the connections and the configuration settings should be checked.
  • Page 362: Commissioning

    3 Installation and Commissioning Commissioning Warning! When operating an electrical device, certain parts of the device inevitably have dangerous voltages. Severe personal injury or property damage can result if the device is not handled properly. Only qualified people shall work on and around this device after becoming 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 363: Test Mode And Blocking Data Transmission

    3.3 Commissioning 3.3.1 Test Mode and Blocking Data Transmission ® If the SIPROTEC 4 device is connected to a central or master computer system via the system interface, then the information that is transmitted can be influenced (see Table “Protocol-dependent functions” in the Appendix A.13). If Test mode is set ON, then a message sent by the device to the master system has an additional test bit.
  • Page 364 3 Installation and Commissioning Figure 3-17 Dialog Box: Generate indications Following the first operation of one of the keys in the column Action a prompt for the Changing the Operating State entry of password No. 6 (for hardware test menus) appears. After correct entry of the password, individual messages can be initiated.
  • Page 365: Checking The Binary Inputs And Outputs

    3.3 Commissioning 3.3.3 Checking the Binary Inputs and Outputs ® Preliminary Notes The binary inputs, outputs, and LEDs of a SIPROTEC 4 device can be individually ® and precisely controlled in DIGSI 4. This feature can be used, for example, to verify control wiring from the device to substation equipment (operational checks), during commissioning.
  • Page 366 3 Installation and Commissioning Figure 3-18 Dialog Box for Hardware Test — Example Changing The displays of the intended conditions are shown as switching fields. To change the Hardware condition of a hardware component, click on the associated switching field in the Schedule column.
  • Page 367: Testing The Breaker Failure Scheme

    3.3 Commissioning Check the reaction in the Status column of the dialog box. To do so, the dialog box must be updated. This is described below under the side title “Updating the display”. If you want to check the effects of a binary input signal without actually performing switching operations in the plant, you can do so by activating individual binary inputs by means of the Hardware Test function.
  • Page 368: Checking The Analog Outputs

    3 Installation and Commissioning 3.3.5 Checking the Analog Outputs 7UM62 can be equipped with up to 2x2 analog outputs. Where analog outputs are provided, and used, their functioning should be tested. Since various types of measured values or events can be output, the test to be performed depends on the type of values for which it will be used.
  • Page 369 3.3 Commissioning X COUPLING = yyy Ω (address 6006) correspond with the above values. Remove earth fault bridge. An earth fault is now fitted as described above via a resistor of the warning resistance, (RE< WARN, address 6002, 10 kΩ when delivered from factory. The earth resistance calculated by the unit can be read out under the Operational Measured Values as Rotor.
  • Page 370: Rotor Earth Fault Protection (1 To 3 Hz)

    3 Installation and Commissioning After the completion of the test, check that all provisional measures for testing have been reversed: − Earthing bridge or resistor has been removed, − Measurement circuit has been closed, − Controller unit connected to its operational supply a.c. voltage (refer also connection diagram in Figure 2-95 in Section 2.25.1).
  • Page 371 3.3 Commissioning Figure 3-20 Test Fault Record After this the fault resistors for the warning and the trip stage are installed, and the op- erational measured value Rearth is read out. The two measured values are the basis for the setting values of the warning stage (address 6102 RE< WARN) and the trip stage (address 6104 RE<<...
  • Page 372: Checking The 100-% Stator Earth Fault Protection

    3 Installation and Commissioning 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 as described in Section 3.4.9.2. 3.3.8 Checking the 100–% Stator Earth Fault Protection The 100-% stator earth fault protection can be checked with the machine at stand-still, because the measuring principle for the earth resistance calculation is independent of whether the machine is at stand-still, rotating or excited.
  • Page 373 3.3 Commissioning 90° must be determined and set as PHI I SEF = –90° – ϕ SES. If the value displayed is, for example, ϕ SES = –75°, PHI I SEF = –15° must be set at address 5309. This will change the measured value to approx.
  • Page 374: Checking The Dc Voltage/Dc Current Circuit

    3 Installation and Commissioning sues a pickup indication, and, after T SEF TRIP address 5305 (1 s on delivery), a trip indication. Remove the test resistor. If the indication „20 Hz voltage missing” to be received from the 20 Hz generator is marshalled to one of the binary inputs, and the delivery setting of this input has been changed for this purpose, the binary input can be checked as well.
  • Page 375: Trip/Close Tests For Primary Equipment

    3.3 Commissioning 3.3.10 Trip/Close Tests for Primary Equipment Control by Local At the end of commissioning, actual 7UM62 tripping and closing should be verified for Command all the relevant circuit breakers and primary switching devices, unless this has been done already in connection with the Hardware Test described in Section 3.3.3. The feedback of the status of the primary equipment, through the equipment’s auxiliary contacts to the binary inputs of the 7UM62, should be checked during the testing.
  • Page 376: Primary Commissioning Tests With The Generator

    3 Installation and Commissioning Commissioning Tests with the Generator Primary 3.4.1 General Hints Warning! When operating an electrical device, certain parts of the device inevitably have dangerous voltages. Severe personal injury or property damage can result if the device is not handled properly. Only qualified people shall work on and around this device after becoming 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 377 3.4 Primary Commissioning Tests with the Generator DANGER! Current transformer secondary circuits must be short-circuited before the current leads to the device are disconnected! If test switches are installed that automatically short-circuit the current transformer circuits, opening these test switches (placing them in the "Test" position) is sufficient provided the short-circuit function has been previously tested.
  • Page 378 If you want to use the commissioning tool, please refer to the help files provided on the subject. Instructions on how to install the long-distance data transmission network and work with the browser can be found on an Internet website (www.siemens.sipro- tec.de) in the download area of the “7SD52” protective relay (title: “Commissioning Tool Help”).
  • Page 379 3.4 Primary Commissioning Tests with the Generator means that the current connection on side 1 and side 2 is OK. A similar display is avail- able for the voltage and current vectors of side 2. Figure 3-21 Currents Flowing through the Protected Object For a test of the differential protection, the differential and restraint currents are en- tered in the characteristic.
  • Page 380: Checking The Current Circuits

    3 Installation and Commissioning 3.4.2 Checking the Current Circuits General The checks of the current circuits are performed with the generator to ensure the correct cabling, polarity, phase sequence, CT ratio etc., not in order to verify individual protection functions in the device. Switch unbalanced load protection (address 1701) and overload protection (address Preparation 1601) to Block relay.
  • Page 381 3.4 Primary Commissioning Tests with the Generator Set impedance protection (address 3301) to IMPEDANCE PROT. = Block relay: Calibrating the Impedance With the primary plant voltage-free and earthed, install a three-pole short-circuit bridge Protection which is capable of carrying rated current (e.g. earthing isolator) to the primary side of the unit transformer.
  • Page 382: Checking The Differential Protection

    3 Installation and Commissioning 3.4.3 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 correct amplitude matching for the current ratings of the protected object and the main primary c.t.s, and the correct vector group matching are set.
  • Page 383 3.4 Primary Commissioning Tests with the Generator Symmetrical The operational measured values supplied by the 7UM62 allow a fast commissioning Current Test without external instruments. The indices of the measured currents are defined 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 384: Checking The Earth Current Differential Protection

    3 Installation and Commissioning The polarity of the current connections and the parameterized polarity are taken into consideration when the angles are displayed. Thus, if all three angles differ by 180° from the theoretical value, the polarity of one complete transformer set is wrong. This can be corrected by checking and changing the corresponding plant parameters: Address 0201 STRPNT->OBJ S1 for the primary winding, Address 0210 STRPNT->OBJ S2 for the secondary winding,...
  • Page 385 3.4 Primary Commissioning Tests with the Generator Primary tests of power units are performed with the generator itself. On transformers, a low-voltage test source is used. Before the test, the CT connections have to be visually checked for correctness. Note: When performing the short-circuit test (3-phase short-circuit) for the earth current dif- ferential protection, check that the three current transformers (side 1 or side 2 –...
  • Page 386 3 Installation and Commissioning If there are deviations, a connection error can be normally assumed. If necessary, modify the wiring, or, in Power System Data 1, the allocation of the CT starpoint for the phase CTs or the earth CT I .
  • Page 387 3.4 Primary Commissioning Tests with the Generator ∼ Test source 7UM62 Figure 3-27 Measurement of the Zero Sequence Currents in a Wye-Delta Transformer ∼ Test source 7UM62 Figure 3-28 Measurement of the Zero Sequence Currents in a Delta-Delta Transformer with Compensating Winding ∼...
  • Page 388 3 Installation and Commissioning ∼ Test source 7UM62 Figure 3-30 Measurement of the Zero Sequence Currents in a Delta Winding with Artificial Starpoint A zero sequence current of at least 2 % the rated generator current is required per phase, i.e. the test current is at least 6 %. In the protection function, the sensitive pick- up threshold must be set, and the zero voltage release disabled.
  • Page 389: Checking The Voltage Circuits

    3.4 Primary Commissioning Tests with the Generator F.No. 05841 „REF U0> releas.“ must appear. When performing the test, keep in mind that the zero voltage is calculated from the three phase voltages and converted on the secondary side to the phase-to-phase voltage (equivalent to √3 U0). The value thus obtained is the same as for a broken delta winding.
  • Page 390: Checking The Stator Earth Fault Protection

    3 Installation and Commissioning Seq.“ will be output. The allocation of measuring quantities to phases must be checked and corrected, if necessary. If signification deviations are found, check, and if necessary correct, the voltage transformer circuits and repeat the test. It is also possible to use for this check the operational measured value of positive- ≠...
  • Page 391: Unit Connection

    3.4 Primary Commissioning Tests with the Generator 3.4.6.1 Unit Connection General In the event of an external (high-voltage side) short-circuit, an interference voltage is transmitted via the coupling capacitance C (Figure 3-31) which induces a neutral displacement voltage on the generator side. To ensure that this voltage is not interpreted by the protection as an earth fault within the generator, it is reduced by a suitable loading resistor to a value which corresponds to approximately one half the pick-up voltage U0>...
  • Page 392 3 Installation and Commissioning Since the reactance of the coupling capacitance is much larger than the referred ≈ U resistance of the loading resistor R ', U can be assumed to be U /√3 (compare also vector diagram Figure 3-32), whereby U /√3 is the neutral displacement voltage with a full displacement of the network (upper-voltage) neutral.
  • Page 393 3.4 Primary Commissioning Tests with the Generator ERD> Pick–up value Earth fault on machine side Value extrapolated to 100 % U Nmach Earth fault on upper voltage side 10 % 40 % 100 % corresponds to 90 % protected zone N mach Figure 3-33 Neutral displacement voltage during earth faults...
  • Page 394: Busbar Connection

    3 Installation and Commissioning Check Using With the primary plant voltage-free and earthed, install a single-pole earth fault bridge Network Earth Fault on the primary side of the unit transformer. DANGER! Primary measurements must only be carried out with the generator at stand– still on disconnected and grounded equipment of the power system.
  • Page 395 3.4 Primary Commissioning Tests with the Generator Σ ------- - --------- - V --------- - V 7UM62 Figure 3-34 Earth Fault with Busbar Connection The generator circuit breaker must be closed for this test and the generator 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 396 3 Installation and Commissioning With Directional The earth fault directional determination requires a check of the current and voltage Determination connections for correctness and correct polarity. The machine continues to be excited to a voltage that corresponds to a displacement voltage above the pick-up value. If the polarity is correct, the trip indication “S/E/F TRIP“...
  • Page 397 3.4 Primary Commissioning Tests with the Generator 7UM62 Figure 3-35 Directional Check with Toroidal Residual Current Transformers Directional Check If the current is supplied from a set of c.t.'s in Holmgreen connection (Figure 3-36), the with C.T.'s in displacement voltage is obtained in the same manner as in the above circuit. Only the Holmgreen current of that current transformer which is in the same phase as the by-passed Connection...
  • Page 398: Testing The 100-% Stator Earth Fault Protection

    3 Installation and Commissioning If, in an isolated network, the voltage connections for the reactive current measurement should be maintained for testing, then it should be noted that with a power flow with inductive component in forwards direction results in a backwards direction for the earth fault relay (contrary to an earth fault in this direction).
  • Page 399 3.4 Primary Commissioning Tests with the Generator With the earth fault bridge in place, the resistance stages of the 100-% protection (warning and trip stage) must pick up immediately on switching in the supply voltage of the 20 Hz generator. To check the pickup behaviour of the current stage SEF100 I>>, read out the mea- sured value I SEF from the operational measured values at approx.
  • Page 400: Checking The Sensitive Earth Fault Protection When Used For Rotor Earth Fault Protection

    3 Installation and Commissioning 3.4.8 Checking the Sensitive Earth Fault Protection when Used for Rotor Earth Fault Protection If the sensitive earth fault protection is used for rotor earth fault protection, it must first be set to Block relay under address 5101. Caution! Make sure that the checked rotor circuit is completed isolated from the earth, to avoid that the earthing resistor that is interposed for test purposes causes a...
  • Page 401: Rotor Earth Fault Protection (1 To 3 Hz)

    3.4 Primary Commissioning Tests with the Generator Start up generator and excite to rated voltage. If applicable place measurement brushes into operation. The rotor earth fault protection initiates pick-up and, after T-TRIP-RE<< (10 s when delivered from factory), trip annunciation (LED 2 and LED 1 as group indications for device pickup and device trip).
  • Page 402: Tests With The Generator Connected To The Network

    3 Installation and Commissioning 3.4.10 Tests with the Generator Connected to the Network 3.4.10.1 Checking the Correct Connection Polarity The following test instructions apply to a synchronous generator. Run up generator and synchronize with network. Slowly increase driving power input (up to approximately 5%).
  • Page 403: Calibrating The Reverse Power Protection

    3.4 Primary Commissioning Tests with the Generator − Read out the motoring power with polarity (negative sign) in the operational measured values and note it down as P (see table below). − Read out the reactive power with polarity (positive sign) in the operational measured values and note it down as Q (see table below).
  • Page 404: Checking The Underexcitation Protection

    3 Installation and Commissioning In order to confirm the correct settings, repeat reverse power test again. For this, the reverse power protection (address 3101) is set to BLOCK relay in order to check its effectiveness (using the annunciations). Start up generator and synchronize with network. Close regulating valves. From the operational measured value for the active power, the motoring power measured with the device can be derived.
  • Page 405: Checking The Directional Function Of The Overcurrent Time Protection

    3.4 Primary Commissioning Tests with the Generator Note: If operation with capacitive load is not possible, then load points can also be checked in the inductive (overexcited) range. In this case, the polarity of the current transformer connections must be re-parameterized (address 0223). Thus, the characteristics of the underexcitation protection are mirrored around the origin.
  • Page 406 3 Installation and Commissioning (FNo 00000004). Triggering for the oscillographic recording then occurs when the input is energized. For example, an auxiliary contact of the circuit breaker or primary switch may be used to control the binary input for triggering. An oscillographic recording that is externally triggered (that is, without a protective element pick-up or device trip) is processed by the device as a normal fault recording with the exception that data are not given in the fault messages.
  • Page 407: Final Preparation Of The Device

    3.5 Final Preparation of the Device Final Preparation of the Device Verify all terminal screws are tight and secure. Do not overtighten. Ensure that all pin connectors are properly inserted. Verify the wires to the terminals are tightly connected. Make sure the communication cables are firmly connected; however, do not overtighten the screws.
  • Page 408 3 Installation and Commissioning 7UM62 Manual C53000-G1176-C149-3...
  • Page 409: Technical Data

    Technical Data ® This chapter provides the technical data of the SIPROTEC 4 7UM62 device and the individual functions of the device, including the limiting values that under no circumstances may be exceeded. The electrical and functional data for devices equipped with all options are followed by the mechanical data with dimensional drawings.
  • Page 410 4 Technical Data 4.24 100–% Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G, –100 %) 4.25 Rotor Earth Fault Protection (R, fn, ANSI 64R) 4.26 Sensitive Rotor Earth Fault Protection with 1 to 3 Hz (ANSI 64R) 4.27 Motor Starting Time Supervision (ANSI 48) 4.28...
  • Page 411: General Device Data

    4.1 General Device Data General Device Data 4.1.1 Analog Inputs Nominal Frequency 50 Hz or 60 Hz (adjustable) Current Inputs Nominal Current 1 A or 5 A ≤ 1.6 A Ground Current, SensitiveI Burden per Phase and Ground Path – At I = 1 A Approx.
  • Page 412: Power Supply

    4 Technical Data 4.1.2 Power Supply Direct Voltage Voltage Supply Via Integrated Converter Nominal Power Supply Direct Voltage V 24/48 VDC 60/110/125 VDC PS nom Permissible Voltage Ranges 19 to 58 VDC 48 to 150 VDC Nominal Power Supply Direct Voltage V 110/125/220/250 VDC PSnom Permissible Voltage Ranges...
  • Page 413: Communications Interfaces

    4.1 General Device Data Binary inputs: 2 ranges ≥ 19 VDC – For Nominal Voltages 24/48/60/ ≤ 14 VDC 110/125 VDC ≥ 88 VDC – For Nominal Voltages 110/125/ ≤ 66 VDC 220/250 VDC Maximum Permissible Voltage 300 VDC Impulse Filter on Input 220 nF Coupling Capacitor at 220 V with recovery time >...
  • Page 414 4 Technical Data – Transmission Speed Min. 4800 Baud; max. 115200 Baud Factory Setting: 38400 Baud; Parity: 8E1 – Maximum Distance of Transmission 15 meters / 49 feet Rear Service–/ – Connection Isolated interface for data transfer Modem– Interface ® –...
  • Page 415 4.1 General Device Data For Panel Surface- Mounted Case On the case bottom λ = 820 nm – Optical Wavelength – Laser Class 1 Under EN 60825–1/ –2 using glass fiber 50/125 µm or using glass fiber 62.5/125 µm – Optical Link Signal Attenuation Max.
  • Page 416 4 Technical Data λ = 820 nm – Optical Wavelength – Laser Class 1 Under EN 60825–1/ –2 Using glass fiber 50/125 µm or Using glass fiber 62.5/125 µm – Optical Link Signal Attenuation Max. 8 dB, with glass fiber 62.5/125 µm –...
  • Page 417: Electrical Tests

    4.1 General Device Data – Signal Levels and Burdens: Rated Signal Voltage 12 V 24 V 6.0 V 15.8 V 31 V IHigh 1.0 V at I = 0.25 mA 1.4 V at I = 0.25 mA 1.9 V at I = 0.25 mA ILow ILow...
  • Page 418 4 Technical Data – Irradiation with HF Field, 10 V/m: 27 MHz to 500 MHz Non-Modulated IEC 60255–22–3 (Report) Class III – Irradiation with HF Field, 10 V/m: 80 MHz to 1000 MHz: 80 % AM: Amplitude Modulated 1 kHz IEC 61000–4–3, Class III –...
  • Page 419: Mechanical Stress Tests

    4.1 General Device Data 4.1.6 Mechanical Stress Tests Vibration and Standards: IEC 60255–21 and IEC 60068 Shock Stress – Vibration Sinusoidal During Operation ±0.075 mm amplitude; IEC 60255–21–1, Class 2 10 Hz to 60 Hz: IEC 60068–2–6 60 Hz to 150 Hz: 1 g acceleration frequency sweep rate 1 Octave/min 20 cycles in 3 orthogonal axes.
  • Page 420: Service Conditions

    56 days of the year up to 93% relative humidity. CONDENSATION MUST BE AVOIDED Siemens recommends that all devices be installed such that they are not exposed to direct sunlight, nor subject to large fluctuations in temperature that may cause condensation to occur.
  • Page 421: Construction

    4.1 General Device Data 4.1.10 Construction Case 7XP20 UL–certification conditions: “For use on a Flat Surface of a Type 1 Enclosure” Dimensions see dimensional drawings, Section 4.35 Weight (Mass) – In Case for Flush Mounting, of 19” 16.5 pounds (7.5 kg) –...
  • Page 422: Definite-Time Overcurrent Protection (Ansi 50, 67)

    4 Technical Data Definite-Time Overcurrent Protection (ANSI 50, 67) Pickup and Delay Pickup Current 50–1 0.25 A to 100.00 A ) (Increments 0.05 A) Time Ranges/ Pickup Current 50–2 0.25 A to 100.00 A ) (Increments 0.05 A) Resolutions Delay Times T 50–1, 50–2, 0.00 s to 60.00 s (Increments 0.01 s)
  • Page 423: Inverse-Time Overcurrent Protection (Ansi 51, 67)

    4.3 Inverse-Time Overcurrent Protection (ANSI 51, 67) Inverse-Time Overcurrent Protection (ANSI 51, 67) Pickup and Time Pickup Current 0.50 A to 20.00 A ) (Increments 0.05 A) Multiplier Ranges/ Time Multipliers for 51 0.05 s to 3.20 s (Increments 0.01 s) Resolutions or ∞...
  • Page 424 4 Technical Data t [s] t [s] 0.05 0.05 0.05 0.05 I/I p I/I p 13 5 0 14 ⋅ ⋅ Very inverse: Normal inverse: --------------------------- - T ------------------------------------- - T 0 02 ⁄ (Type A) ⁄ (Type B) – –...
  • Page 425 4.3 Inverse-Time Overcurrent Protection (ANSI 51, 67) Trip Time As per ANSI/IEEE (see also Figures 4-2 and 4-3) Characteristics As Per ANSI æ ö 3.922 ⋅ VERY INVERSE ç ÷ -------------------------- - 0.0982 è ø ⁄ – æ ö 8.9341 ⋅...
  • Page 426 4 Technical Data t [s] t [s] D [s] D [s] 0.05 0.05 I/I p I/I p æ ö æ ö ç 3 922 ÷ ç 8 9341 ÷ ⋅ ⋅ --------------------------- - 0 0982 -------------------------------------------- - 0 17966 VERY INVERSE INVERSE ç...
  • Page 427 4.3 Inverse-Time Overcurrent Protection (ANSI 51, 67) t [s] t [s] D [s] D [s] 0.05 0.05 I/I p I/I p æ ö æ ö ç 5 64 ÷ ç 0 4797 ÷ ⋅ ⋅ EXTREMELY INVERSE --------------------------- - 0 02434 DEFINITE INVERSE -------------------------------------------- - 0 21359...
  • Page 428: Thermal Overload Protection (Ansi 49)

    4 Technical Data Thermal Overload Protection (ANSI 49) Setting Ranges/ K-Factor per IEC 60255-8 0.10 to 4.00 (Increments 0.01) Resolutions τ Time Constant 30 s to 32000 s (Increments 1 s) Extension K-Factor - Factor 1.0 to 10.0 relative to the time constant for when Machine Stopped the machine running (Increments 0.1) Θ...
  • Page 429 4.4 Thermal Overload Protection (ANSI 49) t [min] t [min] Parameter: Setting Value of Time Constant τ [min] 1000 Parameter: Setting Value of Time Constant τ [min] 1000 0.05 0.05 6 7 8 10 12 6 7 8 10 12 ·...
  • Page 430: Unbalanced Load (Negative Sequence) Protection (Ansi 46)

    4 Technical Data Unbalanced Load (Negative Sequence) Protection (ANSI 46) Setting Ranges/ Permissible Unbalanced Load I >/I 3.0 % to 30.0 % (Increments 0.1 %) Resolutions (Warn. Stage too) Tripping Stage (Definite Time)I >>/I 10 % to 100 % (Increments 1 %) Delay Times >), T(I >>) 0.00 s to 60.00 s...
  • Page 431 4.5 Unbalanced Load (Negative Sequence) Protection (ANSI 46) Schieflast Negative Sequence t = f (I2/In) 10000 2000 1000 Parameter: Setting value FACTOR K 40 s 30 s 20 s 15 s 10 s 9 10 0.05 0.07 I2/In --------------------- - ⁄...
  • Page 432: Startup Overcurrent Protection (Ansi 51)

    4 Technical Data Startup Overcurrent Protection (ANSI 51) Setting Ranges/ Pickup Current I> 0.10 to 20.00 A (Increments 0.01 A) Resolution Delay Times T 0.00 to 60.00 s (Increments 0.01 s) or ∞ (does not expire) Inherent Operating Pickup Times I> 120 ms or higher (dep.
  • Page 433: Differential Protection For Generators And Motors (Ansi 87G/87M)

    4.7 Differential Protection for Generators and Motors (ANSI 87G/87M) Differential Protection for Generators and Motors (ANSI 87G/87M) Setting Ranges/ Differential Current >/I 0.05 to 2.00 (Increments 0.01) DIFF N Gen Resolutions High-Current Stage >>/I 0.5 to 12.0 (Increments 0.1) DIFF N Gen or ∞...
  • Page 434 4 Technical Data diff Fault characteristic -------- - 2031 I DIFF>> Tripping Blocking SLOPE 2 SLOPE 1 Add-On Stabilization 2021 I DIFF> 10 11 12 13 14 15 16 17 18 BASE POINT 2 BASE POINT 1 stab ----------- - Figure 4-6 Pickup Characteristic for Generator or Motor Differential Protection (settable) >>/I...
  • Page 435: Differential Protection For Transformers (Ansi 87T)

    4.8 Differential Protection for Transformers (ANSI 87T) Differential Protection for Transformers (ANSI 87T) Setting Ranges/ Differential Current >/I 0.05 to 2.00 (Increments 0.01) DIFF N transf Resolutions High-Current Stage >>/I 0.5 to 12.0 (Increments 0.1) DIFF N Transf or ∞ ( stage ineffective) Pickup see also Figure 4-8 Characteristic...
  • Page 436 4 Technical Data Influencing Power Supply Direct Voltage in Range 0.8 ≤ V ≤ 1.15 Variables for PS nominal Pickup Temperature in Range 23 °F ≤ ϑ ≤ 131 °F 0.3 % / 10 °F –5 °C ≤ ϑ ≤ 55 °C 0.5 % / 10 K Frequency in Range 0.95 ≤...
  • Page 437 4.8 Differential Protection for Transformers (ANSI 87T) Can be set to e.g. max n/I N = 4 DIFF Tripping Blocking Can be set to e.g. 5th harmonic = 40 % Can be set to e.g. >/I N = 0.2 DIFF Figure 4-10 Restraining Influence of Higher-Order Harmonics (settable)
  • Page 438: Earth Current Differential Protection (Ansi 87Gn/Tn)

    4 Technical Data Earth Current Differential Protection (ANSI 87GN/TN) Setting Ranges/ Differential Current I-REF> I/InO 0.05 to 2.00 (Increments 0.01) Resolution Characteristic: Basepoint I/InO 0.05 to 2.00 Characteristic: Slope 0.00 to 0.95 (Increments 0.01) Delay Times T 0.00 to 60.00 (Increments 0.01 s) or ∞...
  • Page 439: Underexcitation (Loss-Of-Field) Protection (Ansi 40)

    4.10 Underexcitation (Loss-of-Field) Protection (ANSI 40) 4.10 Underexcitation (Loss-of-Field) Protection (ANSI 40) Setting Ranges/ Conductance Sections 1/xd CHAR. 0.25 to 3.00 (Increments 0.01) Resolutions α1, α2, α3 Angle of Inclination 50° to 120° (Increments 1°) Delay Time 0.00 s to 60.00 s (Increments 0.01 s) or ∞...
  • Page 440: Reverse Power Protection (Ansi 32R)

    4 Technical Data 4.11 Reverse Power Protection (ANSI 32R) Setting Ranges/ Reverse Power >/S –0.50 % to –30.0 %(Increments 0.01 %) Resolutions Delay Times 0.00 s to 60.00 s (Increments 0.01 s) or ∞ (does not expire) Inherent Operating Pickup Times Times –...
  • Page 441: Forward Power Supervision (Ansi 32F)

    4.12 Forward Power Supervision (ANSI 32F) 4.12 Forward Power Supervision (ANSI 32F) Setting Ranges/ Forward Power </S 0.5 % to 120.0 % (Increments 0.1 %) Resolutions Forward Power >/S 1.0 % to 120.0 % (Increments 0.1 %) Delay Times 0.00 s to 60.00 s (Increments 0.01 s) or ∞...
  • Page 442: Impedance Protection (Ansi 21)

    4 Technical Data 4.13 Impedance Protection (ANSI 21) Overcurrent Fault Pickup Current IMP I> 0.50 A to 100.00 A ) (Increm. 0.05 A) Detection Drop-Off ratio Approx. 0.95 Measuring Tolerances acc.to 1 % of set value or 50 mA VDE 0435 part 303 Undervoltage Seal-In U<...
  • Page 443: Out-Of-Step Protection (Ansi 78)

    4.14 Out-of-Step Protection (ANSI 78) 4.14 Out-of-Step Protection (ANSI 78) Pickup Positive Sequence Component I >/I 20.0 % to 400.0 % (Increm. 0.1 %) Negative Sequence ComponentI </I 5.0 % to 100.0 % (Increm. 0.1 %) Dropout/Pickup Ratios – I >...
  • Page 444: Undervoltage Protection (Ansi 27)

    4 Technical Data 4.15 Undervoltage Protection (ANSI 27) Setting Ranges / Measurement Quantities: PositiveSequence Voltages Resolution Pickup Voltage U<, U<<, Up< 10.0 V to 125.0 V (Increments 0.1 V) (27) Dropout Ratio U<, U<< 1.01 to 1.20 (Increments 0.01) (27-1 and 27-2 only) Delay Time T U<, T U<<...
  • Page 445 4.15 Undervoltage Protection (ANSI 27) Tripping Time Figure 4-12 Tripping Times of the Inverse Undervoltage Protection for Setting Value Up< = 75 V, Without Additional Trip Delay (T = 0) Up< 7UM62 Manual C53000-G1176-C149-3...
  • Page 446: Overvoltage Protection (Ansi 59)

    4 Technical Data 4.16 Overvoltage Protection (ANSI 59) Setting Ranges / Measurement Quantities: Maximum of the phase–to–phase voltages, Resolution calculated from the phase–to–earth voltag- Pickup Voltage U>, U>> 30.0 V to 170.0 V (Increments 0.1 V) 59-1, 59-2 Dropout Ratio U>, U>>...
  • Page 447: Frequency Protection (Ansi 81)

    4.17 Frequency Protection (ANSI 81) 4.17 Frequency Protection (ANSI 81) Setting Ranges/ Number of Frequency Elements 4: each can be 81/O or 81/U Resolutions Pickup Frequency f> or f< 40.00 Hz to 65.00 Hz (Increments 0.01 Hz) (81–1 to 81–4) Delay Time T f1 (81–1) 0.00 s to 600.00 s...
  • Page 448: Overexcitation (Volt/Hertz) Protection (Ansi 24)

    4 Technical Data 4.18 Overexcitation (Volt/Hertz) Protection (ANSI 24) Setting Ranges/ U / U Resolutions Overexcitation (Ratio 1.00 to 1.20 (Increments 0.01) > f / f (Warning Stage) U / U Overexcitation (Ratio > 1.00 to 1.40 (Increments 0.01) f / f (Stepped Characteristic) Time Delay 0.00 s to 60.00 s...
  • Page 449 4.18 Overexcitation (Volt/Hertz) Protection (ANSI 24) 10000 t [s] 3000 2000 1000 T U/f>> U f ⁄ U/f> U/f>> ---------------- - (Pickup/warning stage) ⁄ Figure 4-13 Tripping Time Characteristic of Thermal Replica and of Stepped Stage of the Overexcitation Protection (Pre–settings) 7UM62 Manual C53000-G1176-C149-3...
  • Page 450: Rate-Of-Frequency-Change Protection (Ansi 81R)

    4 Technical Data 4.19 Rate-of-Frequency-Change Protection (ANSI 81R) Setting Ranges/ Stages, can be +df/dt> or–df/dt Resolution Pickup Values df/dt 0.1 to 10 Hz/s (Increments 0.1 Hz/s) Delay Times T 0.00 to 60.00 s (Increments 0.01 s) or ∞ (does not expire) Undervoltage Lock-Out U1>...
  • Page 451: Jump Of Voltage Vector

    4.20 Jump of Voltage Vector 4.20 Jump of Voltage Vector Stage ∆ϕ Setting Ranges/ 2° to 30° (Increments 1°) Resolution Delay Time T 0.00 to 60.00 s (Increments 0.01 s) or ∞ (does not expire) Reset Time T 0.10 to 60.00 s (Increments 0.01 s) Reset or ∞...
  • Page 452: Stator Earth Fault Protection (Ansi 59N, 64G, 67G)

    4 Technical Data 4.21 90–%–Stator Earth Fault Protection (ANSI 59N, 64G, 67G) Setting Ranges/ Displacement Voltage U0> 2.0 V to 125.0 V (Increments 0.1 V) Resolutions Residual Current > 2 mA to 1000 mA (Increments 1 mA) Inclination of Directional Characteristic 0°...
  • Page 453: Sensitive Earth Fault Protection (Ansi 51Gn, 64R)

    4.22 Sensitive Earth Fault Protection (ANSI 51GN, 64R) 4.22 Sensitive Earth Fault Protection (ANSI 51GN, 64R) Setting Ranges/ Overcurrent pick-up > 2 mA to 1000 mA (Increments 1 mA) Resolutions Delay Time 0.00 s to 60.00 s (Increments 0.01 s) IEE>...
  • Page 454: Stator Earth Fault Protection With 3Rd Harmonics (Ansi 27/59Tn 3Rd Harm.)

    4 Technical Data 4.23 100–%–Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) Setting Ranges/ Pick–Up Value for 3rd Harmonic Resolutions in Undervoltage Stage < 0.2 V to 40.0 V (Increments 0.1 V) 0 (3rd HARM) Pick–Up Value for 3rd Harmonic in Overvoltage Stage >...
  • Page 455: 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 %) 4.24 100–% Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G, –100 %) 20 to 700 Ω (Increments 1 Ω) Setting Ranges/ Alarm Stage R <...
  • Page 456: Rotor Earth Fault Protection (R, Fn, Ansi 64R)

    4 Technical Data 4.25 Rotor Earth Fault Protection (R, fn, ANSI 64R) Setting Ranges/ Alarm Stage 3.0 kΩ to 30.0 kΩ (Increments 0.1 kΩ) E ALARM Resolutions Tripping Stage 1.0 kΩ to 5.0 kΩ (Increments 0.1 kΩ) E TRIP Delay Times 0.00 s to 60.00 s (Increments 0.01 s) RE ALARM...
  • Page 457: Sensitive Rotor Earth Fault Protection With 1 To 3 Hz (Ansi 64R)

    4.26 Sensitive Rotor Earth Fault Protection with 1 to 3 Hz (ANSI 64R) 4.26 Sensitive Rotor Earth Fault Protection with 1 to 3 Hz (ANSI 64R) Setting Ranges/ Warning Stage 5 kΩ to 80 kΩ (Increments 1 kΩ) E WARN Resolution Tripping Stage 1 kΩ...
  • Page 458: Motor Starting Time Supervision (Ansi 48)

    4 Technical Data 4.27 Motor Starting Time Supervision (ANSI 48) Setting Ranges/ Motor Starting Current 0.50 A to 80.00 A ) (Increments 0.05 A) STARTUP Increments Pickup Threshold 3.00 A to 5.00 A (Increments 0.05 A) MOTOR START Permissible Starting Time T 1.0 s to 180.0 s (Increments 0.1 s) STARTUP...
  • Page 459: Restart Inhibit For Motors

    4.28 Restart Inhibit for Motors (ANSI 66, 49 Rotor 4.28 Restart Inhibit for Motors (ANSI 66, 49 Rotor Setting Ranges/ Starting CurrentBased 1.5 to 10.0 (Increments 0.1) Start MOTnom Increments on Nominal Motor Current Max. Permissible 3.0 s to 120.0 s (Increments 0.1 s) MOT START Starting Time...
  • Page 460: Breaker Failure Protection (Ansi 50Bf)

    4 Technical Data 4.29 Breaker Failure Protection (ANSI 50BF) Pickup and Delay Pickup of 50 Element BF.I> 0.20 A to 10.00 A )(Increments 0.05 A) Time Ranges/ Delay Time TRIP-Timer 0.06 s to 60.00 s (Increments 0.01 s) Resolutions or ∞ (no trip) Initiating Time Pickup Times (protection initiates) - For Internal Start...
  • Page 461: Inadvertent Energization (Ansi 50/27)

    4.30 Inadvertent Energization (ANSI 50/27) 4.30 Inadvertent Energization (ANSI 50/27) Setting Ranges/ Overcurrent Pick-Up 0.5 A to 100.0 A ) (Increments 0.5 A) STAGE or ∞ (does not expire) Resolutions Release < 10.0 V to 125.0 V (Increments 0.1 V) Delay Time PICK UP T U <...
  • Page 462: Dc Voltage/Dc Current Protection (Ansi 59N Dc /51N Dc )

    4 Technical Data 4.31 DC Voltage/DC Current Protection (ANSI 59N /51N Setting Ranges/ Voltage Increase > 0.1 V to 8.5 V (Increments 0.1 V) Resolutions Voltage Decrease < 0.1 V to 8.5 V (Increments 0.1 V) Current Increase > 0.2 mA to 17.0 mA (Increments 0.1 mA) Current Decrease <...
  • Page 463: Thermoboxes For Temperature Detection

    4.32 Thermoboxes for Temperature Detection 4.32 Thermoboxes for Temperature Detection Temperature Number of Thermoboxes Possible 1 or 2 Detectors Number of Temperature Detectors per Thermobox max. 6 Pt 100 Ω oder Ni 100 Ω oder Ni 120 Ω Type of Measurement Location Setting “Oil”...
  • Page 464: Additional Functions

    4 Technical Data 4.33 Additional Functions Operational Operating Measured Values L1, S1 L2, S1 L3,S1 L1, S2 L2, S2 L3,S2 Measured Values for Currents in A or kA primary; in A secondary, or in % of I - Range 10 % to 200 % I 0.2 % of measured value or 10 mA ±...
  • Page 465 4.33 Additional Functions P, Real power (with sign) in kW (MW or GW) primary, and in % S - Range 0 % to 120 % S 1 % ± 0.25 % S - Tolerance = √3 · U with S ·...
  • Page 466 4 Technical Data Charge at Polarity Reversal in mAs - Range 0.00 mAs to 1.00 mAs - Tolerance 0.01 mAs Rotor Earth Resistance in kΩ earth - Range 0.0 kΩ to 9999.9 kΩ - Tolerance < 5 % or 0.5 kΩ <...
  • Page 467 4.33 Additional Functions Range 0 mA to 22.5 mA Minimum Threshold (Limit of Validity:) 0.0 mA to 5.0 mA (Increments 0.1 mA) Maximum Threshold 22.0 mA (fixed) Configurable Reference Value 20 mA 10.0 % to 1000.0 %(Increments 0.1 %) Measured Values Current Asymmetry >...
  • Page 468 4 Technical Data Waveform Capture Optionally instantaneous values or r.m.s. (Fault Recorder) values – Instantaneous Values − Recording Time Total of 5 s Pre-event and post-event recording and memory time adjustable − Sampling Rate for 50 Hz 1 sample/1.25 ms (16 sam/cyc) Sampling Rate for 60 Hz 1 sample/1.04 ms (16 sam/cyc) −...
  • Page 469 4.33 Additional Functions Task Level Function Module Description PLC1_ PLC_ SFS_ BEARB BEARB BEARB BEARB BOOL_TO_IC Boolean to Internal Single – Point (conversion) BUILD_DI Create Double Point – Annunciation CMD_CHAIN Command chain – – CMD_INF Command information – – – CONNECT Connection –...
  • Page 470 4 Technical Data Run-Time Level Limits in TICKS MW_BEARB (Measured value processing) 10000 PLC1_BEARB (Slow PLC processing) 1900 PLC_BEARB (Fast PLC processing) SFS_BEARB Interlocking) 10000 In the following table, the amount of TICKS required by the individual elements of a CFC chart is shown.
  • Page 471: Operating Ranges Of The Protection Functions

    4.34 Operating Ranges of the Protection Functions 4.34 Operating Ranges of the Protection Functions Table 4-1 Operating Ranges of the Protection Functions Operat. cond. 0 Operational condition 1 Operat. cond. 0 f ≤ 10 Hz 11 Hz< f/Hz ≤ 40 40 Hz ≤ f/Hz ≤ 69 f ≥...
  • Page 472 4 Technical Data ) Thermical replica registers cooling-down ) Pick -up – when already present – is maintained ) Pick -up – when already present – is maintained, if the measured voltage is not too small ) 25 Hz < f/Hz ≤ 40 Hz ) Function is only active at rated frequency ±...
  • Page 473: Dimensions

    4.35 Dimensions 4.35 Dimensions Housing for Panel Flush Mounting or Cubicle Installation (Size 29.5 29.5 29 30 Mounting plate Mounting plate Rear view Side view (with screwed terminals) Side view (with clamp terminals) 5 or M4 Dimensions in mm ± 0.5 13.2 ±...
  • Page 474 4 Technical Data Housing for Panel Flush Mounting or Cubicle Installation (Size 29.5 29.5 29 30 Mounting plate Monting plate Side view (with screwed terminals) Side view (with clamp terminals) 5 or M4 5 or M4 5 or M4 5 or M4 13,2 Rear view ±...
  • Page 475 4.35 Dimensions Panel Mounting (Housing size 10,5 29,5 Front view Side view Dimensions in mm Figure 4-16 Dimensions 7UM621 for Panel Mounting (size Panel Mounting (Housing size 10,5 29,5 Front view Side view Dimensions in mm Figure 4-17 Dimensions 7UM622 for Panel Mounting (size n n n n 7UM62 Manual C53000-G1176-C149-3...
  • Page 476 4 Technical Data 7UM62 Manual C53000-G1176-C149-3...
  • Page 477: Appendix

    Appendix This appendix is primarily a reference for the experienced user. This Chapter provides ordering information for the models of 7UM62. General diagrams indicating the termi- nal connections of the 7UM62 models are included. Connection examples show the proper connections of the device to primary equipment in typical power system con- figurations.
  • Page 478: Ordering Information And Accessories

    A Appendix Ordering Information and Accessories 9 10 11 12 Multifunctional Machine Protection 7UM62 Housing, Number of Binary Inputs and Outputs Housing 19”, 7 BI, 12 BO, 1 Live Status Contact Housing 19”, 15 BI, 20 BO, 1 Live Status Contact Nominal Current = 1 A, Iee (sensitive) = 5 A, Iee (sensitive)
  • Page 479 A.1 Ordering Information and Accessories 9 10 11 12 Multifunctional Machine Protection 7UM62 Measuring Functionalities without extended measuring functionality Min/Max values, energy counter Protective Elements Basic Generator Elements, included in all versions Overcurrent protection with undervoltage seal in (I> +U<) ANSI 51 Overcurrent protection, directional (I>>, dir.)
  • Page 480: Accessories

    A Appendix A.1.1 Accessories Interface Modules Exchange Modules for Interfaces Name Order No. RS232 C53207-A351-D641-1 RS485 C53207-A351-D642-1 FO 820 nm C53207-A351-D643-1 Profibus DP RS485 C53207-A351-D611-1 Profibus DP double ring C53207-A351-D613-1 Modbus RS485 C53207-A351-D621-1 Modbus 820 nm C53207-A351-D623-1 DNP3.0 RS485 C53207-A351-D631-1 DNP3.0 820 nm C53207-A351-D633-1 Analog output AN20...
  • Page 481 A.1 Ordering Information and Accessories Coupling Unit The sensitive earth fault protection can be used as rotor earth fault protection. The system frequency bias voltage for the rotor circuit is generated and coupled to the rotor circuit via a coupling unit. Coupling unit for rotor earth fault protection (R, fn) Order No.
  • Page 482 A Appendix Interface Cable An interface cable is necessary for communication between the SIPROTEC device and a PC. Requirements for the computer are Windows 95 or Windows NT4 and the ® operating software DIGSI Interface cable between PC or SIPROTEC device Order No.
  • Page 483: Schematic Diagram Of The Accessories

    A.1 Ordering Information and Accessories A.1.1.1 Schematic Diagram of the Accessories ≈ 4 µF ≈ 33 Ω/50 W ≈ 0.75 H 230 V ≈ 60 V ≈ 36 V–49 V 100 to 125 V ∗ Figure A-1 Schematic Diagram of Coupling Unit 7XR6100-0 105 Ω...
  • Page 484 A Appendix 500 Ω 500 Ω 9000 Ω Figure A-4 Schematic Diagram of Voltage Divider 10:1; 20:1; 3PP1326-0BZ-012009 Surface mounting housing Flush mounting housing UOutput 7XR60 Auxiliary voltage 230 VAC 230 VAC UMeas 100...115 VAC 120, 125 VAC UControl Factory Set: 100 - 125 VAC ∗...
  • Page 485 A.1 Ordering Information and Accessories Surface mounting case / Flush mounting case 20 Hz EXTERNAL BLOCK DEVICE OPERATIVE ∗ Figure A-7 General Diagram of 20-Hz-Generator 7XT3300-0 7UM62 Manual C53000-G1176-C149-3...
  • Page 486 A Appendix Surface mounting case / Flush mounting case 10 mF 0R68, 4 x 50 W 600 mH INPUT BANDPASS 47 mF OUTPUT BANDPASS 47 mF 330R, 50 W 330R, 50 W VOLTAGE DIVIDER 330R, 50 W 330R, 50 W 330R, 50 W ∗...
  • Page 487: Dimensional Drawing Of The Accessories

    A.1 Ordering Information and Accessories 1.1.1.2 Dimensional Drawing of the Accessories 29.5 Mounting plate Rear view Connector modules Side view ) Current connectors: Screwed terminal for max. 4 mm Twin spring crimp connector in parallel for max. 2.5 mm 5 or M4 max.
  • Page 488 A Appendix Mounting plate 209.5 Connector modules Side view Rear view 5 or M4 ± 0.3 Dimensions on the mounting plate Dimensions in mm Figure A-10 Dimensions of Coupling Unit 7XR6100-0BA0 for Panel Surface Mounting 7UM62 Manual C53000-G1176-C149-3...
  • Page 489 A.1 Ordering Information and Accessories Drip–proof roof Drip-proof roof Space required for Space required for the cover removing removing the cover Cover Cover Table A-1 3PP1 Degree of Protection IP 20 (with Drip–Proof Roof IP 23); Dimensions in mm Type 3PP1 32 3 x 16 3PP1 33...
  • Page 490 A Appendix recommended space to the next unit 29.5 Current connections (terminals 1 to 6): View A not used in 7XT71 Voltage connections (terminals 7 to 31): isolated ring cable lug: for bolts 4 mm diameter max. major diameter 9 mm type: e.g.
  • Page 491 A.1 Ordering Information and Accessories 29.5 Mounting plate Connec tions for earthing Connections terminals Current connections (terminals 1 to 6): not used in 7XT71 Voltage connections (terminals 7 to 31): isolated ring cable lug: for bolts 4 mm diameter max. major diameter 9 mm type: e.g.
  • Page 492 A Appendix 29.5 Mounting plate Side view (with screwed terminals) 5 or M4 ± 0.5 13.2 Rear view ± 0.3 206.5 Dimensions in mm Panel cut-out Figure A-14 Dimensions of Resistor Unit 7XR6004-0CA00 for Panel Flash Mounting 7UM62 Manual C53000-G1176-C149-3...
  • Page 493 A.1 Ordering Information and Accessories Mounting plate 209.5 Side view (with screwed terminals) ± 0.3 12.5 Rear view ± 0.3 Fixing points of the Dimensions in mm mounting plate Figure A-15 Dimensions of Resistor Unit 7XR6004-0BA00 for Panel Surface Mounting 7UM62 Manual C53000-G1176-C149-3...
  • Page 494 A Appendix 29.5 Mounting plate Connector modules Connectors: Screwed terminal for max. 1.5 mm2. Twin spring crimp connector in paral lel for max. 1.5 mm2. 5 or M4 Panel cut-out Dimensions in mm +0.5 13.2 +0.3 206.5 Figure A-16 Dimensions of 20-Hz-Generator 7XT3300-0CA00 for Panel Flash Mounting 7UM62 Manual C53000-G1176-C149-3...
  • Page 495 A.1 Ordering Information and Accessories 209,5 Connector modules Connectors: Screwed terminal for max. 1.5 mm2. Twin spring crimp connector in paral lel for max. 1.5 mm2. ø4.5 oder M5 Dimensions in mm 12.5 Figure A-17 Dimensions of 20-Hz-Generator 7XT3300-0BA00 for Panel Surface Mounting 7UM62 Manual C53000-G1176-C149-3...
  • Page 496 A Appendix 29.5 Mounting plate Set square *) Dimensions in mm 31.8 - 0.3 Ø5.5(4x) - 0.5 *) For panel flush mounting, 2 set squares C73165- A63-C201-1 are necessary since the mounting rails of the device are not sufficient for the high weight of the device.
  • Page 497 A.1 Ordering Information and Accessories Side view 31.8 - 0.3 29,5 31.8 - 0.3 Set square *) 239.5 - 0,3 Distance piece *) Dimensions in mm *) 2 set squares C73165- A63-C201-1 and 4 distance pieces C73165-A63-C203-1 are necessary for panel surface mounting. Fix the set squares to the mounting rails of the device, using 8 standard screws size M4.
  • Page 498: General Diagrams (Iec)

    A Appendix General Diagrams (IEC) A.2.1 Housing for Panel Flush Mounting or Cubicle Installation 7UM621∗–∗D/E L1S2 L2S2 L3S2 L1S1 L2S1 L3S1 BO10 BO11 BO12 Life status contact Power- supply Analog output or Thermobox Service Port or Thermobox (–) (–) System interface or analog output (–) Time Synchronization...
  • Page 499 A.2 General Diagrams (IEC) 7UM622∗–∗D/E L1S2 L2S2 L3S2 L1S1 L2S1 L3S1 BO10 BO11 BO12 BO13 BO14 BO15 BO16 BO17 BO18 BO19 BO20 BI10 BI11 Life status BI12 contact BI13 Power BI14 supply BI15 Analog output or Thermobox Service port (–) or Thermobox (–) System interface...
  • Page 500: Housing For Panel Surface Mounting

    A Appendix A.2.2 Housing for Panel Surface Mounting 7UM621∗–∗B L1S2 L2S2 L3S2 L1S1 L2S1 L3S1 BO10 BO11 BO12 Life status contact Power supply Earthing terminal (26) IN SYNC IN 12 V COM SYNC (–) Time synchronization COMMON IN 5 V (–) IN 24 V Screen...
  • Page 501 A.2 General Diagrams (IEC) 7UM622∗–∗B L1S2 L2S2 L3S2 L1S1 L2S1 L3S1 BO10 BO11 BO12 BO13 BO14 BO15 BO16 BO17 BO18 BO19 BO20 BI10 Life status BI11 contact BI12 Power BI13 supply Earthing BI14 terminal (51) IN SYNC BI15 IN 12 V COM SYNC Time synchronization COMMON...
  • Page 502: General Diagrams (Ansi)

    A Appendix General Diagrams (ANSI) 7UM621∗– Surface-mounting housing Flush-mounting housing A,S2 7UM621 B,S2 C,S2 G,sens. (EE2) R 15 R 17 R 10 R 18 R 16 R 11 R 12 R 13 N(E) R 14 A,S1 R 10 B,S1 R 11 C,S1 R 12 G,sens.(EE1)
  • Page 503 A.3 General Diagrams (ANSI) 7UM622∗– Surface-mounting housing Flush-mounting housing A,S2 7UM622 B,S2 C,S2 G,sens. (EE2) R 15 R 17 R 18 R 10 R 16 R 11 R 12 R 13 N(E) R 14 A,S1 B,S1 C,S1 G,sens.(EE1) R 13 K 13 TD 1 (Start-up)
  • Page 504: Connection Examples

    A Appendix Connection Examples A (L1) B (L2) C (L3) ANSI 7UM62 A(L1)S1 B(L2)S1 C(L3)S1 A(L1) B(L2) C(L3) K17 + Excitation voltage injection Rotor earth current injection A(L1)S2 B(L2)S2 C(L3)S2 Measuring transducer: K13 + -Temperature injection K15 + - or DC voltage injection Figure A-26 Bus–Bar Connection Current and voltage connections to three transformers, core balance neutral current transformers and...
  • Page 505 A.4 Connection Examples A (L1) B (L2) C (L3) ANSI 7UM62 A(L1)S1 B(L2)S1 C(L3)S1 A(L1) B(L2) C(L3) K17 + Excitation voltage injection do not earth here A(L1)S2 B(L2)S2 C(L3)S2 Measuring transducer: K13 + - Temperature injection low resistance - or DC voltage K15 + injection if necessary...
  • Page 506 A Appendix A (L1) B (L2) C (L3) ANSI Earthing transformer 7UM62 with measuring winding A(L1) B(L2) C(L3) For 100 % stator earth fault protection A(L1)S1 B(L2)S1 C(L3)S1 Divider 3PP1326 K17 + Excitation Exc. Rotor earth-current injection A(L1)S2 B(L2)S2 C(L3)S2 Measuring transducer: K13 + - Temperature...
  • Page 507 A.4 Connection Examples A (L1) B (L2) C (L3) ANSI 7UM62 A(L1)S1 B(L2)S1 C(L3)S1 Yd11 A(L1) B(L2) C(L3) Divider 3PP1326 K17 + Excitation Exc. Rotor earth current injection A(L1)S2 B(L2)S2 C(L3)S2 For 100 % stator max. 10A Neutral earth-fault protection transformer K13 + Measuring transducer:...
  • Page 508 A Appendix 7UM62 K15 + K17 + Exc. Exc. + 12 + 31 K13 + 7KG6 - 32 - 11 (Amplifier) connections shall be twisted and screened max. 10 cm Shunt: 10 A/ 150 mV Figure A-30 Startup Earth Fault Protection Connection of DC Voltage Input TD1 with Series-Connected Amplifier 7KG6 for Systems with Startup Converter Connection to the...
  • Page 509 A.4 Connection Examples Connection to the phase-to-phase VT 7UM6 voltage 100 V - 125 V AC Ω 3PP1336 Exc. Ω Figure A-32 Rotor Earth Fault Protection – with series device 7XR61for injection of a rated-frequency voltage into the rotor circuit if the sensitive earth current input is used.
  • Page 510 A Appendix A (L1) B (L2) C (L3) ANSI 7UM62 A(L1) B(L2) C(L3) A(L1)S1 B(L2)S1 C(L3)S1 K13 + Measuring transducer for injection of any RTD module analog signal K15 + e.g. speed, 7XV5662 vibration, pressure (6 meas. K17 + junctions) To serial interface A(L1)S2...
  • Page 511 A.4 Connection Examples 7UM61 7UM62 A(L1) B(L2) C(L3) Figure A-34 Voltage Transformer Connections for Two Voltage Transformers in Open Delta Connection (V Connection) L1 L2 L3 7UM62 7UM6 A(L1) A(L1), B(L2) B(L2) C(L3) C)L3) Figure A-35 Voltage Transformer Connection with L2 Earthed on the Secondary Side Connection to the phase-to-phase VT voltage...
  • Page 512 A Appendix 7UM62 K15 + At gas turbines: Injection of cold gas temperature K17 + Excitation Exc. Auxiliary- 20-Hz- voltage 20-Hz- Generator Bandpass A(L1) 7XT33 7XT34 B(L2) C(L3) External Wiring block 400A Neutral shielded transformer Device operative max 200 V + 12 + 31 K13 +...
  • Page 513 A.4 Connection Examples A (L1) B (L2) C (L3) 7UM62 C(L3)S2 A(L1)S2 B(L2)S1 B(L2)S2 C(L3)S1 A(L1)S1 Figure A-38 Earth current differential protection (generator) A (L1) B (L2) C (L3) 7UM62 C(L3)S2 B(L2)S2 B(L2)S1 A(L1)S2 C(L3)S1 A(L1)S1 Figure A-39 Earth current differential protection (transformer) 7UM62 Manual C53000-G1176-C149-3...
  • Page 514: Connection Examples For Rtd-Box

    A Appendix A.4.1 Connection Examples for RTD-Box 7XV566 A’ 7XV5650 RTD-Box Port D FO/RS485 7UM62 Bus number: 00 Converter A’ and B’ jumpers for the terminating resis- B’ tors 7XV566 A’ RTD-Box Port C or D 7UM62 Bus number: 00 A’...
  • Page 515: 100-% Stator Earth Fault Protection With Primary Load Resistor

    A.5 100–% Stator Earth Fault Protection with Primary Load Resistor 100–% Stator Earth Fault Protection with Primary Load Resistor Some power systems with generators in unit connection have a load resistor installed directly in the generator starpoint to reduce interference. Figure A-43 shows the con- nection of the 20 Hz generator and the band pass in this application, and the integra- tion of the protection device.
  • Page 516: Protection Settings

    A Appendix A.5.1 Protection Settings The settings recommended are the same as in Section 2.29. In addition, the correction angle (address 5309 PHI I SEF) and the ohmic contact resistance of the voltage transformer must be determined during the primary tests, and set at address 5310A SEF Rps.
  • Page 517 A.5 100–% Stator Earth Fault Protection with Primary Load Resistor 3. Insert now on the primary side a resistance which corresponds to the tripping val- ue (e.g. 2 kΩ). Check the measured fault resistance (R SEF=). If this resistance differs very much from the value expected, modify SEF Rps accordingly and, if necessary, make a fine adjustment with the correction angle (PHI I SEF).
  • Page 518: Definition Of The Active Power Measurement

    A Appendix Definition of the Active Power Measurement The 7UM62 used the generator reference-arrow system. The power output is posi- tive. Figure A-44 Definition of Positive Direction of Reference Arrows Table A-2 shows the operating ranges for synchronous and asynchronous machines. Parameter 1108 ACTIVE POWER is set to Generator.
  • Page 519 A.6 Definition of the Active Power Measurement Table A-2 shows that the operating ranges in generator and motor operation are mir- rored around the reactive power axis. The measured power values also result from the above definition. If, for instance, the forward power monitoring or the reverse power protection is to be used in a synchronous motor, parameter 1108 ACTIVE POWER must be set to Motor.
  • Page 520: Current Transformer Requirements

    A Appendix Current Transformer Requirements The differential protection is of decisive importance for the requirements that the cur- rent transformers must meet. The highspeed trip stage (IDiff >>) uses instantaneous values and can therefore reliably trip high-current internal short-circuits. The other decisive factor for the requirements that the current transformers must meet are external short-circuits with their possible DC component.
  • Page 521 A.7 Current Transformer Requirements Table A-4 Transformer Requirements Transformer Generator Symmetrical short circuit cur- rent I ⋅ ⋅ ≈ ≈ --------- - I ------- - I ″ pN, Tr pN, G Example = 0.1 ’’ = 0.12 n’ > 40 n’...
  • Page 522: Overview Of The Masking Features Of The User Defined Information

    A Appendix Overview of the Masking Features of the User Defined Information A.8.1 Source: BI, F, C; Destination: BO, LED, C Type of Information Source Destination CFC Task level • Annunciation: Single Point – SP Single Point Indication ON/OFF – –...
  • Page 523 A.8 Overview of the Masking Features of the User Defined Information Type of Information Source Destination CFC Task level Single Controls negated – C_SN ON/OFF – – – – – C_SN Open/Close – – – – Double Controls 1 Trip 1 Close –...
  • Page 524 A Appendix Type of Information Source Destination CFC Task level • Control Commands with feedback: Single Controls – CF_S Single Point Indication ON/OFF Control – – – – – SP Feedback – – – CF_S Single Point Indication Open/Close Control –...
  • Page 525 A.8 Overview of the Masking Features of the User Defined Information Type of Information Source Destination CFC Task level – CF_D4 Double Point Indication (Breaker indication “00” Control – – – – = not valid/transmitted as “3”) – DP Feedback –...
  • Page 526: Destination: Indication Buffer, System Interface

    A Appendix A.8.2 Destination: Indication Buffer, System Interface Configuring an In- Two indication buffers are available for selection: Operation (Event Log) Buffer (E) and dication Buffer as a Trip Log (T). The indications from protective functions are firmly assigned to these in- Destination dication buffers.
  • Page 527: Default Settings

    A.9 Default Settings Default Settings A.9.1 Binary Inputs Binary input Abbreviation Type of Description information >SV tripped 5086 Binary input 1 SP O/O >Stop valve tripped >Uexc fail. 5328 Binary input 2 >Exc. voltage failure recognized >BLOCK f1 5206 Binary input 3 SP O/O >BLOCK U<...
  • Page 528 A Appendix Binary output Abbreviation Type Description I> TRIP 1815 Output relay 8 OUT O/O Marshalled via the tripping matrix: S/E/F TRIP 5193 OUT O/O U>> TRIP 6573 OUT O/O f1 TRIP 5236 OUT O/O f2 TRIP 5237 OUT O/O EXC<3 TRIP 5343 OUT O/O...
  • Page 529 FNro 5098 Pr+SV TRIP FNo 1223 FNo 5568 SEF 3H TRIP IEE>> TRIP FNo 5671 FNo 5128 Pf< TRIP FNo 1226 Diff TRIP IEE> TRIP FNo 5129 FNo 1471 FNo 5691 Diff> Trip Pf> TRIP BrkFailure TRIP FNo 5692 FNo 1521 Diff>>...
  • Page 530: Led Indicators

    A Appendix A.9.3 LED Indicators Abbreviation Type of Description information Relay TRIP 0511 LED 1 OUT O/O Protective relay has tripped Relay PICKUP 0501 LED 2 OUT O/O Protective relay has picked up I> Fault L1 1811 LED 3 OUT O/O Fault L1 I>...
  • Page 531: Establishing A Default Display

    A.9 Default Settings A.9.5 Establishing a Default Display I1: 0.50kA cosϕ: Side 1 Side 2 U : 10.93kV f:50.00Hz 122A 1222A 4.64MW 124A 1243A 2.86MVAR 123A 1231A 0.50kA 6.31kV DIFF STAB 0.50kA 6.30kV 0.00A 0.00A 0.50kA 6.29kV 0.00A 0.00A 0.0A 0.00A 0.00A Figure A-46 Basic Displays of 7UM62...
  • Page 532: Pre-Defined Cfc Charts

    A Appendix A.9.7 Pre–Defined CFC Charts ® Some CFC Charts are already supplied with the SIPROTEC device: Device and System The single-point indication “>DataStop“ that can be injected by binary inputs is con- UnlockDT Logic verted by means of a NEGATOR block into an indication “ “...
  • Page 533: Interoperability List

    A.10 Interoperability List A.10 Interoperability List Physical layer Electrical interface EIA RS-485 Number of loads for one equipment: 32 Optical interface Glass fibre F-SMA type connector Plastic fibre BFOC/2,5 type connector Transmission speed 9600 bit/s 19200 bit/s Link layer There are no choices for the link layer Application layer Transmission mode for application data Mode 1 (least significant octet first) as defined in 4.10 of IEC 60870-5-4...
  • Page 534 A Appendix 3.4.3 Generic functions in control direction Read headings of all defined groups Read values of all entries of one group Read directory of a single entry Read value of a single entry General interrogation of generic data Write entry Write entry with confirmation Write entry with execution Write entry abort...
  • Page 535: Functions Overview

    A.11 Functions Overview A.11 Functions Overview Addr. Setting Title Setting Options Default Setting Comments Grp Chge OPTION Disabled Disabled Setting Group Change Option Enabled FAULT VALUE Disabled Instantaneous Fault values Instantaneous values values RMS values DIFF. PROT. Disabled Enabled Differential Protection Enabled PROT.
  • Page 536 A Appendix Addr. Setting Title Setting Options Default Setting Comments IMPEDANCE Disabled Enabled Impedance Protection PROT. Enabled OUT-OF-STEP Disabled Enabled Out-of-Step Protection Enabled UNDERVOLTAGE Disabled Enabled Undervoltage Protection Enabled OVERVOLTAGE Disabled Enabled Overvoltage Protection Enabled FREQUENCY Prot. Disabled Enabled Over / Underfrequency Protec- Enabled tion OVEREXC.
  • Page 537 A.11 Functions Overview Addr. Setting Title Setting Options Default Setting Comments ANALOGOUTPUT Disabled Disabled Analog Output B1 (Port B) Positive Sequence Current I1 [%] Negative Sequence Current I2 [%] Positive Sequence Voltage U1 [%] Active Power |P| [%] Reactive Power |Q| [%] Frequency f [%] |Power Factor| [%] p.u.
  • Page 538 A Appendix Addr. Setting Title Setting Options Default Setting Comments ANALOGOUTPUT Disabled Disabled Analog Output D2 (Port D) Positive Sequence Current I1 [%] Negative Sequence Current I2 [%] Positive Sequence Voltage U1 [%] Active Power |P| [%] Reactive Power |Q| [%] Frequency f [%] |Power Factor| [%] p.u.
  • Page 539: Settings

    A.12 Settings A.12 Settings NOTE: The following table lists all data which are available in the maximum complement of the device. De- pendent on the ordered model, only those data may be present which are valid for the individual version. Addr.
  • Page 540 A Appendix Addr. Setting Title Function Setting Options Default Setting Comments STARPNT SIDE 1 Power System Isolated Isolated Starpoint of Side 1 is Data 1 Solid Earthed UN-PRI SIDE 2 Power System 0.40..800.00 kV 6.30 kV Rated Primary Voltage side Data 1 STARPNT SIDE 2 Power System...
  • Page 541 A.12 Settings Addr. Setting Title Function Setting Options Default Setting Comments WAVEFORM Oscillographic Fault event Fault event Scope of Waveform Data DATA Fault Records Power System fault MAX. LENGTH Oscillographic 0.30..5.00 sec 1.00 sec Max. length of a Waveform Fault Records Capture Record PRE.
  • Page 542 A Appendix Addr. Setting Title Function Setting Options Default Setting Comments 1401 O/C Ip Inverse O/C Inverse O/C Time Protec- Time Protection tion Ip Block relay for trip commands 1402 Inverse O/C 0.10..4.00 A 1.00 A Ip Pickup Time Protection 0.05..3.20 sec;...
  • Page 543 A.12 Settings Addr. Setting Title Function Setting Options Default Setting Comments 1612A Kτ-FACTOR Thermal Over- 1.0..10.0 Kt-Factor when Motor load Protection Stops 1615A I MAX THERM. Thermal Over- 0.50..8.00 A 3.30 A Maximum Current for Ther- load Protection mal Replica 1616A T EMERGENCY Thermal Over- 10..15000 sec...
  • Page 544 A Appendix Addr. Setting Title Function Setting Options Default Setting Comments 2021 I-DIFF> Differential Pro- 0.05..2.00 I/InO 0.20 I/InO Pickup Value of Differential tection Curr. 0.00..60.00 sec; ∞ 2026A T I-DIFF> Differential Pro- 0.00 sec T I-DIFF> Time Delay tection 0.5..12.0 I/InO;...
  • Page 545 A.12 Settings Addr. Setting Title Function Setting Options Default Setting Comments 2110 I-REF> Restricted Earth 0.05..2.00 I/InO 0.10 I/InO I-REF> Pickup Fault Protection 0.00..60.00 sec; ∞ 2112 T I-REF> Restricted Earth 0.00 sec T I-REF> Time Delay Fault Protection 2113A SLOPE Restricted Earth 0.00..0.95 0.25...
  • Page 546 A Appendix Addr. Setting Title Function Setting Options Default Setting Comments 0.00..60.00 sec; ∞ 3104 T-SV-CLOSED Reverse Power 1.00 sec Time Delay Short (with Protection Stop Valve) 0.00..60.00 sec; ∞ 3105A T-HOLD Reverse Power 0.00 sec Pickup Holding Time Protection 3201 FORWARD Forward Power...
  • Page 547 A.12 Settings Addr. Setting Title Function Setting Options Default Setting Comments 3314 P/SPOL-TPOL Impedance Pro- 0.10..30.00 Ohm 8.00 Ohm Distance betw. Power tection Swing - Trip-Pol. 3315 dZ/dt Impedance Pro- 1.0..600.0 Ohm/s 300.0 Ohm/s Rate of Change of dZ/dt tection 3316A BLOCKING OF Impedance Pro- Zone Z1...
  • Page 548 A Appendix Addr. Setting Title Function Setting Options Default Setting Comments 4006A U< DOUT RATIO Undervoltage 1.01..1.20 1.05 U< Drop Out Ratio Protection 4101 OVERVOLTAGE Overvoltage Overvoltage Protection Protection Block relay for trip commands 4102 U> Overvoltage 30.0..170.0 V 115.0 V U>...
  • Page 549 A.12 Settings Addr. Setting Title Function Setting Options Default Setting Comments 4213 T f4 Frequency Pro- 0.00..100.00 sec 10.00 sec T f4 Time Delay tection 4214 THRESHOLD f4 Frequency Pro- Freq. prot. stage Freq. prot. stage Handling of Threshold tection automatic automatic Stage f4...
  • Page 550 A Appendix Addr. Setting Title Function Setting Options Default Setting Comments 4403 T MUL Inverse Under- 0.10..5.00 sec; 0 1.00 sec Time Multiplier for Charac- voltage Protec- teristic tion 0.00..60.00 sec; ∞ 4404 T Up< Inverse Under- 0.00 sec T Up< Time Delay voltage Protec- tion 4501...
  • Page 551 A.12 Settings Addr. Setting Title Function Setting Options Default Setting Comments 4514 df4/dt >/< Rate-of-fre- -df/dt< negative rate -df/dt< negative rate Mode of Threshold (df4/dt quency-change of freq. change of freq. change >/<) protection +df/dt> positive rate of freq. change 0.1..10.0 Hz/s;...
  • Page 552 A Appendix Addr. Setting Title Function Setting Options Default Setting Comments 5002 U0> Stator Earth 2.0..125.0 V 10.0 V U0> Pickup Fault Protection 5003 3I0> Stator Earth 2..1000 mA 5 mA 3I0> Pickup Fault Protection 0..360 ° 15 ° 5004 DIR.
  • Page 553 A.12 Settings Addr. Setting Title Function Setting Options Default Setting Comments 5301 100% SEF-PROT. 100% Stator- 100% Stator-Earth-Fault Earth-Fault Pro- Protection tection Block relay for trip commands 5302 R< SEF ALARM 100% Stator- 20..700 Ohm 100 Ohm Pickup Value of Alarm Earth-Fault Pro- Stage Rsef<...
  • Page 554 A Appendix Addr. Setting Title Function Setting Options Default Setting Comments 6007 R SERIES Rotor Earth 0..999 Ohm 50 Ohm Series Resistance (e.g. Fault Protection Meas. Brushes) 6008 I RE< Rotor Earth 1.0..50.0 mA; 0 2.0 mA Pickup Value of Failure Fault Protection Detection Ire<...
  • Page 555 A.12 Settings Addr. Setting Title Function Setting Options Default Setting Comments 6602 IStart/IMOTnom Restart Inhibit 1.5..10.0 I Start / I Motor nominal for Motors 6603 T START MAX Restart Inhibit 3.0..320.0 sec 8.5 sec Maximum Permissible Star- for Motors ting Time 6604 T EQUAL Restart Inhibit...
  • Page 556 A Appendix Addr. Setting Title Function Setting Options Default Setting Comments 7201 DC PROTECTION DC Voltage/ DC Voltage/Current Protec- Current Protec- tion tion Block relay for trip commands 7202 MEAS.METHOD DC Voltage/ Mean Value Mean Value Measurement Method Current Protec- Root Mean Square (MEAN/RMS Values) tion...
  • Page 557 A.12 Settings Addr. Setting Title Function Setting Options Default Setting Comments 8107 BAL. FACT. I S2 Measurement 0.10..0.90 0.50 Balance Factor for Current Supervision Monitor S2 8108 SUM.thres. U Measurement 10..200 V 10 V Summation Thres. for Volt. Supervision Monitoring 8109 SUM.Fact.
  • Page 558 A Appendix Addr. Setting Title Function Setting Options Default Setting Comments 8505 MEAS. VALUE 3> Threshold Disabled Disabled Measured Value for Thres- supervision Active Power P hold MV3> Reactive Power Q Change of Active Power Delta P Positive Sequence Voltage U1 Negative Sequence Voltage U2 Zero Sequence Cur-...
  • Page 559 A.12 Settings Addr. Setting Title Function Setting Options Default Setting Comments 8511 MEAS. VALUE 6< Threshold Disabled Disabled Measured Value for Thres- supervision Active Power P hold MV6< Reactive Power Q Change of Active Power Delta P Positive Sequence Voltage U1 Negative Sequence Voltage U2 Zero Sequence Cur-...
  • Page 560 A Appendix Addr. Setting Title Function Setting Options Default Setting Comments -50..250 °C; ∞ 100 °C 9013 RTD 1 STAGE 1 RTD-Box RTD 1: Temperature Stage 1 Pickup -58..482 °F; ∞ 212 °F 9014 RTD 1 STAGE 1 RTD-Box RTD 1: Temperature Stage 1 Pickup -50..250 °C;...
  • Page 561 A.12 Settings Addr. Setting Title Function Setting Options Default Setting Comments 9042A RTD 4 LOCATION RTD-Box Other RTD 4: Location Ambient Winding Bearing Other -50..250 °C; ∞ 100 °C 9043 RTD 4 STAGE 1 RTD-Box RTD 4: Temperature Stage 1 Pickup -58..482 °F;...
  • Page 562 A Appendix Addr. Setting Title Function Setting Options Default Setting Comments 9071A RTD 7 TYPE RTD-Box not connected not connected RTD 7: Type Pt 100 Ohm Ni 120 Ohm Ni 100 Ohm 9072A RTD 7 LOCATION RTD-Box Other RTD 7: Location Ambient Winding Bearing...
  • Page 563 A.12 Settings Addr. Setting Title Function Setting Options Default Setting Comments -50..250 °C; ∞ 120 °C 9095 RTD 9 STAGE 2 RTD-Box RTD 9: Temperature Stage 2 Pickup -58..482 °F; ∞ 248 °F 9096 RTD 9 STAGE 2 RTD-Box RTD 9: Temperature Stage 2 Pickup 9101A RTD10 TYPE RTD-Box...
  • Page 564 A Appendix Addr. Setting Title Function Setting Options Default Setting Comments -50..250 °C; ∞ 100 °C 9123 RTD12 STAGE 1 RTD-Box RTD12: Temperature Stage 1 Pickup -58..482 °F; ∞ 212 °F 9124 RTD12 STAGE 1 RTD-Box RTD12: Temperature Stage 1 Pickup -50..250 °C;...
  • Page 565: List Of Information

    A.13 List of Information A.13 List of Information NOTE: The following table lists all data which are available in the maximum complement of the device. De- pendent on the ordered model, only those data may be present which are valid for the individual version. The symbol ’...
  • Page 566 A Appendix F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 00113 Flag Lost (Flag Lost) Supervision 00125 Chatter ON (Chatter ON) Device 00140 Error with a summary alarm (Error Supervision Sum Alarm) 00147 Error Power Supply (Error PwrSupply) Supervision 00160 Alarm Summary Event (Alarm Sum Supervision...
  • Page 567 A.13 List of Information F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 00210 Err:1A/5Ajumper different from Supervision settingS1 (Err1A/5AwrongS1) 00211 Err:1A/5Ajumper different from Supervision settingS2 (Err1A/5AwrongS2) 00212 Err: TD1 jumper different from setting Supervision (Err. TD1 jumper) 00213 Err: TD2 jumper different from setting Supervision (Err.
  • Page 568 A Appendix F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 00402 >Q MIN/MAX Buffer Reset (>Q MiMa Min/Max Measure- Reset) ment Setup 00407 >Frq. MIN/MAX Buffer Reset (>Frq Min/Max Measure- MiMa Reset) ment Setup 00409 >BLOCK Op Counter (>BLOCK Op Statistics LED BI Count)
  • Page 569 A.13 List of Information F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 01233 Earth current prot. is BLOCKED (IEE Sensitive Earth BLOCKED) Current Protection 01234 Earth current prot. is ACTIVE (IEE Sensitive Earth ACTIVE) Current Protection 01403 >BLOCK breaker failure (>BLOCK Breaker Failure LED BI...
  • Page 570 A Appendix F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 01508 >Failure temperature input Thermal Overload LED BI (>Fail.Temp.inp) Protection 01511 Thermal Overload Protection OFF Thermal Overload (Th.Overload OFF) Protection 01512 Thermal Overload Protection BLOK- Thermal Overload KED (Th.Overload BLK) Protection 01513 Overload Protection ACTIVE (Over-...
  • Page 571 A.13 List of Information F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 01809 O/C I>> TRIP (I>> TRIP) O/C I>> (with direc- tion) 01811 O/C fault detection stage I> phase L1 O/C I> (with under- (I> Fault L1) voltage seal-in) 01812 O/C fault detection stage I>...
  • Page 572 A Appendix F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 01966 O/C prot. stage I> is BLOCKED (I> O/C I> (with under- BLOCKED) voltage seal-in) 01967 O/C prot. stage I> is ACTIVE (I> O/C I> (with under- ACTIVE) voltage seal-in) 01970 O/C prot.
  • Page 573 A.13 List of Information F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 04526 >Trigger external trip 1 (>Ext trip 1) External Trip LED BI Functions 04531 External trip 1 is switched OFF (Ext 1 External Trip OFF) Functions 04532 External trip 1 is BLOCKED (Ext 1...
  • Page 574 A Appendix F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 04576 External trip 3: General picked up (Ext External Trip 3 picked up) Functions 04577 External trip 3: General TRIP (Ext 3 External Trip Gen.TRP) Functions 04583 >BLOCK external trip 4 (>BLOCK Ext External Trip LED BI...
  • Page 575 A.13 List of Information F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 05002 Suitable measured quantities present Power System Data (Operat. Cond.) 05010 >BLOCK fuse failure monitor (>FFM Supervision LED BI BLOCK) 05011 >FFM extern undervoltage (>FFM U< Supervision LED BI extern)
  • Page 576 A Appendix F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 05086 >Stop valve tripped (>SV tripped) Reverse Power LED BI Protection 05091 Reverse power prot. is switched OFF Reverse Power (Pr OFF) Protection 05092 Reverse power protection is BLOK- Reverse Power KED (Pr BLOCKED) Protection...
  • Page 577 A.13 List of Information F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 05145 >Reverse Phase Rotation (>Reverse Power System Data LED BI Rot.) 05146 >Reset memory for thermal replica I2 Unbalance Load LED BI (>RM th.rep. I2) (Negative Sequence) 05147 Phase Rotation L1L2L3 (Rotation...
  • Page 578 A Appendix F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 05183 Stator earth fault protection is ACTIVE Stator Earth Fault (S/E/F ACTIVE) Protection 05186 Stator earth fault: U0 picked up (U0> Stator Earth Fault picked up) Protection 05187 Stator earth fault: U0 stage TRIP (U0>...
  • Page 579 A.13 List of Information F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 05233 f2 picked up (f2 picked up) Frequency Protec- tion 05234 f3 picked up (f3 picked up) Frequency Protec- tion 05235 f4 picked up (f4 picked up) Frequency Protec- tion 05236 f1 TRIP (f1 TRIP)
  • Page 580 A Appendix F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 05331 Underexc. prot. is switched OFF Underexcitation (Excit. OFF) Protection 05332 Underexc. prot. is BLOCKED Underexcitation (Excit.BLOCKED) Protection 05333 Underexc. prot. is ACTIVE Underexcitation (Excit.ACTIVE) Protection 05334 Underexc.
  • Page 581 A.13 List of Information F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 05372 Overexc. prot.: TRIP of th. stage (U/f> Overexcitation Pro- th.TRIP) tection (U/f) 05373 Overexc. prot.: U/f>> picked up (U/f>> Overexcitation Pro- pick.up) tection (U/f) 05381 >BLOCK rotor earth fault prot.
  • Page 582 A Appendix F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 05401 Failure REF protection (1-3Hz) (Fail Rotor Earth Fault REF 1-3Hz) Protection (1-3Hz) 05403 REF prot. (1-3Hz): warning stage Rotor Earth Fault (Re<) (REF 1-3Hz Warn) Protection (1-3Hz) 05406 REF prot.
  • Page 583 A.13 List of Information F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 05504 >BLOCK df1/dt stage (>df1/dt block) Rate-of-frequency- LED BI change protection 05505 >BLOCK df2/dt stage (>df2/dt block) Rate-of-frequency- LED BI change protection 05506 >BLOCK df3/dt stage (>df3/dt block) Rate-of-frequency- LED BI change protection...
  • Page 584 A Appendix F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 05543 Inadvert. Energ. prot. is ACTIVE (I.En. Inadvertent Energi- ACTIVE) sation 05546 Release of the current stage (I.En. Inadvertent Energi- release) sation 05547 Inadvert. Energ. prot.: picked up (I.En. Inadvertent Energi- picked up) sation...
  • Page 585 A.13 List of Information F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 05581 >BLOCK Vector Jump (>VEC JUMP Jump of Voltage LED BI block) Vector 05582 Vector Jump is switched OFF (VEC Jump of Voltage JUMP OFF) Vector 05583 Vector Jump is BLOCKED (VEC JMP Jump of Voltage...
  • Page 586 A Appendix F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 05652 Diff. prot.: Blocked by ext. fault L2 (Diff Differential Protec- Bl. exF.L2) tion 05653 Diff. prot.: Blocked by ext. fault.L3 (Diff Differential Protec- Bl. exF.L3) tion 05657 Diff: Crossblock by 2.Harmonic Differential Protec-...
  • Page 587 A.13 List of Information F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 05702 Diff. current in phase L2 at trip (Diff Differential Protec- L2:) tion 05703 Diff. current in phase L3 at trip (Diff Differential Protec- L3:) tion 05704 Restr.
  • Page 588 A Appendix F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 06506 >BLOCK undervoltage protection U< Undervoltage Pro- LED BI (>BLOCK U<) tection 06508 >BLOCK undervoltage protection U<< Undervoltage Pro- LED BI (>BLOCK U<<) tection 06513 >BLOCK overvoltage protection Overvoltage Protec- LED BI (>BLOCK O/V)
  • Page 589 A.13 List of Information F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 06565 Overvoltage protection switched OFF Overvoltage Protec- (Overvolt. OFF) tion 06566 Overvoltage protection is BLOCKED Overvoltage Protec- (Overvolt. BLK) tion 06567 Overvoltage protection is ACTIVE Overvoltage Protec- (Overvolt.
  • Page 590 A Appendix F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 06853 >Trip circuit supervision: breaker relay Trip Circuit Supervi- LED BI (>TripC brk rel.) sion 06861 Trip circuit supervision OFF (TripC Trip Circuit Supervi- OFF) sion 06862 Trip circuit supervision is BLOCKED Trip Circuit Supervi- (TripC BLOCKED)
  • Page 591 A.13 List of Information F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 14123 RTD 2 Temperature stage 2 picked up RTD-Box (RTD 2 St.2 p.up) 14131 Fail: RTD 3 (broken wire/shorted) RTD-Box (Fail: RTD 3) 14132 RTD 3 Temperature stage 1 picked up RTD-Box (RTD 3 St.1 p.up) 14133 RTD 3 Temperature stage 2 picked up...
  • Page 592 A Appendix F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 14181 Fail: RTD 8 (broken wire/shorted) RTD-Box (Fail: RTD 8) 14182 RTD 8 Temperature stage 1 picked up RTD-Box (RTD 8 St.1 p.up) 14183 RTD 8 Temperature stage 2 picked up RTD-Box (RTD 8 St.2 p.up) 14191 Fail: RTD 9 (broken wire/shorted)
  • Page 593 A.13 List of Information F.No. Description Function Type Log-Buffers Configurable in Matrix IEC 60870-5-103 Infor- matio 30609 Accumulation of interrupted curr. L3 Statistics S1 (ΣIL3 S1:) 30610 Accumulation of interrupted curr. L1 Statistics S2 (ΣIL1 S2:) 30611 Accumulation of interrupted curr. L2 Statistics S2 (ΣIL2 S2:) 30612 Accumulation of interrupted curr.
  • Page 594: List Of Measured Values

    A Appendix A.14 List of Measured Values F.No. Description Function IEC 60870-5-103 Configurable in Matrix 00605 I1 (positive sequence) (I1 =) Measure- priv ment 00606 I2 (negative sequence) (I2 =) Measure- priv ment 00621 U L1-E (UL1E=) Measure- priv ment 00622 U L2-E (UL2E=) Measure-...
  • Page 595 A.14 List of Measured Values F.No. Description Function IEC 60870-5-103 Configurable in Matrix 00662 DC Current (I DC =) Measure- ment 00693 REF(R,fn): Total Resistance (R total) (Rtot =) Measure- ment 00696 REF(R,fn): Total Reactance (X total) (Xtot =) Measure- ment 00697 REF(R,fn): Phase Angle of Z total (ϕ...
  • Page 596 A Appendix F.No. Description Function IEC 60870-5-103 Configurable in Matrix 00802 Temperature rise for phase L1 (Θ /ΘtripL1=) Thermal Measure- ment 00803 Temperature rise for phase L2 (Θ /ΘtripL2=) Thermal Measure- ment 00804 Temperature rise for phase L3 (Θ /ΘtripL3=) Thermal Measure- ment...
  • Page 597 A.14 List of Measured Values F.No. Description Function IEC 60870-5-103 Configurable in Matrix 00883 Frequency Maximum (fMax=) Min/Max Measure- ment Setup 00888 Pulsed Energy Wp (active) (Wp(puls)) Energy 00889 Pulsed Energy Wq (reactive) (Wq(puls)) Energy 00894 DC voltage (U DC =) Measure- ment 00896...
  • Page 598 A Appendix F.No. Description Function IEC 60870-5-103 Configurable in Matrix 01071 Temperature of RTD 4 (Θ RTD 4 =) Thermal priv Measure- ment 01072 Temperature of RTD 5 (Θ RTD 5 =) Thermal priv Measure- ment 01073 Temperature of RTD 6 (Θ RTD 6 =) Thermal priv Measure-...
  • Page 599 A.14 List of Measured Values F.No. Description Function IEC 60870-5-103 Configurable in Matrix 07749 Phase angle in phase IL3 side 1 (ϕIL3S1=) Measure- ment 07750 Phase angle in phase IL1 side 2 (ϕIL1S2=) Measure- ment 07759 Phase angle in phase IL2 side 2 (ϕIL2S2=) Measure- ment 07760...
  • Page 600: Protocol-Dependent Functions

    A Appendix A.15 Protocol-Dependent Functions → IEC 60870–5–103 Profibus DP DNP3.0 Modbus ASCII/RTU Additional inter- Protocol face ß Function (optional) Operational measured values Metered values Fault recording No. Only via addi- No. Only via additional tional service inter- service interface face Remote relay setting No.
  • Page 601: Index

    Corrections From Siemens AG Name: Dept. PTD PA D DM D–13623 Berlin Company/Dept.: Germany Address: Dear reader, printing errors can never be entirely eliminated: therefore, should you come across any when read- Phone no.: Fax no.: ing this manual, kindly enter them in this form to- gether with any comments or suggestions for im- provement that you may have.
  • Page 602 All rights are reserved in the event of the grant of a patent or the registration of a utility model or design. Subject to technical alteration Siemens Aktiengesellschaft Order-no.: C53000-G1176-C149-3 Available from: LZF Fürth-Bislohe Printed in Germany/Imprimé en Allemagne...