Preface Introduction Functions SIPROTEC Mounting and Commissioning Multi-Functional Generator Technical Data Protection Relay Appendix 7UM61 V4.1 Literature Glossary Manual Index C53000-G1176-C127-3...
SIPROTEC, SINAUT, SICAM and DIGSI are registered trade- and software described. However, deviations from the descrip- marks of SIEMENS AG. Other designations in this manual may tion cannot be completely ruled out, so that no liability can be ac- be trademarks that if used by third parties for their own purposes cepted for any errors or omissions contained in the information may violate the rights of the owner.
(Low-voltage directive 73/23 EEC). This conformity has been proved by tests conducted by Siemens AG in accor- dance with Article 10 of the Council Directive in agreement with the generic stan- dards EN 50081 and EN 61000-6-2 (for EMC directive) and the standard EN 60255-6 (for low-voltage directive).
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Preface Definition QUALIFIED PERSONNEL For the purpose of this instruction manual and product labels, a qualified person is one who is familiar with the installation, construction and operation of the equipment and the hazards involved. In addition, he has the following qualifications: •...
Preface External binary output signal with number (device indication) used as input signal Example of a parameter switch designated FUNCTION with the address 1234 and the possible settings ON and OFF Besides these, graphical symbols are used according to IEC 60617-12 and IEC 60617-13 or symbols derived from these standards.
Introduction ® The SIPROTEC 7UM61 devices are introduced in this section. An overview of the 7UM61 is presented with its application areas, features, and scope of functions. Overall Operation Application Scope Characteristics 7UM61 Manual C53000-G1176-C127-3...
1 Introduction Overall Operation ® The digital Multi-Function Protection SIPROTEC 7UM61 is equipped with a high per- formance microprocessor. All tasks such as the acquisition of the measured values and issuing of commands to circuit breakers and other switching equipment, are pro- cessed digitally.
1.1 Overall Operation tion is possible as well). The 4th voltage input is for displacement voltage measure- ment for stator earth fault protection. The IA input amplifier group allows high impedance connection for analog input values and contains filters optimized for measured value processing bandwidth and speed. The AD analog digital converter group contains high resolution Σ∆...
1 Introduction Serial Interfaces A serial operator interface in the front cover is provided for local communication with ® a PC, using the operating program DIGSI 4. This permits convenient operation of all functions of the device. A serial service interface can likewise make communication via PC with the device ®...
1.2 Application Scope Application Scope ® The SIPROTEC 7UM61 device is a digital multi-function machine protection unit from the 7UM6 Numerical Protection series. It provides all functions necessary for protec- tion of generators and motors. As the scope of functions of the 7UM61 can be custom- ized, it is suited for small, medium-sized and large generators.
1 Introduction The 7UM61 device is usable for further applications such as • Backup protection, since in addition to overcurrent protection, a large variety of pro- tection functions allow, for example, monitoring of voltage and frequency load. • Protection of synchronous and asynchronous motors. •...
1.3 Characteristics Characteristics General Features • Powerful 32-bit microprocessor system. • Complete digital processing of measured values and control, from sampling and digitalization of measured quantities to tripping circuit breakers or other switchgear devices. • Total electrical separation between the internal processing stages of the device and the external transformer, control and DC supply circuits of the system because of the design of the binary inputs, outputs, and the DC converters.
1 Introduction Negative Sequence • Precise evaluation of negative sequence component of the three phase currents. Protection • Alarm stage when a set unbalanced load is exceeded. • Thermal characteristic with adjustable negative sequence factor and adjustable cooldown time. • High-speed trip stage for large unbalanced loads (can be used for short-circuit pro- tection).
1.3 Characteristics Rate-of-Frequency- • Monitors whether the frequency overshoots (df/dt>) and/or undershoots (df/dt<) a Change Protection set limit value, with 4 individually settable limit values or delay times. • Variable measuring windows • Coupling to frequency protection pickup. • Settable undervoltage threshold. Vector Jump •...
1 Introduction Inadvertent Ener- • Damage limitation on inadvertent switching on of a stationary generator by fast gizing Protection opening of the generator switch. • Instantaneous value acquisition of the phase currents. • Operational state and voltage supervision as well as fuse failure monitor are the enable criteria.
Functions ® This chapter describes the numerous functions available on the SIPROTEC 7UM61. It shows the setting possibilities for all the functions in maximum configura- tion. Instructions for deriving setting values and formulae, where required are provid- Additionally it may be defined which functions are to be used. Introduction, Reference Systems Functional Scope Power System Data 1...
2.1 Introduction, Reference Systems Introduction, Reference Systems The following chapters explain the individual protective and additional functions and provide information about the setting values. 2.1.1 Functional Description Generator The calculation examples are based on two smaller capacity reference power systems with the two typical basic connections, i.e.
2 Functions Technical Data of the Reference Power Systems Generator = 5.27 MVA N, T = 6.3 kV N, Gen = 483 A cos ϕ = 0.8 Current transformer: = 500 A; = 1 A N,prim N, sec Toroidal c.t.: = 60 A;...
2.2 Functional Scope Functional Scope The 7UM61 device has numerous protection and supplementary functions. The hard- ware 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 UE and IEE respectively.
2 Functions Parameter 104 FAULT VALUE is used to specify whether the oscillographic fault re- cording should record Instant. values or RMS values. If RMS values is stored, the available recording time increases by the factor 16. For the high-current stage I>> of the overcurrent protection, address 113O/C PROT. I>>...
2 Functions Power System Data 1 The device requires certain network and power system data so that it can be adapted to its intended functions in accordance with application. These include, for instance, rated power system and transformer data, measured quantity polarities and connec- tion, breaker properties etc.
2.3 Power System Data 1 Iee Transformation For conversion of the ground current Iee in primary quantities, the device requires the primary/secondary transformation ratio of the transformer. This is set at address 213 Ratios FACTOR IEE. At addresses 221 Unom PRIMARY and 222 Unom SECONDARY, information is entered Nominal Values of Voltage Transform- regarding the primary nominal voltage and secondary nominal voltages (phase-to-...
2 Functions The address 225 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 e-n windings connected to the device (UE input), this must be specified accordingly in address 223 (see above margin heading "UE Input").
2.3 Power System Data 1 Parameter 274 ATEX100 allows compliance with PTB requirements (special require- ATEX100 ments in Germany) for thermal replicas. If this parameter is set to YES, all thermal rep- licas of the 7UM61 are stored on auxiliary power supply failure. As soon as the supply voltage returns, the thermal replicas continue operating with the stored values.
2.4 Change Group Change Group Two independent groups of parameters can be set for the device functions. During operation the user can locally switch between setting groups using the operator panel, binary inputs (if so configured), the operator and service interface per PC, or via the system interface.
2 Functions Power System Data 2 The general protection data (P.System Data 2) include settings associated with all functions rather than a specific protection or monitoring function. Parameter settings P.System Data 2 can be switched using the setting group. 2.5.1 Functional Description Setting Groups In the 7UM61 relay, two independent setting groups (A and B) are possible.
2.5 Power System Data 2 Information Type of In- Comments formation IL2: Primary fault current IL2 IL3: Primary fault current IL3 5012 UL1E: Voltage UL1E at trip 5013 UL2E: Voltage UL2E at trip 5014 UL3E: Voltage UL3E at trip 5015 Active power at trip 5016 Reactive power at trip...
2 Functions Definite-Time Overcurrent Protection (I>, ANSI 50/51) with Undervoltage Seal-In 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 may be not promptly disconnected thus endangering the protected object. Initially, the currents are numerically filtered so that only the fundamental frequency currents are used for the measurement.
2.6 Definite-Time Overcurrent Protection (I>, ANSI 50/51) with Undervoltage Seal-In Figure 2-4 Logic Diagram of the Overcurrent Stage I> with Undervoltage Seal-In 2.6.2 Setting Notes Overcurrent protection is only effective and available if address 112 O/C PROT. I> General is set to Enabled during configuration. If the function is not needed it is set to Disabled.
2 Functions The 1205 U< undervoltage stage (positive-sequence voltage) is set to a value below Undervoltage Seal- the lowest phase-to-phase voltage admissible during operation, e.g. 80 V. The seal-in time 1206 T-SEAL-IN limits the pickup seal-in introduced by the overcur- rent/undervoltage.
2 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 may be not promptly disconnected thus endangering the protected object. In order to ensure that pick-up always occurs even with internal faults, the protection - for generators - is usually connected to the current transformer set in the neutral leads of the machine.
2.7 Definite-Time Overcurrent Protection (I>>, ANSI 50, 51, 67) with Direction Detection Figure 2-6 Cross-Polarized Voltages for Direction Determination The phase carrying the highest voltage is selected for the direction decision. With equal current levels, the phase with the smaller number is chosen (I before I before ).
2 Functions Figure 2-7 Logic Diagram of I>> Stage with Direction Element 2.7.2 Setting Notes General The high current stage I>> of the time overcurrent protection will only be effective and available if address 113 O/C PROT. I>> is set to either directional or Non- Directional on configuration.
2.7 Definite-Time Overcurrent Protection (I>>, ANSI 50, 51, 67) with Direction Detection Current Transform- Example: Unit Connection er in the Starpoint Rated apparent power - generator = 5.27 MVA (without direction N, Mach detection) Rated voltage - generator = 6.3 kV N, Mach Direct-axis transient reactance x’...
2 Functions Figure 2-8 Definition of Parameters 1304 Phase Direction and 1305 LINE 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 pickup value results from the short-circuit current calculation.
2.7 Definite-Time Overcurrent Protection (I>>, ANSI 50, 51, 67) with Direction Detection 2.7.3 Settings The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter Setting Options Default Setting Comments 1301 O/C I>>...
2 Functions Inverse-Time Overcurrent Protection (ANSI 51V) The overcurrent time protection replicates 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 may be not promptly discon- nected thus endangering the machine.
2.8 Inverse-Time Overcurrent Protection (ANSI 51V) Figure 2-10 Pick-up Value Voltage Dependency The Ip reference value is decreased proportional to voltage decrease. Consequently for constant current I, the I/Ip ratio is increased and the trip time is reduced. Compared with the standard characteristics represented in Section 4 the tripping characteristic shifts to the left side in relation to decreasing voltage.
2 Functions Figure 2-11 Logic Diagram of the Inverse Overcurrent Time Protection without Undervoltage Influencing 7UM61 Manual C53000-G1176-C127-3...
2.8 Inverse-Time Overcurrent Protection (ANSI 51V) Figure 2-12 Logic Diagram of the Voltage Controlled Inverse Overcurrent Time Protection The changeover to the lower current pickup value on decreasing voltage (loop enable) is performed on a phase by phase basis in accordance with Table 2-3. 7UM61 Manual C53000-G1176-C127-3...
2 Functions Figure 2-13 Logic Diagram of the Voltage Restraint Inverse Time Overcurrent Protection The reduction of the current pickup threshold on decreasing voltage (control voltage allocation) is performed phase in accordance with Table 2-3. 2.8.2 Setting Notes Inverse overcurrent time protection is only effective and available if address 114 O/C General PROT.
2.8 Inverse-Time Overcurrent Protection (ANSI 51V) The current value is set at address 1402 Ip. The setting is mainly determined by the maximum operating current. Pickup due to overload should never occur, since the device in this operating mode operates as fault protection with correspondingly short tripping times and not as overload protection.
2 Functions Addr. Parameter Setting Options Default Setting Comments 1407 VOLT. INFLUENCE without without Voltage Influence Volt. controll. Volt. restraint 1408 U< 10.0 .. 125.0 V 75.0 V U< Threshold for Release 2.8.4 Information List Information Type of In- Comments formation 1883 >BLOCK O/C Ip...
2.9 Thermal Overload Protection (ANSI 49) Thermal Overload Protection (ANSI 49) The thermal overload protection prevents thermal overloading of the stator windings of the machine being protected. 2.9.1 Functional Description Thermal Profile The device calculates the excessive temperatures in accordance with a single-body thermal model, based on the following differential equation: with Θ...
2 Functions Coolant Tempera- With 7UM61 the thermal model of the considers an external temperature value. De- ture (Ambient Tem- pending on the application, this temperature can be the coolant or ambient tempera- perature) ture or, in the case of gas turbines, the entry temperature of the cold gas. The temperature to be considered can be input in one of the following ways: •...
2.9 Thermal Overload Protection (ANSI 49) The following figure shows the logic diagram for overload protection. Figure 2-14 Logic Diagram of the Overload Protection 7UM61 Manual C53000-G1176-C127-3...
2 Functions 2.9.2 Setting Notes Overload protection is only effective and accessible if address 116 Therm.Overload General is set to Enabled during configuration. If the function is not required Disabled is set. Transformers and generators are prone to damage by extended overloads. These overloads cannot and should not be detected by short-circuit protection.
2.9 Thermal Overload Protection (ANSI 49) Example: Generator and current transformer with the following data: Permissible Continuous Current I = 1.15 · I max prim N, Machine Generator Nominal Current = 483 A N Machine Current Transformer 500 A / 1 A Time Constant τ...
2 Functions A current-related alarm level is also available (address 1610 I ALARM). The level is set in secondary amperes and should be set equal to, or slightly less than, the permis- sible continuous current K-FACTOR · I . It may be used instead of the thermal alarm N sec level by setting the thermal alarm level to 100 % and is then practically inactive.
2.9 Thermal Overload Protection (ANSI 49) Figure 2-15 Tripping Characteristics for Overload Protection The run-on time to be entered at address 1616 T EMERGENCY must be sufficient to Emergency Startup ensure that after an emergency startup and dropout of binary input “>Emer.Start O/L”...
2 Functions address 1607 is set to Disabled. The allocation between the input signal and the temperature can be set at address 1608 (in °C) or 1609 (in °F) TEMP. SCAL.. For this the temperature value set here corresponds to the 100% value from Profibus DP. In the default setting, 100% (field bus) correspond to 100°C.
2.9 Thermal Overload Protection (ANSI 49) If the temperature input is used, the trip times change if the coolant temperature devi- ates from the internal reference temperature of 104.00 °F or 40 °C. The following formula can be used to calculate the trip time: with τ...
2 Functions With a supposed load current of I = 1.5 · I and a preload I = 0, for different N, Device ambient temperatures Θ the following trip times result 2.9.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings.
2 Functions 2.10 Unbalanced Load (Negative Sequence) Protection (ANSI 46) Unbalanced load protection detects unbalanced loads of three-phase induction ma- chines. Unbalanced loads create a counter-rotating field which acts on the rotor at double frequency. Eddy currents are induced at the rotor surface leading to local over- heating in rotor end zones and slot wedges.
2.10 Unbalanced Load (Negative Sequence) Protection (ANSI 46) Cool Down A settable cool-down time starts as soon as the constantly permissible unbalanced load I2> is undershot. The tripping drops out on dropout of the pickup threshold drop- out. However, the counter content is reset to zero with the cooling time parameterized at address 1705 T COOL DOWN.
2 Functions Figure 2-17 Logic diagram of the unbalanced load protection 2.10.2 Setting Notes The unbalanced load protection is only in effect and accessible if address 117 General UNBALANCE LOAD is set to Enabled during configuration. If the function is not re- quired Disabled is set.
2.10 Unbalanced Load (Negative Sequence) Protection (ANSI 46) The value for I2> is set at Address 1702. It is at the same time the pickup value for a Pickup Threshold / current warning stage whose delay time T WARN is set at address 1703. Warning Stage Example: Machine...
2 Functions Figure 2-18 Example of an Unbalanced Load Characteristic Specified by the Machine Man- ufacturer The parameter 1705 T COOL DOWN establishes the time required by the protection Cooldown Time object to cool down under admissible unbalanced load I2> to the initial value. If the machine manufacturer does not provide this information, the setting value can be cal- culated by assuming an equal value for cool-down time and heatup time of the object to be protected.
2.10 Unbalanced Load (Negative Sequence) Protection (ANSI 46) This value T COOL DOWN is set at address 1705. Definite-Time Trip- Asymmetrical faults also cause high negative phase-sequence currents. A definite- time negative phase-sequence current stage characteristic 1706 I2>> can thus ping Characteristic detect asymmetrical power system short circuits.
2.11 Underexcitation (Loss-of-Field) Protection (ANSI 40) 2.11 Underexcitation (Loss-of-Field) Protection (ANSI 40) The underexcitation protection protects a synchronous machine from asynchronous operation in the event of faulty excitation or regulation and from local overheating of the rotor. Furthermore, it avoids endangering network stability by underexcitation of large synchronous machines.
2 Functions The underexcitation protection in the 7UM61 makes available three independent, freely combinable characteristics. As illustrated in the following figure, it is possible for example to model static machine stability by means of two partial characteristics with the same time delays (T CHAR. 1 = T CHAR 2). The partial characteristics are distin- guished by the corresponding distance from the zero point (1/xd CHAR.
2.11 Underexcitation (Loss-of-Field) Protection (ANSI 40) The following figure shows the logic diagram for underexcitation protection. Figure 2-21 Logic diagram of the Underexcitation Protection 2.11.2 Setting Notes General The underexcitation protection is only effective and available if this function was set during protective function configuration (Section 2.2, address 130, UNDEREXCIT.
2 Functions The trip characteristics of the underexcitation protection in the admittance value diagram are composed of straight segments which are respectively defined by their admittance 1/xd (=coordinate distance) and their inclination angle α. The straight seg- ments (1/xd CHAR.1)/α (characteristic 1) and (1/xd CHAR.2)/α...
2.11 Underexcitation (Loss-of-Field) Protection (ANSI 40) Figure 2-23 Capability Curve of a Salient-Pole Generator, Indicated per Unit The primary setting values can be read out directly from the diagram. The related values must be converted for the protection setting. The same conversion formula can be used if the protection setting is performed with the predefined synchronous direct reactance.
2 Functions Setting example: Machine = 6.3 kV N, Mach = SN/√3 U = 5270 kVA/√3 · 6.3 kV = 483 A N Machine = 2.47 d mach (read from machine manufacturer's specifications in Figure 2-23) Current Trans- = 500 A N CT prim former Voltage trans-...
2.11 Underexcitation (Loss-of-Field) Protection (ANSI 40) Delay Times If the static limit curve consisting of the characteristics 1 and 2 is exceeded, the voltage regulator must first have the opportunity of increasing the excitation. For this reason, a warning message due to this criterion is ”long-time" delayed (at least 10 s for 3004 T CHAR.
2 Functions Addr. Parameter Setting Options Default Setting Comments 0.00 .. 60.00 sec; ∞ 3011 T SHRT Uex< 0.50 sec T-Short Time Delay (Char. & Uexc<) 3014A Umin 10.0 .. 125.0 V 25.0 V Undervoltage blocking Pickup 2.11.4 Information List Information Type of In- Comments...
2.12 Reverse Power Protection (ANSI 32R) 2.12 Reverse Power Protection (ANSI 32R) Reverse power protection is used to protect a turbo-generator unit on failure of energy to the prime mover when the synchronous generator runs as a motor and drives the turbine taking motoring energy from the network.
2 Functions Figure 2-25 Logic Diagram of the Reverse Power Protection 2.12.2 Setting Notes General Reverse power protection is only effective and available if this function was set during protective function configuration (Section 2.2, address 131, REVERSE POWER is set to Enabled.
2.12 Reverse Power Protection (ANSI 32R) The pickup value 3102 P> REVERSE is set in percent of the secondary apparent power rating SNsec = √3 · U · I . If the primary motoring energy is known, it must Nsec Nsec be converted to secondary quantities using the following formula: with...
2 Functions 2.12.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings. Addr. Parameter Setting Options Default Setting Comments 3101 REVERSE POWER Reverse Power Protection Block relay 3102 P> REVERSE -30.00 .. -0.50 % -1.93 % P>...
2.13 Forward Active Power Supervision (ANSI 32F) 2.13 Forward Active Power Supervision (ANSI 32F) The machine protection 7UM61 includes an active power supervision which monitors whether the active power undershoots one set value or overshoots a separate second set value. Each of these functions can initiate different control functions. When, for example, with generators operating in parallel, the active power output of one machine becomes so small that other generators could take over this power, then it is often appropriate to shut down the lightly loaded machine.
2 Functions 2.13.2 Setting Notes General The forward active power protection is only effective and available if this function was set on protective functions configuration (section 2.2, address 132, FORWARD POWER = to Enabled. If the function is not required Disabled is set. The address 3201 FORWARD POWER serves to switch the function ON or OFF or to block only the trip command (Block relay).
2.13 Forward Active Power Supervision (ANSI 32F) 2.13.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings. Addr. Parameter Setting Options Default Setting Comments 3201 FORWARD POWER Forward Power Supervision Block relay 3202 Pf<...
2 Functions 2.14 Impedance Protection (ANSI 21) 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 unit transformer. It thus also provides backup protection functions to the main protection of a power plant or protection equipment connected in series like generator, transformer differential and system protection de- vices.
2.14 Impedance Protection (ANSI 21) Loop Selection • The corresponding phase-earth loop is used for a 1-pole pickup. • With a 2-pole pickup, the phase-phase loop with the corresponding phase-to-phase voltage is used for impedance calculation. • With a 3-pole pickup, the phase-phase loop with the highest current value is used and with equal current amplitudes, the procedure described in the last row of the following of table is applied.
2 Functions Figure 2-27 Logic Diagram of the Pickup Stage of the Impedance Protection Tripping Characteristic The tripping characteristic of the impedance protection is a polygon (see also Figure 2-28). It is a symmetrical characteristic, even though a fault in reverse direction (neg- ative R and/or X values) is impossible provided the usual connection to the current transformers at the star-point side of the generator is used.
2.14 Impedance Protection (ANSI 21) covers the network. It should be noted that high voltage side 1-pole faults cause im- pedance measurement errors due to the star-delta connection of the unit transformer on the lower voltage side. An unwanted operation of the stage can be excluded since the fault impedances of power system faults are modeled too high.
2 Functions A drop-out can only be caused by a drop-out of the overcurrent pickup and not by exiting the tripping polygon. The following figure shows the logic diagram for the impedance protection. Figure 2-29 Logic Diagram of the Impedance Protection 2.14.2 Setting Notes General Machine impedance protection is only effective and available if enabled during config-...
2.14 Impedance Protection (ANSI 21) Pickup The maximum load current during operation is the most important criterion for setting overcurrent pickup. A pickup by an overload must be excluded! For this reason, the 3302 IMP I> pickup value must be set above the maximum (over) load current to be expected.
2 Functions The following formula is generally valid for the primary impedance (with limiting to the unit transformer): with Protection zone reach [%] Relative transformer short-circuit voltage [%] Rated transformer power [MVA] Machine-side rated transformer voltage [kV] The derived primary impedances must be converted for the secondary side of the current and voltage transformers.
2.14 Impedance Protection (ANSI 21) This results to a 70 % reach for zone 1: The following secondary side setting value of zone 1 results at address 3306 ZONE Note: The following ratio would result from the connection of a 5 A device to a 5 A current transformer: Likewise the following primary reactance results for a 100 % reach for zone 2: 7UM61 Manual...
2 Functions The following secondary side setting value of zone 2 results at address 3310 ZONE Figure 2-30 Time Grading for Machine Impedance Protection – Example The Z1B overreach zone (address 3308 ZONE Z1B) is an externally controlled stage. Z1B Overreach Zone It does not influence the Z1 zone normal stage.
2.15 Undervoltage Protection (ANSI 27) 2.15 Undervoltage Protection (ANSI 27) Undervoltage protection detects voltage dips in electrical machines and avoids inad- missible operating states and possible loss of stability. Two-pole short circuits or earth faults cause asymmetrical voltage collapse. Compared with three single phase mea- suring systems, the detection of the positive phase-sequence system is not influenced by these procedures and is particularly advantageous for assessing stability problems.
2 Functions Figure 2-31 Logic diagram of the undervoltage protection 2.15.2 Setting Notes General The undervoltage protection is only effective and available if this function was set during protective function configuration (Section 2.2, address 140, UNDERVOLTAGE is set to Enabled. If the function is not required Disabled is set. Address 4001 UNDERVOLTAGE serves to switch the function ON or OFF or to block only the trip command (Block relay).
2.15 Undervoltage Protection (ANSI 27) 2.15.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings. Addr. Parameter Setting Options Default Setting Comments 4001 UNDERVOLTAGE Undervoltage Protection Block relay 4002 U< 10.0 .. 125.0 V 75.0 V U<...
2 Functions 2.16 Overvoltage Protection (ANSI 59) Overvoltage protection serves to protect the electrical machine and connected electri- cal plant components from the effects of inadmissible voltage increases. Overvoltages can be caused by incorrect manual operation of the excitation system, faulty operation of the automatic voltage regulator, (full) load shedding of a generator, separation of the generator from the system or during island operation.
2.16 Overvoltage Protection (ANSI 59) Address 4107 VALUES serves to specify the measured quantities used by the protec- Settings tion 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).
2.17 Frequency Protection (ANSI 81) 2.17 Frequency Protection (ANSI 81) The frequency protection function detects abnormally high and low frequencies of the generator. If the frequency lies outside the admissible range, appropriate actions are initiated, such as separating the generator from the system. A decrease in system frequency occurs when the system experiences an increase in real power demand, or when a frequency or speed control malfunction occurs.
2 Functions Figure 2-33 Logic diagram of the frequency protection 2.17.2 Setting Notes Frequency protection is only effective and available if address 142 FREQUENCY General Prot. is set to Enabled during configuration. If the function is not required Disabled is set. Address 4201 O/U FREQUENCY serves to switch the function ON or OFF or to block only the trip command (Block relay).
2.17 Frequency Protection (ANSI 81) specifications. In this context, frequency decrease protection ensures the power sta- tion’s own demand by disconnecting it from the power system on time. The turbo reg- ulator then regulates the machine set to nominal speed so that the station's own re- quirements can be continuously provided at rated frequency.
2.18 Overexcitation (Volt/Hertz) Protection (ANSI 24) 2.18 Overexcitation (Volt/Hertz) Protection (ANSI 24) Overexcitation protection is used to detect inadmissibly high induction in generators and transformers, especially in power station unit transformers. Overexcitation protec- tion must intervene when the admissible induction level for the protected object (e.g. unit transformer) is exceeded.
2 Functions spond to the actual thermal behaviour of the object to be protected, any desired char- acteristic can be implemented by entering customer-specific trip times for the specified U/f overexcitation values. Intermediate values are determined by a linear interpolation within the device.
2.18 Overexcitation (Volt/Hertz) Protection (ANSI 24) Figure 2-35 Logic Diagram of the Overexcitation Protection 2.18.2 Setting Notes Overexcitation protection is only effective and available if address 143 OVEREXC. General PROT. is set to Enabled during configuration. If the function is not required Disabled is set.
Figure 2-36 Thermal tripping time characteristic (with presettings) The characteristic of a Siemens standard transformer was selected as a presetting for the parameters 4306 to 4313. If the protection object manufacturer did not provide any information, the preset standard characteristic should be used. Otherwise any trip characteristic can be specified by point-wise entering of parameters for up to 7 straight segments.
2 Functions 2.19 Rate-of-Frequency-Change Protection df/dt (ANSI 81R) 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 command can be issued even before the pickup threshold of the frequency protection (see Section 2.17) is reached.
2.19 Rate-of-Frequency-Change Protection df/dt (ANSI 81R) Figure 2-37 Logic Diagram of the Rate-of-Frequency-Change Protection 2.19.2 Setting Notes General The rate-of-frequency-change protection is only effective and accessible if during the configuration Address 145 df/dt Protect. has been set accordingly. 2 or 4 stages can be selected.
2 Functions The following relations can be used as an example for estimation. They apply for the change rate at the beginning of a frequency change (approx. 1 second). Significance: Nominal Frequency ∆P Active power change ∆P = P – P Consumption Generation Nominal apparent power of the machines...
2.19 Rate-of-Frequency-Change Protection df/dt (ANSI 81R) Setting changes are necessary e.g. to obtain a great dropout difference. For the de- tection of very small frequency changes (< 0.5 Hz/s), the default setting of the mea- suring window should be extended. This is to improve the measuring accuracy. df/dt HYSTERES.
2.20 Jump of Voltage Vector 2.20 Jump of Voltage Vector Sometimes consumers with their own generating plant feed power directly into a net- work. The incoming feeder is usually the ownership boundary between the network utility and these consumers/producers. A failure of the input feeder line for example due to a three-pole automatic reclosure, can result in a deviation of the voltage or fre- quency at the feeding generator which is a function of the overall power balance.
2 Functions Measuring Princi- The vector of the positive sequence system voltage is calculated from the phase-to- earth voltages, and the phase angle change of the voltage vector is determined over a delta interval of 2 cycles. The presence of a phase angle jump indicates an abrupt change of current flow.
2.20 Jump of Voltage Vector The vector jump function becomes ineffective on exiting the admissible frequency band. The same applies for the voltage. In such a case the limiting parameters are U MIN and U MAX. If the frequency or voltage range is not maintained, the logic generates a logical 1, and the reset input is continuously active.
2 Functions vector. The value to be set must be established in accordance with the particular power system. This can be done on the basis of the simplified equivalent circuit of the diagram “voltage vector after a load shedding” in Section 2.20, or using network cal- culation software.
2.20 Jump of Voltage Vector 2.20.4 Information List Information Type of In- Comments formation 5581 >VEC JUMP block >BLOCK Vector Jump 5582 VEC JUMP OFF Vector Jump is switched OFF 5583 VEC JMP BLOCKED Vector Jump is BLOCKED 5584 VEC JUMP ACTIVE Vector Jump is ACTIVE 5585 VEC JUMP Range...
2 Functions 2.21 90-%-Stator Earth Fault Protection (ANSI 59N, 64G, 67G) The stator earth fault protection detects earth faults in the stator windings of three- phase machines. The machine can be operated in busbar connection (directly con- nected to the network) or in unit connection (via unit transformer). The criterion for the occurrence of an earth fault is mainly the emergence of a displacement voltage, or ad- ditionally with busbar connection, of an earth current.
2.21 90-%-Stator Earth Fault Protection (ANSI 59N, 64G, 67G) Figure 2-41 Unit Connection with Earthing Transformer Figure 2-42 Unit Connection with Earthing Transformer Earth Current Di- For machines in busbar connection, it is not possible to differentiate between network rection Detection earth faults and machine earth faults using the displacement voltage alone.
2 Functions Figure 2-43 Earth Fault Direction Detection with Busbar Connection Consequently, the loading resistor must be situated on the other side of the measure- ment location (current transformer, toroidal current transformer) viewed from the ma- chine. The earthing transformer is preferably connected to the busbar. Apart from the magnitude of the earth fault current, the direction of this current in relation to the dis- placement voltage is needed for the secure detection of a machine earth fault with busbar connection.
2.21 90-%-Stator Earth Fault Protection (ANSI 59N, 64G, 67G) On the occurrence of an 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 for detecting an earth fault when the circuit breaker is open, the earth current detection can be switched off for a certain time via a binary input.
2 Functions Figure 2-46 Logic Diagram of 100% Stator Earth Fault Protection 2.21.2 Setting Notes The 90% stator earth fault protection is only fully effective and available if address 150 General S/E/F PROT. is set to directional, non-dir. U0 or non-dir. U0&I0 during configuration.
2.21 90-%-Stator Earth Fault Protection (ANSI 59N, 64G, 67G) voltage which is coupled in at full network displacement. The setting value is finally de- termined during commissioning with primary values. The stator earth fault trip is delayed by the time set under address 5005 T S/E/F. Delay For the delay time, the overload capacity of the load equipment must be considered.
2 Functions Referred to the 6.3 kV side, this results in The secondary current of the toroidal transformer supplies to the input of the device For a protected zone of 90 %, the protection should already operate at 1/10 of the full displacement voltage, whereby only 1/10 of the earth fault current is generated: In this example 3I0>...
2.21 90-%-Stator Earth Fault Protection (ANSI 59N, 64G, 67G) Information Type of In- Comments formation 5186 U0> picked up Stator earth fault: U0 picked up 5187 U0> TRIP Stator earth fault: U0 stage TRIP 5188 3I0> picked up Stator earth fault: I0 picked up 5189 Uearth L1 Earth fault in phase L1...
2 Functions 2.22 Sensitive Earth Fault Protection (ANSI 51GN, 64R) The highly sensitive earth fault protection detects earth faults in systems with isolated or high-impedance earthed starpoint. This stage operates with the magnitude of the earth current. It is intended for use where the earth current amplitude gives an indica- tion of the earth fault.
2.22 Sensitive Earth Fault Protection (ANSI 51GN, 64R) Figure 2-47 Logic Diagram of the Sensitive Earth Fault Protection Figure 2-48 Application Case as Rotor Earth Fault Protection (7XR61 – Series Device for Rotor Earth Fault Protection; 3PP13 – from Uexc > 150 V, Resistors in 7XR61 are then to be Shorted!) 7UM61 Manual C53000-G1176-C127-3...
2 Functions 2.22.2 Setting Notes Sensitive earth fault detection can only be effective and available if address 151 O/C General PROT. Iee> is set to Enabled during configuration. If one of the options with current evaluation was selected during the configuration of the 90% stator earth fault protec- tion (150 S/E/F PROT., see Section 2.2.2) the sensitive current measuring input of the 7UM61 device is allocated.
2.22 Sensitive Earth Fault Protection (ANSI 51GN, 64R) Use as Earth Short- For low-voltage machines with incorporated neutral conductor or machines with low- Circuit Protection impedance earthed starpoint, the time-overcurrent protection of the phase branches already is an earth short-circuit protection, since the short-circuit current also flows through the faulty phase.
2 Functions 2.23 100-%-Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) As described in Section 2.21, the measuring procedure based on the fundamental wave of the displacement voltage serves to protect maximally 90 % to 95 % of the stator winding.
2.23 100-%-Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) Different measuring procedures are applied, depending on how the displacement voltage is detected (configuration parameter 223 UE CONNECTION): 1. neutr. transf.: Connection of the U input to the voltage transformer at the machine starpoint 2.
2 Functions Figure 2-50 Logic Diagram of 100% Stator Earth Fault Protection 2.23.2 Setting Notes General The 100% Stator earth fault protection is only fully effective and available if address 152 SEF 3rd HARM. is set to Enabled during configuration. If the function is not required Disabled is set.
2.23 100-%-Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) Operating Range Due to the strong dependency of the measurable 3rd harmonic on the corresponding operating point of the generator, the working range of the 100% stator earth fault pro- tection is only enabled above the active-power threshold set via 5205 P min >...
2 Functions 2.24 Motor Starting Time Supervision (ANSI 48) When the 7UM61 is used to protect a motor, the startup time monitoring feature sup- plements overload protection (see Section 2.9) by protecting the motor against ex- tended startup durations. In particular, rotor-critical high-voltage motors can quickly be heated above their thermal limit if multiple consecutive startup attempts are made.
2.24 Motor Starting Time Supervision (ANSI 48) Figure 2-51 Trip Time Depending on Startup Current Therefore, if the starting current I actually measured is smaller (or larger) than the (Parameter START. CURRENT) entered at Address nominal starting current I StartCurr. 6502, the actual tripping time t is prolonged (or shortened) accordingly (see also Trip...
2 Functions Figure 2-52 Logic Diagram of the Motor Startup Time Monitoring 2.24.2 Setting Notes Motor Starting Time Supervision is only effective and available if address 165 General STARTUP MOTOR was set to Enabled during configuration. If the function is not re- quired Disabled is set.
2.24 Motor Starting Time Supervision (ANSI 48) Example: Motor with the following data: Rated voltage = 6600 V Rated current = 126 A Mot.nom Starting current = 624 A StartCurr. Long-Term Current Rating = 135 A Startup Duration for I = 8.5 s StartCurr.
2 Functions 2.24.3 Settings The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter Setting Options Default Setting Comments 6501 STARTUP MOTOR Motor Starting Time Su- pervision Block relay 6502 START.
2.25 Restart Inhibit for Motors (ANSI 66, 49Rotor) 2.25 Restart Inhibit for Motors (ANSI 66, 49Rotor) The rotor temperature of a motor generally remains well below its maximum admissi- ble temperature during normal operation and also under increased load conditions. However, with startups and resulting high startup currents caused by small thermal time constants it may suffer more thermal damage than the rotor.
2 Functions Although the heat distribution at the rotor cage bars can range widely during motor startup, the different maximum temperatures in the rotor do not necessarily affect the motor restart inhibit (see Figure 2-53). It is much more important to establish a thermal profile, after a complete motor startup, that is appropriate for protection of the motor’s thermal state.
2.25 Restart Inhibit for Motors (ANSI 66, 49Rotor) τ – rotor time constant, calculated internally: τ · (n – n ) · I Start cold warm Start where: = Startup time in s Start = Startup current in pu Start Θ...
2 Functions The following figure shows the logic diagram for the restart inhibit. Figure 2-54 Logic diagram of the Restart Inhibit 2.25.2 Setting Notes Restart inhibit is only effective and available if address 166 RESTART INHIBIT was General set to Enabled during configuration. If the function is not required Disabled is set. Address 6601RESTART INHIBIT serves to switch the function ON or OFF or to block only the trip command (Block relay).
2.25 Restart Inhibit for Motors (ANSI 66, 49Rotor) Required Charac- The user communicates to the device the characteristic motor values supplied by the teristic Values manufacturer, which are necessary for calculation of the rotor temperature. These values include the startup current Istart, the nominal motor current IMot.nom, the maximum admissible startup time T START MAX (address 6603), the number of ad- missible restart attempts under cold (n ) and (n...
2 Functions For the rotor temperature leveling time, a setting of approx. T EQUAL = 1.0 min has proven to be a practical value. The value for the minimum inhibit time T MIN. INHIBIT depends on the requirements of the motor manufacturer, or on the system conditions.
2.25 Restart Inhibit for Motors (ANSI 66, 49Rotor) In Figure 2-56, 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 fol- lowing the first startup attempt, the thermal profile is "frozen".
2 Functions Addr. Parameter 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 2.25.4 Information List...
2.26 Breaker Failure Protection (ANSI 50BF) 2.26 Breaker Failure Protection (ANSI 50BF) The breaker failure protection function monitors proper switchoff of a circuit breaker. In machine protection it is typically relates to the mains breaker. 2.26.1 Functional Description Mode of Operation The following two criteria are available for circuit breaker failure protection: •...
2 Functions If the binary input of the circuit breaker auxiliary contact is inactive, only the current criterion is effective. The breaker failure protection cannot become active with a trip- ping signal if the current is below the CIRC. BR. I> threshold. Two-Channel To increase security and to protect against possible disturbance impulses the binary Feature...
2.26 Breaker Failure Protection (ANSI 50BF) Figure 2-58 Logic Diagram of the Breaker Failure Protection 2.26.2 Setting Notes General Breaker failure protection is only effective and available if address 170 BREAKER FAILURE is set to Enabled during configuration. If the function is not required Disabled is set.
2 Functions However the pickup value should not be selected lower than necessary, as a too sen- sitive setting risks prolonging the drop-out time due to balancing processes in the current transformer secondary circuit during switchoff of heavy currents. The time delay is entered at address 7004 TRIP-Timer and is based on the Time Delay maximum breaker disconnecting time, the dropout time of overcurrent detection plus a safety margin which takes into consideration delay time runtime deviation.
2 Functions 2.27 Inadvertent Energization (ANSI 50, 27) The inadvertent energizing protection serves to limit damage by accidental connection of the stationary or already started, but not yet synchronized generator, by fast actua- tion of the mains breaker. A connection to a stationary machine is equivalent to con- nection to a low-ohmic resistor.
2.27 Inadvertent Energization (ANSI 50, 27) Figure 2-60 Logic Diagram of the Inadvertent Energizing Protection (Dead Machine Protec- tion) 2.27.2 Setting Notes General Inadvertent energizing protection is only effective and available if address 171 INADVERT. EN. is set to Enabled during configuration. If the function is not required Disabled is set.
2 Functions The following figure illustrates the course of events during an unwanted connection at machine standstill and, contrast to this, during a voltage collapse on short circuit close to generator terminals. Figure 2-61 Chronological Sequences of the Inadvertent Energizing Protection 2.27.3 Settings The table indicates region-specific presettings.
2.27 Inadvertent Energization (ANSI 50, 27) 2.27.4 Information List Information Type of In- Comments formation 5533 >BLOCK I.En. >BLOCK inadvertent energ. prot. 5541 I.En. OFF Inadvert. Energ. prot. is swiched OFF 5542 I.En. BLOCKED Inadvert. Energ. prot. is BLOCKED 5543 I.En.
2 Functions 2.28 Measurement Supervision The device is equipped with extensive monitoring capabilities - both hardware and software. In addition, the measured values are also constantly checked for plausibility, so that the current and voltage transformer circuits are largely integrated into the mon- itoring.
2.28 Measurement Supervision Measurement Value In the current paths there are three input transformers; the digitized sum of the trans- Acquisition – Cur- former currents of one side must be almost zero for generators with isolated starpoint rents during earth-fault-free operation. A current circuit fault is detected if | >...
2 Functions Note Voltage sum monitoring is only effective if an external displacement voltage is con- nected at the displacement voltage measuring input and this is also notified via the pa- rameter 223 UE CONNECTION to the device. Voltage sum monitoring can operate properly only if the adaptation factor Uph / Udelta at address 225 has been correctly configured (see Section 2.3.1).
2.28 Measurement Supervision Thereby I is the largest of the three phase currents I the smallest. The symmetry factor BAL. FACTOR I represents the allowable asymmetry of the phase currents while the limit value BALANCE I LIMIT is the lower limit of the operating range of this monitoring (see the following figure).
2 Functions Current and Voltage To detect swapped phase connections in the voltage and current input circuits, the Phase Sequence phase sequence of the phase-to-phase measured voltages and the phase currents are checked by monitoring the sequence of same polarity zero transitions of the volt- ages.
2.28 Measurement Supervision Measuring Principle The measuring voltage failure detection is based on the fact a significant negative- for 1–Pole and 2– phase sequence system is formed in the voltage during a 1- or 2-pole voltage failure, Pole Fuse Failures without influencing the current.
2 Functions transformer error and the monitoring switching can be blocked. The separate under- voltage protection must be set non-delayed and should also evaluate the positive- phase sequence system of the voltages (e.g. 7RW600). Voltage at U Input Depending on how U is connected, it may be necessary to block the voltage mea- surement of this input.
2.28 Measurement Supervision Malfunction Responses of the Monitoring Functions Depending on the type of malfunction detected, an indication is sent, a restart of the processor system initiated, or the device is taken out of service. After three unsuccess- ful restart attempts, the device is also taken out of service. The operational readiness NC contact operates to indicate the device is malfunctioning.
2 Functions 2.28.2 Setting Notes Measured value monitoring can be activated at address 8101 MEASURE. SUPERV ON Measured Value or OFF. In addition the sensitivity of measured value monitorings can be modified. Monitoring Default values are set at the factory, which are sufficient in most cases. If especially high operating asymmetries in currents and/or voltages is to be expected for the ap- plication, or if it becomes apparent during operation that certain monitoring functions activate sporadically, then the setting should be made less sensitive.
2 Functions 2.29 Trip Circuit Supervision The Multi-Functional Protective Relay 7UM61 is equipped with an integrated trip circuit supervision. Depending on the number of available binary inputs (connected or not to a common potential), monitoring with one or two binary inputs can be selected. If allocation of the required binary inputs does not match the selected monitoring type, then an indication to this effect is generated (“TripC ProgFail”).
2.29 Trip Circuit Supervision circuit has been interrupted, a short-circuit exists in the trip circuit, battery voltage failure occurs, or malfunctions occur with the circuit breaker mechanism. Accordingly it is used as monitoring criterion. Table 2-8 Condition Table for Binary Inputs, Depending on RTC and CB Position Trip contact Circuit breaker AuxCont 1...
2 Functions Depending on the conditions of the trip contact and the circuit breaker, the binary inputs are activated (logical condition "H" in the following Table), or not activated (log- ical condition "L"). Table 2-9 Condition Table for Binary Inputs, Depending on RTC and CB Position Trip Circuit AuxCont...
2.29 Trip Circuit Supervision Figure 2-70 Principle of Trip Circuit Monitoring with One Binary Input During normal operation, the binary input is activated (logical condition "H") when the trip contact is open and the trip circuit is intact, because the monitoring circuit is closed by either the circuit breaker auxiliary contact (if the circuit breaker is closed) or through the bypass resistor R.
2 Functions The following figure shows the logic diagram for the message that can be generated by the trip circuit monitor, depending on the control settings and binary inputs. Figure 2-72 Message Logic for the Trip Circuit Monitor 2.29.2 Setting Notes The function is only in effective and available if address 182 Trip Cir.
2.29 Trip Circuit Supervision When using only one binary input, a resistor R is inserted into the circuit on the system side, instead of the missing second binary input. Through appropriate sizing of the re- sistor and depending on the system conditions, a lower control voltage can often be sufficient.
2 Functions Example: ® 1.8 mA (from the SIPROTEC 7UM61) BI (HIGH) 19 V for delivery setting for nominal voltages 24/48/60 V (for device BI min 7UM61) 88 V for delivery setting for nominal voltages 110/125/220/250 V) (for device 7UM61) 110 V (system / trip circuit) Ctrl 500 Ω...
2.30 Threshold supervision 2.30 Threshold supervision This function monitors the thresholds of selected measured values (for overshoot or undershoot). The processing speed of this function is so high that it can be used for protection applications. The necessary logical combinations can be implemented by means of CFC.
2 Functions Measured Value Scaling Explanation I0/I · 100 % The zero sequence current is determined N,sec (Zero sequence from the phase currents on the basis of the current system) definition equation for symmetrical compo- nents. The calculation is performed once per cycle.
2.30 Threshold supervision Figure 2-73 Logic of the Threshold Supervision The figure shows that the measured values can be freely allocated to the threshold supervision blocks. The dropout ratio for the MVx> stage is 0.95 or 1 %. Accordingly, it is 1.05 or 1 % for the MVx< stage. 2.30.2 Setting Notes Threshold supervisions are only effective and available if addresses 185 THRESHOLD General...
2 Functions The measured values for power P, Q and ∆P as well as the phase angle, can be either positive or negative. If a negative threshold value is to be monitored, the number line definition applies (–10 is smaller than –5). Example: The measured quantity P (active power) is allocated to MV1>...
2.30 Threshold supervision Addr. Parameter Setting Options Default Setting Comments 8503 MEAS. VALUE 2< Disabled Disabled Measured Value for Threshold MV2< Delta P 8504 THRESHOLD MV2< -200 .. 200 % 100 % Pickup Value of Measured Value MV2< 8505 MEAS. VALUE 3> Disabled Disabled Measured Value for Threshold...
2 Functions Addr. Parameter Setting Options Default Setting Comments 8511 MEAS. VALUE 6< Disabled Disabled Measured Value for Threshold MV6< Delta P 8512 THRESHOLD MV6< -200 .. 200 % 100 % Pickup Value of Measured Value MV6< 2.30.4 Information List Information Type of In- Comments...
2.31 External Trip Functions 2.31 External Trip Functions Any signals from external protection or supervision units can be incorporated into the processing of the digital machine protection 7UM61 via binary inputs. Like the internal signals, they can be signaled, time delayed, transmitted to the trip matrix, and also in- dividually blocked.
2 Functions 2.32 RTD-Box Up to 2 thermoboxes with a total of 12 measuring points can be used for temperature detection and evaluated by the protection device. In particular they enable the thermal status of motors, generators and transformers to be monitored. Rotating machines are additionally monitored for a violation of the bearing temperature thresholds.
2.32 RTD-Box Figure 2-75 Logic Diagram for Temperature Processing 2.32.2 Setting Notes General The temperature detection function is only effective and accessible if it has been as- signed to an interface during the configuration of the protection functions (Section 2.2). At address 190 RTD-BOX INPUT the RTD-box(es) is allocated to the interface at which it will be operated (e.g.
2 Functions Address 9012 RTD 1 LOCATION informs the device on the mounting location of RTD 1. You can choose between Oil, Ambient, Winding, Bearing and Other. This ® setting is only possible via DIGSI at "Additional Settings". Furthermore, you can set an alarm temperature and a tripping temperature. Depend- ing on the temperature unit selected in the Power System Data (Section 2.2.2 in address 276 TEMP.
2.32 RTD-Box 2.32.3 Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings. Addr. Parameter Setting Options Default Setting Comments Pt 100 Ω 9011A RTD 1 TYPE Not connected RTD 1: Type Pt 100 Ω Ni 120 Ω...
2.33 Phase Rotation Reversal 2.33 Phase Rotation Reversal A phase rotation feature via binary input and parameter is implemented in the 7UM61 device. This permits all protection and monitoring functions to operate correctly even with phase rotation reversal, without the need for two phases to be reversed. If an anti-clockwise rotating phase sequence permanently exists, this should be entered in the power system data (see Section 2.3).
2 Functions Influence on Pro- Swapping phases with a phase sequence inversion affects exclusively calculation of tective Functions positive and negative sequence quantities, as well as phase-to-phase voltages by subtraction of one phase-to-ground voltage from another, so that phase related indi- cations, fault values, and operating measurement values are not distorted.
2.34 Protection Function Control 2.34 Protection Function Control The function logic coordinates the sequence of both the protective and ancillary func- tions, processes the functional decisions, and data received from the system. In particular, this includes: • Pick-up logic • Tripping logic •...
2 Functions 2.34.2 Tripping Logic of Device This section describes general pickup and terminating of the trip command. 184.108.40.206 Functional Description General Trip The trip signals for all protective functions are OR-combined and generate the message “Relay TRIP”. This annunciation, like individual trip indications, can be allocated to an LED or an output relay.
2.34 Protection Function Control 220.127.116.11 Setting Notes The minimum trip command duration 280 TMin TRIP CMD was described already in Command Duration Section 2.3. This setting applies to all protective functions that initiate tripping. 2.34.3 Fault Display on the LEDs/LCD The storage of messages masked to local LEDs, and the maintenance of spontaneous messages, can be made dependent on whether the device has issued a trip signal.
2 Functions 2.34.4 Statistics Tripping commands from the device are counted. Currents of the last disconnections instigated by the device are logged. Disconnected fault currents are accumulated for each breaker pole. 18.104.22.168 Functional Description Number of Trips The number of trips initiated by the 7UM61 is counted, as long as the position of the circuit breaker is monitored via binary inputs.
2.34 Protection Function Control 22.214.171.124 Information List Information Type of In- Comments formation #of TRIPs= IPZW Number of TRIPs #of TRIPs= IPZW Number of TRIPs >BLOCK Op Count >BLOCK Op Counter 1020 Op.Hours= Counter of operating hours Σ L1: 1021 Accumulation of interrupted current L1 Σ...
2 Functions 2.35 Ancillary Functions Chapter Ancillary Functions describes the general device functions. 2.35.1 Processing of Annunciations After occurrence of a system fault, data regarding the response of the relay and the measured quantities should be saved for analysis purposes. For this reason indication processing is done in three ways: 126.96.36.199 Functional Description Displays and Binary Outputs (output relays)
2.35 Ancillary Functions The device is 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. These indications can be displayed on the LCD at any time by keypad selection, or transferred to the PC via the serial service.
2 Functions Retrievable Indica- The indications of the last eight faults can be retrieved and output. Where a generator tions fault causes several protective functions to pick up, the fault is considered to include all that occurred between pickup of the first protective function and dropout of the last protective function.
2.35 Ancillary Functions 2.35.2 Measurement A series of measured values and the values derived from them are constantly avail- able for call up on site, or for data transfer (See table 2-12, as well as the following list). 188.8.131.52 Functional Description Display of Mea- The operational measured values listed in Table 2-12 can be read out as secondary, sured Values...
2 Functions Measured Secondary Primary Values P, Q, S ϕ in °el ϕ in °el ϕ in °el Angle PHI cos ϕ cos ϕ cos ϕ · 100 in % Power factor Frequency f in Hz f in Hz R, X no display of percentage measured values in V...
2.35 Ancillary Functions In addition, the following are be available: Minimum and Minimum and maximum values for the positive-sequence components I and U , the Maximum Values active power P, reactive power Q, in primary values, of the frequency f and of the 3rd harmonic content in the displacement voltage in secondary values U .
2 Functions Table 2-13 Operating Ranges for Synchronous and Asynchronous Machines Synchronous generator Synchronous motor Asynchronous generator Asynchronous motor The table 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.
2.35 Ancillary Functions 184.108.40.206 Information List Information Type of In- Comments formation IL1 = I L1 IL2 = I L2 IL3 = I L3 I1 = I1 (positive sequence) I2 = I2 (negative sequence) UL1E= U L1-E UL2E= U L2-E UL3E= U L3-E UL12=...
2 Functions their measured and metered values have been set accordingly in CFC (see SIPRO- TEC 4 System Description /1/). 220.127.116.11 Setting Notes Limit Values Limit settings are entered under MEASUREMENTS in the sub-menu LIMITS SETTING by overwriting the default values. 18.104.22.168 Information List Information Type of In-...
2.35 Ancillary Functions by appropriate programs in the central device. Currents and voltages are referred to their maximum values, scaled to their rated values and prepared for graphic presen- tation. Binary signal traces (marks) of particular events e.g. "pickup", "tripping" are also recorded.
2 Functions Addr. Parameter Setting Options Default Setting Comments POST REC. TIME 0.05 .. 0.50 sec 0.10 sec Captured Waveform after Event 0.10 .. 5.00 sec; ∞ BinIn CAPT.TIME 0.50 sec Capture Time via Binary Input 22.214.171.124 Information List Information Type of In- Comments formation...
2.35 Ancillary Functions The time display may be set using either the European format (DD.MM.YYYY) or the US format (MM/DD/YYYY). To preserve the internal battery, this switches off automatically after some hours in the absence of an auxiliary voltage supply. 2.35.6 Commissioning Aids Device data sent to a central or master computer system during test mode or commis- sioning can be influenced.
2 Functions ® Checking the The binary inputs, outputs, and LEDs of a SIPROTEC 4 device can be individually Binary Inputs and and precisely controlled in DIGSI. This feature can be used, for example, to verify Outputs control wiring from the device to substation equipment (operational checks), during commissioning.
2.36 Command Processing 2.36 Command Processing ® A control command process is integrated in the SIPROTEC 7UM61 to coordinate the operation of circuit breakers and other equipment in the power system. Control commands can originate from four command sources: • Local operation using the keypad on the local user interface of the device ®...
2 Functions Operation using the Control of switching devices can be performed via the serial system interface and a System Interface connection to the switchgear control system. For this the required peripherals physi- cally must exist both in the device and in the power system. Within the device also spe- ®...
2 Functions 2.36.4 System Interlocking Interlocking can be executed by the user-defined logic (CFC). 126.96.36.199 Functional Description ® Interlocked / Non- The configurable command checks in the SIPROTEC 4 devices are also called "stan- ® interlocked Switch- dard interlocking". These checks can be activated via DIGSI (interlocked switch- ing/tagging) or deactivated (non-interlocked).
2.36 Command Processing Standard Interlock- The standard interlockings contain the following fixed programmed tests for each ing (fixed program- switching device, which can be individually enabled or disabled using parameters: ming) • Device Status Check (set = actual): The switching command is rejected, and an error indication is displayed if the circuit breaker is already in the set position.
2 Functions Figure 2-82 Standard interlockings The following figure shows the configuration of the interlocking conditions using ® DIGSI 7UM61 Manual C53000-G1176-C127-3...
2.36 Command Processing ® Figure 2-83 DIGSI –dialog box for setting the interlocking conditions For devices with operator panel the display shows the configured interlocking reasons. They are marked by letters explained in the following table. Table 2-14 Command types and corresponding messages Interlocking Commands Abbrev.
2 Functions Enabling Logic via For the bay interlocking a control logic can be structured via the CFC. Via specific release conditions the information "information released” or "bay interlocked” are available (e.g. object "52 Close" and "52 Open" with the data values: ON / OFF). Switching Authori- The interlocking condition "Switching Authority"...
2.36 Command Processing Table 2-15 Interlocking logic ® Current Switch- DIGSI Command issued Command issued Command ing Authority switching with SC =LOCAL from SC=LOCAL or with SC=DIG- ® Status authority: REMOTE LOCAL (ON) not logged on not allocated interlocked - "inter- interlocked - ®...
2 Functions Interlocking conditions can be programmed separately for device control CLOSE and/or OPEN. The enable information with the data "switching device is interlocked (OFF/NV/FLT) or enabled (ON)" can be set up, • directly, using a single point or double point indication, key-switch, or internal indi- cation (marking), or •...
2.36 Command Processing 2.36.5 Command Logging/Acknowledgement During the processing of the commands, independent of the further message routing and processing, command and process feedback information are sent to the message processing centre. These messages contain information on the cause. With the cor- responding allocation (configuration) these messages are entered in the event list, thus serving as a report.
Mounting and Commissioning This chapter is intended for experienced commissioning staff. They should be familiar with the commissioning of protection and control equipment, with operation of the power system network and with the safety rules and regulations. Certain adaptations of the hardware to the power system specifications may be necessary. For primary testing, the object to be protected (generator, motor, transformer) must be started up and in put into service.
3 Mounting and Commissioning Mounting and Connections General WARNING! Warning of improper transport, storage, installation or erection of the device. Failure to observe these precautions can result in death, personal injury or substantial property damage. Unproblematic and safe use of this device depends on proper transport, storage, in- stallation and erection of the device taking into account the warnings and instructions of the device manual.
3.1 Mounting and Connections The factor 213 FACTOR IEE considers the transformation ratio between the primary and the secondary side of the summation current transformer when using the sensitive current input in the corresponding connection example. Example: Summation current transformer 60 A / 1 A Matching factor for sensitive earth fault current detection: FACTOR IEE = 60 In the appendix “the busbar system with low-ohmic earthing”...
3 Mounting and Commissioning resistance. The higher secondary voltage thereby resulting can be reduced by a voltage divider. Address 223 UE CONNECTION is set to neutr. transf.. Figure “Voltage Transformer Connections for Two Voltage Transformers in Open Delta Connection (V Connection)” in Appendix A.3 shows how a connection is made with only two system-side voltage transformers in open delta connection (V connection).
3.1 Mounting and Connections Auxiliary Voltage There are different power supply voltage ranges for the auxiliary voltage (refer to the Ordering Information in Appendix). The versions for 60/110/125 VDC and 110/125/220/250 VDC, 115 VAC are interchangeable by altering jumper settings. Jumper setting allocation to the rated voltage ranges, and their location on the PCB are described in this section under the margin title "Processor Board B-CPU".
3 Mounting and Commissioning Replacing Interfac- The serial interfaces can only be exchanged in the versions for panel flush mounting and cubicle mounting. Which interfaces can be exchanged, and how this is done, is described in this Section under the margin title “Replacing Interface Modules”. Terminating Resis- For reliable data transmission the RS 485 bus or the electrical Profibus DP must be tors for RS485 and...
3.1 Mounting and Connections To perform work on the PCBs, such as checking or moving switching elements or re- placing modules, proceed as follows: • Prepare area of work: Provide a suitable underlay for electrostatically sensitive components (ESD). Also the following tools are required: –...
3 Mounting and Commissioning Figure 3-1 7UM611: Front view with housing size 1/3 after removal of the front cover (sim- plified and scaled down). Figure 3-2 7UM612: Front view with housing size 1/2 after removal of the front cover (sim- plified and scaled down) 7UM61 Manual C53000-G1176-C127-3...
3.1 Mounting and Connections 188.8.131.52 Switch Elements on the PCBs Processor board There are two different releases of the B–CPU board a different layout and setting of B–CPU for the jumpers. The following figure depicts the layout of the PCB for processor board 7UM61.../BB version up to 7UM61.../BB.
3 Mounting and Commissioning For devices up to release 7UM61.../BB check the jumpers for the set nominal voltage of the integrated power supply according to Table 3-1, the quiescent state of the life contact according to Table 3-2 and the selected pickup voltages of the binary inputs BI1 through BI7 according to Table 3-3.
3.1 Mounting and Connections Processor board The following figure depicts the PCB layout for devices from version 7UM61.../CC. B–CPU for The location of the miniature fuse (F1) and of the buffer battery (G1) are shown in the 7UM61.../CC following figure. Figure 3-4 B–CPU processor PCB for devices from version.../CC with jumper settings required for checking configu- ration settings...
3 Mounting and Commissioning Table 3-4 Jumper setting for nominal voltage of the integrated power supply on the B– CPU processor PCB for 7UM61.../CC Jumper Rated voltage 60/110/125 VDC 220/250 VDC 24/48 VDC 115/230 VAC 1–2 2–3 1–2 1–2 and 3–4 2–3 none 1–2...
3.1 Mounting and Connections C–I/O–1 Input / The layout of the input/output board C-I/O-1 is shown in the following Figure. Output Board Figure 3-5 Input/output board C-I/O-1 with representation of the jumper settings required for the board configuration In the version 7UM612 , for the Input/Output module C–I/O–1, binary output BO 4 can be configured as normally open or normally closed (see also overview diagrams in Ap- pendix A.2).
3 Mounting and Commissioning Table 3-8 Jumper setting of control voltages of binary inputs BI1 to BI8 on Input/Output module module C– I/O–1 in the 7UM612 Binary Inputs Jumper 19 V Threshold 88 V Threshold 176 V Threshold X21/X22 X23/X24 BI10 X25/X26 BI11...
3.1 Mounting and Connections C-I/O-2 Input / PCB layout for the C-I/O-2 board is shown in the following Figure. Output Module Figure 3-6 Input/output board C–I/O-2 with representation of jumper settings required for checking configuration settings The relay contact for binary output BO17 can be configured as normally open or nor- mally closed (see overview diagrams in Appendix A.2): Table 3-10 Jumper Setting for Relay Contact for Binary Output BO17...
3 Mounting and Commissioning The set rated current settings of the input current transformers are checked on the In- put/Output C-I/O-2 board. All jumpers must be in the same position for a rated current, i.e. there must be one jumper each (X61 through X64) for each of the input transform- ers, and also the common jumper X60.
3.1 Mounting and Connections 184.108.40.206 Interface Modules Replacing Inter- The interface modules are located on the B–CPU processor board ((1) in Figure 3-1 face Modules and 3-2). The following figure shows the PCB with location of the modules. Figure 3-7 Processor board CPU with interface modules Please note the following: •...
3 Mounting and Commissioning Table 3-12 Replacement modules for interfaces Interface Mounting Location / Port Replacement module RS232 RS 485 FO 820 nm Profibus DP RS485 System interface Profibus DP double ring Modbus RS 485 Modbus 820 nm DNP3.0, RS 485 DNP 3.0 820 nm RS232 Service interface...
3.1 Mounting and Connections Figure 3-9 Position of the plug-in jumpers for configuration of terminating resistors of the Profibus interface The terminating resistors can also be connected externally (e.g. to the connection module). In this case the terminating resistors provided on the RS485/Profibus inter- face module or directly on the B–CPU processor PCB must be switched out.
3 Mounting and Commissioning 3.1.3 Mounting 220.127.116.11 Panel Flush Mounting Depending on the version, the housing size can be • Remove the 4 covers on the corners of the front plate. This gives access to the 4 or 6 slots in the mounting flange. •...
3.1 Mounting and Connections 18.104.22.168 Rack Mounting and Cubicle Mounting For housing size 4 covering caps and 4 securing holes are provided. To install the device in a frame or cubicle, two mounting brackets are required. Order numbers are given in the Appendix under A.1. •...
3 Mounting and Commissioning Figure 3-12 Installing a 7UM612 in a rack or cubicle (housing size 1/2) 22.214.171.124 Panel Surface Mounting For installation proceed as follows: • Secure the device to the panel with four screws. For dimensions see for the Tech- nical Data in Section 4.26.
3.2 Checking Connections Checking Connections 3.2.1 Checking Data Connections of Serial Interfaces Pin assignments The following tables illustrate the pin assignment of the various serial device interfaces and of the time synchronization interface. The position of the connections can be seen in the following figure.
3 Mounting and Commissioning Table 3-14 DSUB socket connections for the various interfaces Pin No. Operation inter- RS232 RS 485 Profibus DP Slave, DNP3.0 Modbus, face RS 485 RS485 Shield (with shield ends electrically connected) – – – A/A' (RxD/TxD–N) B/B' (RxD/TxD–P) –...
3.2 Checking Connections Optical Fibers WARNING! Warning of Laser rays! Non-observance of the following measures can result in death, personal injury or sub- stantial property damage. Do not look directly into the fiber-optic elements! Signals transmitted via optical fibers are unaffected by interference. The fibers guar- antee electrical isolation between the connections.
3 Mounting and Commissioning A plausibility check of the analog-digital converter with the operational measured values is sufficient since the subsequent processing of the measured values is numer- ical and thus internal failures of protection functions can be ruled out. For any secondary checks to be carried out, where possible three-phase test equip- ment with currents and voltages is recommended (e.g.
3.2 Checking Connections Test Switch Check the functions of all test switches that are installed for the purposes of secondary testing and isolation of the device. Of particular importance are “test switches ” in current transformer circuits. Be sure these switches short-circuit the current transform- ers when they are in the test mode.
3 Mounting and Commissioning Caution! Be careful when operating the device connected to a battery charger without a battery Non-observance of the following measure can lead to unusually high voltages and thus the destruction of the device. Do not operate the device on a battery charger without a connected battery. (For limit values see also Technical Data Section 4.1).
3.2 Checking Connections • Check control circuits from the output relays via control lines to the circuit breakers and isolators etc. • Check binary input signals via signal lines up to the protection device by activating the external contacts. Protective Switch- Since it is very important for the undervoltage protection, impedance protection and es for the Voltage voltage-dependent definite time and inverse time overcurrent protection that these...
3 Mounting and Commissioning Commissioning WARNING! Warning of dangerous voltages when operating an electrical device Non-observance of the following measures can result in death, personal injury or sub- stantial property damage. Only qualified people shall work on and around this device. They must be thoroughly familiar with all warnings and safety notices in this instruction manual as well as with the applicable safety steps, safety regulations, and precautionary measures.
3.3 Commissioning WARNING! Warning of dangers evolving from improper primary tests Non-observance of the following measures can result in death, personal injury or sub- stantial property damage. Primary test may only be carried out by qualified personnel, who are familiar with the commissioning of protection systems, the operation of the plant and the safety rules and regulations (switching, earthing, etc.).
3 Mounting and Commissioning Note After termination of this test, the device will reboot. All annunciation buffers are erased. If required, these buffers should be extracted with DIGSI prior to the test. ® The interface test is carried out Online using DIGSI •...
3.3 Commissioning Test in Message Di- For all information that is transmitted to the central station test in Status Scheduled rection the desired options in the list which appears: • Make sure that each checking process is carried out carefully without causing any danger (see above and refer to DANGER!) •...
3 Mounting and Commissioning Structure of the The dialog box is divided into three groups: BI for binary inputs, REL for output relays, Test Dialogue Box and LED for light-emitting diodes. On the left of each group is an accordingly labelled button.
3.3 Commissioning Proceed as follows in order to check the output relay : • Ensure that the switching of the output relay can be executed without danger (see above under DANGER!). • Each output relay must be tested via the corresponding Scheduled-cell in the dialog box.
3 Mounting and Commissioning 3.3.4 Testing Circuit Breaker Failure Protection General If the device is equipped with the breaker failure protection and this function is used, its interaction with the breakers of the power plant must be tested in practice. Especially important for checking the system is the correct distribution of the trip com- mands to the adjacent circuit breakers in the event of breaker failure.
3.3 Commissioning Control from a If the device is connected to a remote substation via a system interface, the corre- Remote Control sponding switching tests may also be checked from the substation. Please also take Centre into consideration that the switching authority is set in correspondence with the source of commands used.
3 Mounting and Commissioning In addition the following must be observed: • Before making any connections, the device must be earthed at the protection earth terminal. • Hazardous voltages can exist in all switchgear components connected to the power supply and to measurement and test circuits. •...
3.3 Commissioning The effective switching of a protection function configured as Enabled can occur in two ways. The setting addresses for this are specified in the corresponding sections. • Protection function Block. Relay : The protection function is operative and outputs indications (also tripping indications) and measured values.
3 Mounting and Commissioning 3.3.8 Checking the Current Circuits General The checks of the current circuits are performed with the generator to ensure correct CT circuit connections with regard to cabling, polarity, phase sequence, CT ratio etc., not in order to verify individual protection functions in the device. Switch unbalanced load protection (address 1701) and overload protection (address Preparation 1601) to Block.
3.3 Commissioning Switch impedance protection (address 3301) to IMPEDANCE PROT. = Block Calibrate the Im- relay. pedance Protection With the primary system voltage-free and earthed, install a three-pole short-circuit bridge which is capable of carrying rated current (e.g. earthing isolator) to the primary side of the unit transformer.
3 Mounting and Commissioning In secondary values: with - Current transformer ratio - Voltage transf. transform. ratio If substantial deviations or wrong the sign occur, then the voltage transformer connec- tions are incorrect. After shutdown and de-excitation of the generator, and removal of the short-circuit bridge, the short-circuit tests are completed.
3.3 Commissioning Amplitudes Read out voltages in all three phases in the operational measured values and compare with the actual voltages. The voltage of the positive sequence system U must be approximately the same as the indicated phase voltages. If there are signifi- cant deviations, the voltage transformer connections are incorrect.
3 Mounting and Commissioning 3.3.10 Checking the Stator Earth Fault Protection General The procedure for checking the stator earth fault protection depends mainly on whether the generator is connected to the network in unit connection or in busbar con- nection. In both cases correct functioning and protected zone must be checked. In order to check interference suppression of the loading resistor, and in order to verify the protected zone of the earth fault protection, it is appropriate to test once with an earth fault at the machine terminals (e.g.
3.3 Commissioning Calculation of Pro- Coupling capacitance C and loading resistor R represent a voltage divider, whereby tected Zone is the resistance R referred to the machine terminal circuit. Figure 3-17 Equivalent Diagram and Vector Diagram Equivalent circuit and vector diagram Since the reactance of the coupling capacitance ≈...
3 Mounting and Commissioning Together with the voltage divider R 500 V/100 V this corresponds to a displacement voltage at the input of the device of: The pickup value U0> for the neutral displacement voltage should amount to at least twice the value of this interference voltage.
3.3 Commissioning Switch stator earth fault protection S/E/F PROT. (address 5001) to Block relay. Checking for Gen- erator Earth Fault If the sensitive earth fault detection is used for stator earth fault protection, switch it to Block relay also under address 5101. With the primary equipment disconnected and earthed, insert a single-pole earth fault bridge in the generator terminal circuit.
3 Mounting 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! Energized equipment of the power system ! Capacitive coupled voltages at discon- nected equipment of the power system ! Non-observance of the following measure will result in death, severe personal injury or substantial property damage.
3.3 Commissioning DANGER! Warning of hazardous voltages on equipment components, e.g. due to capacitative coupling with other components! Nonobservance of the following measure will result in fatality, severe personal injury or substantial material damage. Primary steps may be undertaken only on machine standstill. Before carrying out primary steps on components they must be earthed.
3 Mounting and Commissioning For protection zone Z the following applies: Example: Machine voltage at pickup 0.1 x U Measured value = 10 V Setting value U0> = 10 V Protected zone = 90 % With Directional De- The earth fault directional determination requires a check of the current and voltage termination connections for correctness and correct polarity.
3.3 Commissioning the relay to pickup, then its effect can be increased by looping the conductor several times through the toroidal transformer. For Z either a resistor (30 to 500 Ω) or a capacitor (10 to 100 µF) in series with an inrush-current-limiting resistor (approximately 50 to 100 Ω) is used.
3 Mounting and Commissioning Figure 3-21 Directional Check with Holmgreen Connection If in an isolated network the voltage connections for the reactive current measurement should be kept for testing, then it should be noted that for a power flow with inductive component in forwards direction a backwards direction results (contrary to an earth fault in this direction).
3.3 Commissioning 3.3.11 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 5101 under address O/C PROT. Iee> Block relay. Caution! A rotor circuit not isolated from earth can result in a double fault in conjunction with an earth resistor inserted for checking purposes!
3 Mounting and Commissioning If the power continues being incorrect, there must be an error in the transformer wiring (e.g. cyclical phase swap): • Remedy faults of the transformer lines (current and/or voltage transformers); ob- serving for this the safety rules, •...
3.3 Commissioning • Reduce excitation slowly to approximately 30% rated apparent power of generator (underexcited). – Read out the motoring power P with polarity (negative) in the operational mea- sured values and note it (see table below). – Read out reactive power Q with polarity (negative) in the operational measured values and note it (see table below).
3 Mounting and Commissioning From the operational measured value for the active power, the motoring power mea- sured with the device can be derived. 50% of that value should be taken as the setting for the reverse power protection. Increase driving power. On a further test check the stop valve criterion.
3.3 Commissioning Note If operation with capacitive load is not possible, then load points in the underexcited range can be achieved by changing the polarity of the current transformer connections (address 210). Thereby the characteristics of the underexcitation protection are mir- rored around the zero point.
3 Mounting and Commissioning ® Start Waveform Re- To trigger test measurement recording with DIGSI , click on Test in the left part of the cording window. Double click the entry Test Wave Form in the list of the window. Figure 3-23 Triggering oscillographic recording with DIGSI®...
3.4 Final Preparation of the Device Final Preparation of the Device Firmly tighten all screws. Tighten all terminal screws, including those that are not used. Caution! Inadmissable tightening torques Non–observance of the following measure can result in minor personal injury or prop- erty damage.
3 Mounting and Commissioning 7UM61 Manual C53000-G1176-C127-3...
Technical Data ® This chapter presents the technical data of SIPROTEC 7UM61 device and its individ- ual functions, including the limit values that under no circumstances may be exceed- ed. The electrical and functional data for the maximum functional extent are followed by the mechanical specifications with dimension diagrams.
4 Technical Data 4.25 Operating Ranges of the Protection Functions 4.26 Dimensions 7UM61 Manual C53000-G1176-C127-3...
4.1 General General 4.1.1 Analog Inputs/Outputs Current Inputs Rated system frequency 50 Hz or 60 Hz (adjustable) Rated current 1 A or 5 A ≤ linear range 1.6 A Earth Current, Sensitive Burden per Phase and Earth Path - at I = 1 A Approx.
4 Technical Data 7UM611 energized approx. 9.5 W 7UM612 approx. 12.5 W ≥ 50 ms at V ≥ 110 V DC Bridging time on failure or short circuit ≥ 20 ms at V ≥ 24 V DC AC Voltage Voltage supply using integrated converter Nominal Auxiliary AC Voltage U 115 VAC (50/60 Hz) 230 V AC (50/60 Hz)
4.1 General Output Relays Indication/command relay Number: 7UM611*– 11 (each with 1 NO contact) 7UM612*– 19 (each with 1 NO contact) Make/break capacity MAKE 1000 W/VA BREAK 30 VA 40 W resistive 25 W at L/R ≤ 50 ms Switching Voltage 250 V admissible current per contact 5 A continuous 30 A for 0.5 s...
4 Technical Data Service / Modem Interface Connection isolated interface for data transfer ® Operation with DIGSI Transmission Speed min. 4 800 Baud; max. 115 200 Baud Factory Setting: 38,400 Baud Parity: 8E1 RS232/RS485 RS232/RS485 according to the order- ing variant Connection for flush- rear panel, slot "C", 9-pin DSUB mounted case...
4.1 General Fibre optic cable (FO) Fibre optic connector type ST connector Connection for flush- rear panel, mounting location "B" mounted case for surface-mounted case in console housing at case bottom λ = 820 nm optical wavelength Using glass fibre 50/125 µm or using Laser Class 1 according to glass fibre 62.5/125 µm EN 60825–1/–2...
4 Technical Data Profibus FO (FMS and DP) Fibre optic connector type ST-connector single ring / double ring according to the order for FMS; for DP only double ring available Connection for flush- rear panel, mounting location "B" mounted case for surface-mounted case in console housing at case bottom Transmission Speed up to 1.5 MBd...
4.1 General Time Synchronization Interface Time synchronization DCF 77 IRIG B Signal (telegram format IRIG-B000) Connection for flush-mounted case rear panel, mounting location "A"; 9-pin D-SUB socket for surface-mounted case at two-tier terminals on case bottom Signal Nominal Voltages selectable 5 V, 12 V or 24 V Signal levels and burdens: Nominal Signal Voltage 12 V...
4 Technical Data EMC Tests for Interference Immunity (type tests) Standards: IEC 60,255-6 and -22 (product standards) EN 50,082-2 (Generic standard) DIN VDE 0435-110 2.5 kV (Peak); 1 MHz; τ = 15 µs; 400 surges per High Frequency Test = 200 Ω IEC 60,255-22-1, Class III s;...
56 days of the year up to 93% relative humid- ity. CONDENSATION MUST BE AVOIDED IN OPERATION Siemens recommends that all devices be installed so that they are not exposed to direct sun- light nor subject to large fluctuations in temperature that may cause condensation to occur. 4.1.8...
4.1 General 4.1.9 Certifications UL Listing UL recognition 7UM61**–*B***–**** 7UM61**–*B***–**** Models with screw ter- Models with plug–in minals terminals 7UM61**–*B***–**** 4.1.10 Construction Case 7XP20 Dimensions See dimensional drawings, Section 4.26 Weight approx. in flush mounting, housing size 1/3 about 12 pounds (5.5 kg) in flush mounting, housing size 1/2 about 12 pounds (7 kg) in surface mounting, housing size 1/3...
4 Technical Data Definite-Time Overcurrent Protection (I>, ANSI 50/51; I>>, ANSI 50/51/67) Setting Ranges / Increments Pickup Current I> for I = 1 A 0.05 A to 20.00 A Increments 0.01 A for I = 5 A 0.25 A to 100.00 A Increments 0.05 A Pickup Current I>>...
4.2 Definite-Time Overcurrent Protection (I>, ANSI 50/51; I>>, ANSI 50/51/67) Influencing Variables for Pickup Values Auxiliary direct voltage in range 0.8 ≤ ≤ 1 % ≤ 1.15 ≤ 0.5 % / 10 K Temperature in Range 23°F or –5 °C ≤ Θ ≤...
4 Technical Data Inverse-Time Overcurrent Protection (ANSI 51V) Setting Ranges / Increments Pickup current I for I = 1 A 0.10 A to 4.00 A Increments 0.01 A (Phase) for I = 5A 0.50 A to 20.00 A Increments 0.05 A Time Multipliers T for 0.05 s to 3.20 s Increments 0.01 s...
4.3 Inverse-Time Overcurrent Protection (ANSI 51V) Influencing Variables for Pickup Values ≤ 1 % Auxiliary DC voltage in range 0.8 ≤ U ≤ 1.15 AuxN ≤ 0.5 % / 10 K Temperature in Range 23°F or –5 °C ≤ Θ ≤...
4 Technical Data Figure 4-1 Trip Characteristics of the Inverse-time Overcurrent Protection, as per IEC 7UM61 Manual C53000-G1176-C127-3...
4.3 Inverse-Time Overcurrent Protection (ANSI 51V) Trip Time Curves acc. to ANSI As per ANSI/IEEE (see also Figures 4-2 and 4-3) ≥ 20 are identical to those for I/I The trip times for I/I = 20. Pickup Threshold approx. 1.10 · I ≥...
4 Technical Data ≤ 0.5 % / 10 K Temperature in Range 23°F or –5 °C ≤ Θ ≤ 131°F or 55 °C Frequency in range 0.95 ≤ f/f ≤ 1.05 7UM61 Manual C53000-G1176-C127-3...
4.3 Inverse-Time Overcurrent Protection (ANSI 51V) Figure 4-2 Trip Time Characteristics of the Inverse-time Overcurrent Protection, acc. to ANSI/IEEE 7UM61 Manual C53000-G1176-C127-3...
4 Technical Data Figure 4-3 Trip Time Characteristics of the Inverse-time Overcurrent Protection, acc. to ANSI/IEEE 7UM61 Manual C53000-G1176-C127-3...
4.4 Thermal Overload Protection (ANSI 49) Thermal Overload Protection (ANSI 49) Setting Ranges / Increments K-Factor per IEC 60,255-8 0.10 to 4.00 Increments 0.01 Time Constant τ 30 s to 32000 s Increments 1 s Extension of Time Constant at 1.0 to 10.0 Increments 0.1 Standstill...
4 Technical Data Influencing Variables Referred to k · I ≤ 1 % Auxiliary DC voltage in range 0.8 ≤ U ≤ 1.15 AuxN ≤ 0.5 % / 10 K Temperature in Range 23°F or –5 °C ≤ Θ ≤ 131°F or 55 °C Frequency in Range 0.95 ≤...
4 Technical Data Influencing Variables for Pickup Values ≤ 1 % Auxiliary DC voltage in range 0.8 ≤ U ≤ 1.15 AuxN ≤ 0.5 % / 10 K Temperature in Range 23°F or –5 °C ≤ Θ ≤ 131°F or 55 °C Frequency in Range 0.95 ≤...
4 Technical Data Reverse Power Protection (ANSI 32R) Setting Ranges / Increments Reverse power P >/S -0.50 % to -30.00 % Increments 0.01 reverse Delay times T 0.00 to 60.00 s Increments 0.01 or ∞ (ineffective) Times Pickup Times – Reverse power P >...
4.8 Forward Active Power Supervision (ANSI 32F) Forward Active Power Supervision (ANSI 32F) Setting Ranges / Increments Reverse power P >/S 0.5 % to 120.0 % Increments 0.1 % reverse Reverse power P >/S 1.0 % to 120.0 % Increments 0.1 % reverse Delay times T 0.00 to 60.00 s...
4 Technical Data 4.11 Overvoltage Protection (ANSI 59) Setting Ranges / Increments Measured Quantity Maximum of the phase-to-phase voltages, calcu- lated from the phase-to-earth voltages Pickup thresholds U<, U<<, Up< 30.0 V to 170.0 V Increments 0.1V Dropout ratio RV U< 0.90 to 0.99 Increments 0.01 (Stages U>, U>>)
4.12 Frequency Protection (ANSI 81) 4.12 Frequency Protection (ANSI 81) Setting Ranges / Increments Number of Frequency Elements 4; can be set to f> or f< Pickup Frequency f> or f< 40 Hz to 65.00 Hz Increments 0.01 Hz Delay Times T f1 0.00 s to 600.00 s Increments 0.01 s...
4 Technical Data 4.13 Overexcitation (Volt/Hertz) Protection (ANSI 24) Setting Ranges / Increments Pickup threshold (Alarm Stage) 1.00 to 1.20 Increments 0.01 Pickup threshold of stage characteristic 1.00 to 1.40 Increments 0.01 Time Delays T U/f>, T U/f>>Warning Stage 0.00 s to 60.00 s Increments 0.01 s or ∞...
4.13 Overexcitation (Volt/Hertz) Protection (ANSI 24) Influencing Variables ≤ 1 % Auxiliary DC voltage in range 0.8 ≤ U ≤ 1.15 AuxN ≤ 0.5 % / 10 K Temperature in Range 23°F or –5 °C ≤ Θ ≤ 131°F or 55 °C Harmonics ≤...
4 Technical Data 4.14 Rate-of-Frequency-Change Protection df/dt (ANSI 81R) Setting Ranges / Increments Stages, can be +df/dt> or –df/dt Pickup values df/dt 0.1 to 10 Hz/s Increments 0.1 Hz/s Delay times T 0.00 to 60.00 s Increments 0.01 s or ineffective Undervoltage Blocking U1>...
4.15 Jump of Voltage Vector 4.15 Jump of Voltage Vector Setting Ranges / Increments Stage ∆ 2° to 30° Increments 1° ϕ Delay Time T 0.00 to 60.00 s Increments 0.01 s or ineffective Reset Time T 0.00 to 60.00 s Increments 0.01 s Reset or ineffective...
4 Technical Data 4.16 90-%-Stator Earth Fault Protection (ANSI 59N, 64G, 67G) Setting Ranges / Increments Displacement Voltage U 2.0 V to 125.0 V Increments 0.1V Earth Earth current I 2 mA to 1000 mA Increments 1 mA Earth Earth current angle criterion 0°...
4.17 Sensitive Earth Fault Protection (ANSI 51GN, 64R) 4.17 Sensitive Earth Fault Protection (ANSI 51GN, 64R) Setting Ranges / Increments Pickup Current I > 2 mA to 1000 mA Increments 1 mA Delay time T > 0.00 s to 60.00 s Increments 0.01 s or ∞...
4 Technical Data 4.18 100-%-Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN 3rd Harm.) Setting Ranges / Increments Pickup Value for 3rd Harmonic in Undervolt- 0.2 V to 40.0 V Increments 0.1V age Stage U < 0 (3. Harmon.) Pickup Value for 3rd Harmonic in Undervolt- 0.2 V to 40.0 V Increments 0.1V...
4.19 Motor Starting Time Supervision (ANSI 48) 4.19 Motor Starting Time Supervision (ANSI 48) Setting Ranges / Increments Motor Startup Current for I = 1 A 0.10 A to 16.00 A Increments 0.01 A for I = 5 A 0.50 A to 80.00 A Increments 0.05 A STARTUP Pickup Threshold for Startup...
4 Technical Data 4.20 Restart Inhibit for Motors (ANSI 66, 49Rotor) Setting Ranges / Increments Motor starting current relative to Nominal 1.5 to 10.0 Increments 0.1 Motor Current Start Motor Nom Max. admissible Startup Time 3.0 s to 120.0 s Increments 1 s Start Max Leveling Time...
4.21 Breaker Failure Protection (ANSI 50BF) 4.21 Breaker Failure Protection (ANSI 50BF) Setting Ranges / Increments Pickup thresholds BF I> for I = 1 A 0.04 A to 2.00 A Increments 0.01 A for I = 5 A 0.20 A to 10.00 A Increments 0.05 A Delay Time BF-T...
4 Technical Data 4.22 Inadvertent Energization (ANSI 50, 27) Setting Ranges / Increments Pickup Current I>>> for I = 1 A 0.1 A to 20.0 A Increments 0.1 A for I = 5 A 0.5 A to 20.0 A Increments 0.5 A or ∞...
4.23 RTD-Box 4.23 RTD-Box Temperature Detectors connectable thermoboxes 1 or 2 Number of temperature detectors per ther- Max. 6 mobox Pt 100 Ω or Ni 100 Ω or Ni 120 Ω Measuring Method Mounting Identification “Oil” or “Ambient” or “Winding” or “Bearing” or “Other”...
4 Technical Data 4.24 Auxiliary Functions Operational Measured Values Operational Measured Values for Currents I in A (kA) primary and in A secondary or in % of I in A (kA) primary and in A secondary Range 10 % to 200 % I 0.2 % of measured value, or ±10 mA ±1 digit Tolerance Operational Measured Values for Currents I...
4.24 Auxiliary Functions Meter Values for Energy Wp, Wq (real and reactive energy) in kWh (MWh or GWh) and in kVARh (MVARh or GVARh) Range 8 1/2 digits (28 bit) for VDEW protocol 9 1/2 digits (31 bit) in the device 1 % ±...
4 Technical Data Voltage Phase Sequence Clockwise/ counter-clockwise phase sequence < limit value I < configurable using CFC Fault Logging Indications memory for the last 8 fault cases (max. 600 indications) Time Allocation Resolution for Event Log (Operational Indi- 1 ms cations) Resolution for Fault Log (Fault Indications) 1 ms Maximum Time Deviation (Internal Clock)
4.24 Auxiliary Functions Trip Circuit Monitoring Number of monitorable circuits with one or two binary inputs Commissioning Aids Phase Rotation Field Check Operational measured values Switching device test Creation of a Test Measurement Report Clock Time synchronization DCF 77 IRIG B-Signal (telegram format IRIG-B000) Binary Input Communication User Defined Functions (CFC)
4 Technical Data Function Modules and Possible Allocation to Task Levels Function Module Explanation Sequence Level PLC1_ PLC1_ SFS_ BEARB BEARB BEARB BEARB LOOP Signal Feedback — — — LOWER_SETPOINT Limit value undershoot — — — Multiplication — — — NAND NAND Gate —...
4.25 Operating Ranges of the Protection Functions 4.25 Operating Ranges of the Protection Functions Operational condi- Operational condition 1 Operational condi- tion 0 tion 0 f ≤ 0 Hz 11 Hz < f/Hz ≤ 40 40 Hz ≤ f/Hz ≤ 69 f ≥...
4 Technical Data the thermal replica registers cooling-down a pickup – if already present – is maintained a pick -up – if already present – is maintained, if the measured voltage is not too small 25 Hz < f/Hz ≤ 40 Hz The function is only active at rated frequency ±...
4 Technical Data 4.26.2 Panel Flush and Cubicle Mounting – 7UM612 Figure 4-8 Dimensions of a 7UM612 for panel flush mounting or cubicle installation (housing size 1/2) 7UM61 Manual C53000-G1176-C127-3...
4 Technical Data 4.26.5 Dimensions of Coupling Unit 7XR6100-0CA0 for Panel Flush Mounting Figure 4-11 Dimensions of Coupling Unit 7XR6100-0CA0 for Panel Flush Mounting 7UM61 Manual C53000-G1176-C127-3...
4.26 Dimensions 4.26.6 Dimensions of Coupling Unit 7XR6100-0BA0 for Panel Flush Mounting Figure 4-12 Dimensions of Coupling Unit 7XR6100-0BA0 for Panel Surface Mounting 7UM61 Manual C53000-G1176-C127-3...
Appendix This appendix is primarily a reference for the experienced user. This section provides ordering information for the models of this device. Connection diagrams for indicating the terminal connections of the models of this device are included. Following the general diagrams are diagrams that show the proper connections of the devices to primary equipment in many typical power system configurations.
A Appendix Ordering Information and Accessories A.1.1 Ordering Information A.1.1.1 7UM61 10 11 12 13 14 17 18 19 Machine Protection — — Number of Binary Inputs and Outputs Pos. 6 Housing 1/3 19'', 7 BI, 11 BO, 1 Live Status Contact Housing 1/2 19'', 15 BI, 19 BO, 1 Live Status Contact Nominal current Pos.
A.1 Ordering Information and Accessories Additional Information L Pos. 17 Pos. 18 Pos. 19 (Port B) Profibus DP Slave, RS485 Profibus DP Slave, optical 820 nm, Double ring, ST Connector Modbus electrical RS485 Modbus, 820 nm, optical, ST Connector DNP3.0, RS485 DNP3.0, 820 nm, optical, ST connector not for “B”...
A Appendix Functionality Pos. 14 Unbalanced load protection >, t=f(I Breaker Failure Protection > 50BF Generator Full, comprising: ANSI No. Generator Standard and in addition: Inadvertent Energizing Protection I>, U< 50/27 100% Stator Earth Fault Protection with 3rd Harmonic 59TN 27TN(3.H) 0 (3rd Harm.) Impedance Protection with (I>+U<) Excitation Z<...
A.1 Ordering Information and Accessories Short-circuit links Short circuit jumpers for terminal type Order No. Voltage terminal, 18-pole terminal, or 12-pole terminal C73334-A1-C34-1 Current terminal,12-pole terminal, or 8-pole terminal C73334-A1-C33-1 Socket housing Socket housing Order No. 2-pole C73334-A1-C35-1 3-pole C73334-A1-C36-1 Angle brackets for Name Order No.
A Appendix Graphic Tools Graphic Tools 4 Order No. Full version with license for 10 computers 7XS5430-0AA0 DIGSI REMOTE 4 Software for remotely operating protective devices via a modem (and possibly a star connector) using DIGSI® 4 (option package of the complete version of DIGSI® 4) Order No.
A.3 Connection Examples Connection Examples A.3.1 Connection Examples Figure A-5 Busbar connection: Current and voltage connections to three transformers (phase-earth-voltages) and in each case three current transformers, – earth current from additional summation current transformer for sensitive earth fault detection; Displacement voltage detection at broken delta winding (e–n). 7UM61 Manual C53000-G1176-C127-3...
A Appendix Figure A-6 Busbar System with Low-Ohmic Earthing: CT connections to three voltage transformers (phase-to- ground voltages) and in each case three current transformers – earth fault detection as differential current measuring of two CT sets; detection of displacement voltage at broken delta winding (e–n) as an additional criterion.
A.3 Connection Examples Figure A-7 Busbar system with high-ohmic, switchable starpoint resistors ,CT connection to three current transformers and three voltage transformers (phase-to-ground voltages) –earth fault detection as differential current measuring between star- point current and summation current measured via toroidal CTs; detection of displacement voltage at open delta winding (e–n).
A Appendix Figure A-8 Unit Connection with Isolated Starpoint: Connection to three current transformers and three voltage transformers (phase-to-earth voltages) –with series device 7XR61 for rotor circuit injection and with super- vision of the rotor ground insulation by sensitive earth fault detection; detection of displacement voltage at open delta winding (e–n).
A.3 Connection Examples Figure A-9 Unit Connection with Isolated Starpoint:CT connections to three voltage transformers (phase-to-earth voltages) and three voltage transformers each; Loading resistor connected either directly to starpoint circuit or via intermediate transformer. 7UM61 Manual C53000-G1176-C127-3...
A Appendix Figure A-10 Rotor earth fault protection – with series device 7XR61 for injection of a rated-frequency voltage into the rotor circuit if the sensitive earth current input is used. 7UM61 Manual C53000-G1176-C127-3...
A Appendix Figure A-12 Asynchronous motor:Connection to three voltage transformers (phase-to-earth voltages, usually from the busbar); Displacement voltage detection at broken delta winding, three current transformers; Earth fault di- rection detection by toroidal CTs 7UM61 Manual C53000-G1176-C127-3...
A.3 Connection Examples Figure A-13 Voltage Transformer Connections for Two Voltage Transformers in Open Delta Connection (V Connection) Figure A-14 Current Transformer Connections with only Two System-Side Current Transformers Figure A-15 Voltage Transformer Connection with L2 Earthed on the Secondary Side 7UM61 Manual C53000-G1176-C127-3...
A Appendix A.3.2 Connection Examples for Thermobox Figure A-16 Simplex operation with one Thermobox Figure A-17 Semiduplex operation with one thermobox Figure A-18 Semiduplex operation with two thermoboxes 7UM61 Manual C53000-G1176-C127-3...
A Appendix A.4.3 Binary Output Table A-3 Output relay presettings for all devices and ordering variants Binary Output Short Text Function No. Description Error PwrSupply Error Power Supply Fail Battery Failure: Battery empty Relay TRIP Relay GENERAL TRIP command List Empty BO4 ...
A.4 Default Settings A.4.4 Function Keys Table A-4 Applies to all devices and ordered variants Function Keys Presetting Display of Operational Annunciations Display of Primary Operational Values Jumping to heading for last eight fault annunciations Jumping to the reset menu of the min/max values A.4.5 Default Display Figure A-23...
A Appendix A.4.6 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 converted Logic by means of a NEGATOR block into an indication UnlockDT that can be processed internally (internal single point indication, IntSP), and assigned to an output.
A Appendix Settings Addresses which have an appended "A" can only be changed with DIGSI, under Ad- ditional Settings. The table indicates region-specific presettings. Column C (configuration) indicates the corresponding secondary nominal current of the current transformer. Addr. Parameter Function Setting Options Default Setting Comments...
A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 1202 I> O/C Prot. I> 0.05 .. 20.00 A 1.35 A I> Pickup 0.25 .. 100.00 A 6.75 A 0.00 .. 60.00 sec; ∞ 1203 T I> O/C Prot. I> 3.00 sec T I>...
A Appendix Addr. Parameter Function Setting Options Default Setting Comments 1702 I2> Unbalance Load 3.0 .. 30.0 % 10.6 % Continously Permissible Current 0.00 .. 60.00 sec; ∞ 1703 T WARN Unbalance Load 20.00 sec Warning Stage Time Delay 2.0 .. 100.0 sec; ∞ 1704 FACTOR K Unbalance Load...
A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 0.00 .. 60.00 sec; ∞ 3309 T-Z1B Impedance 0.10 sec Impedance Zone Z1B Time Delay 0.05 .. 65.00 Ω 4.15 Ω 3310 ZONE Z2 Impedance Impedanz Zone Z2 0.01 .. 13.00 Ω 0.83 Ω...
A Appendix Addr. Parameter Function Setting Options Default Setting Comments 4314 T COOL DOWN Overexcitation 0 .. 20000 sec 3600 sec Time for Cooling Down 4501 df/dt Protect. df/dt Protect. Rate-of-frequency-change pro- tection Block relay 4502 df1/dt >/< df/dt Protect. -df/dt<...
A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 5106 IEE< Sens. E Fault 1.5 .. 50.0 mA; 0 0.0 mA Iee< Pickup (Interrupted Circuit) 5201 SEF 3rd HARM. SEF 3.Harm. Stator Earth Fault Protection 3rdHarm. Block relay 5202 U0 3.HARM<...
A Appendix Addr. Parameter Function Setting Options Default Setting Comments 8104 BALANCE I LIMIT Measurem.Superv 0.10 .. 1.00 A 0.50 A Current Balance Monitor 0.50 .. 5.00 A 2.50 A 8105 BAL. FACTOR I Measurem.Superv 0.10 .. 0.90 0.50 Balance Factor for Current Monitor ΣI THRESHOLD 8106...
A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 8510 THRESHOLD MV5> Threshold -200 .. 200 % 100 % Pickup Value of Measured Value MV5> 8511 MEAS. VALUE 6< Threshold Disabled Disabled Measured Value for Threshold MV6< Delta P 8512 THRESHOLD MV6<...
A Appendix Addr. Parameter Function Setting Options Default Setting Comments 9032A RTD 3 LOCATION RTD-Box Other RTD 3: Location Ambient Winding Bearing Other -50 .. 250 °C; ∞ 100 °C 9033 RTD 3 STAGE 1 RTD-Box RTD 3: Temperature Stage 1 Pickup -58 ..
A.7 Settings Addr. Parameter Function Setting Options Default Setting Comments 9072A RTD 7 LOCATION RTD-Box Other RTD 7: Location Ambient Winding Bearing Other -50 .. 250 °C; ∞ 100 °C 9073 RTD 7 STAGE 1 RTD-Box RTD 7: Temperature Stage 1 Pickup -58 ..
A Appendix Addr. Parameter Function Setting Options Default Setting Comments 9112A RTD11 LOCATION RTD-Box Other RTD11: Location Ambient Winding Bearing Other -50 .. 250 °C; ∞ 100 °C 9113 RTD11 STAGE 1 RTD-Box RTD11: Temperature Stage 1 Pickup -58 .. 482 °F; ∞ 212 °F 9114 RTD11 STAGE 1...
A.8 Information List Information List Indications for IEC 60 870-5-103 are always reported ON / OFF if they are subject to general interrogation for IEC 60 870-5-103. If not, they are reported only as ON.. New user-defined indications or such newly allocated to IEC 60 870-5-103 are set to ON / OFF and subjected to general interrogation if the information type is not a spon- taneous event (“.._Ev”).
A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio Reset Minimum and Maximum Min/Max meter IE_W counter (ResMinMax) Reset meter (Meter res) Energy IE_W Error Systeminterface (SysIn- Protocol tErr.) No Function configured (Not con- Device figured) Function Not Available (Non Exis-...
A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio Failure: Current Summation (Fail- Measurem.Superv ure Σ I) Failure: Current Balance (Fail I Measurem.Superv balance) Failure: General Voltage Supervi- Measurem.Superv sion (Fail U Superv.) Failure: Voltage Summation Measurem.Superv Phase-Earth (Fail Σ...
A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio Power System fault Device (Pow.Sys.Flt.) Fault Event (Fault Event) Device >Failure: Feeder VT (MCB P.System Data 1 LED BI tripped) (>FAIL:Feeder VT) >UE 3rd Harm. MIN/MAX Buffer Min/Max meter Reset (>UE3h MiMa Res.) >I1 MIN/MAX Buffer Reset (>I1...
A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 1231 >BLOCK sensitiv earth current Sens. E Fault LED BI prot. (>BLOCK Sens. E) 1232 Earth current prot. is swiched Sens. E Fault OFF (IEE OFF) 1233 Earth current prot.
A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 1521 Thermal Overload TRIP (ThOver- Therm. Overload load TRIP) 1720 >BLOCK direction I>> stage O/C Prot. I>> LED BI (>BLOCK dir.) 1721 >BLOCK I>> (>BLOCK I>>) O/C Prot.
A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 1967 O/C prot. stage I> is ACTIVE (I> O/C Prot. I> ACTIVE) 1970 O/C prot. undervoltage seal-in O/C Prot. I> (U< seal in) 3953 >BLOCK impedance protection Impedance...
A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 4556 External trip 2: General picked up External Trips (Ext 2 picked up) 4557 External trip 2: General TRIP (Ext External Trips 2 Gen.TRP) 4563 >BLOCK external trip 3 (>BLOCK External Trips...
A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 5012 Voltage UL1E at trip (UL1E:) P.System Data 2 5013 Voltage UL2E at trip (UL2E:) P.System Data 2 5014 Voltage UL3E at trip (UL3E:) P.System Data 2 5015 Active power at trip (P:)
A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 5148 Phase Rotation L1L3L2 (Rotation P.System Data 1 L1L3L2) 5151 I2 switched OFF (I2 OFF) Unbalance Load 5152 I2 is BLOCKED (I2 BLOCKED) Unbalance Load 5153 I2 is ACTIVE (I2 ACTIVE) Unbalance Load...
A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 5211 Frequency protection is OFF Frequency Prot. (Freq. OFF) 5212 Frequency protection is Frequency Prot. BLOCKED (Freq. BLOCKED) 5213 Frequency protection is ACTIVE Frequency Prot.
A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 5361 Overexcitation prot. is swiched Overexcitation OFF (U/f> OFF) 5362 Overexcitation prot. is BLOCKED Overexcitation (U/f> BLOCKED) 5363 Overexcitation prot. is ACTIVE Overexcitation (U/f> ACTIVE) 5367 Overexc.
A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 5542 Inadvert. Energ. prot. is Inadvert. En. BLOCKED (I.En. BLOCKED) 5543 Inadvert. Energ. prot. is ACTIVE Inadvert. En. (I.En. ACTIVE) 5546 Release of the current stage Inadvert.
A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 6537 Undervoltage U<< picked up Undervoltage (U<< picked up) 6539 Undervoltage U< TRIP (U< TRIP) Undervoltage 6540 Undervoltage U<< TRIP (U<< Undervoltage TRIP) 6565 Overvoltage protection switched Overvoltage OFF (Overvolt.
A.8 Information List Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 7961 Measured Value MV2< picked up Threshold (Meas. Value2<) 7962 Measured Value MV3> picked up Threshold (Meas. Value3>) 7963 Measured Value MV4< picked up Threshold (Meas.
A Appendix Description Function Type Log Buffers Configurable in Matrix IEC 60870-5-103 of In- for- matio 14182 RTD 8 Temperature stage 1 RTD-Box picked up (RTD 8 St.1 p.up) 14183 RTD 8 Temperature stage 2 RTD-Box picked up (RTD 8 St.2 p.up) 14191 Fail: RTD 9 (broken wire/shorted) RTD-Box...
A Appendix A.10 Measured Values Description Function IEC 60870-5-103 Configurable in Matrix IL< under current (IL<) Set Points(MV) Number of TRIPs (#of TRIPs=) Statistics Number of TRIPs (#of TRIPs=) Statistics Operating hours greater than (OpHour>) SetPoint(Stat) I L1 (IL1 =) Measurement I L2 (IL2 =) Measurement...
A.10 Measured Values Description Function IEC 60870-5-103 Configurable in Matrix Active Power Minimum (PMin=) Min/Max meter Active Power Maximum (PMax=) Min/Max meter Reactive Power Minimum (QMin=) Min/Max meter Reactive Power Maximum (QMax=) Min/Max meter Frequency Minimum (fMin=) Min/Max meter Frequency Maximum (fMax=) Min/Max meter Pulsed Energy Wp (active) (Wp(puls)) Energy...
A Appendix 7UM61 Manual C53000-G1176-C127-3...
Glossary Battery The buffer battery ensures that specified data areas, flags, timers and counters are re- tained retentively. Bay controllers Bay controllers are devices with control and monitoring functions without protective functions. Bit pattern indica- Bit pattern indication is a processing function by means of which items of digital tion process information applying across several inputs can be detected together in paral- lel and processed further.
Glossary Component view In addition to a topological view, SIMATIC Manager offers you a component view. The component view does not offer any overview of the hierarchy of a project. It does, how- ever, provide an overview of all the SIPROTEC 4 devices within a project. COMTRADE Common Format for Transient Data Exchange, format for fault records.
Glossary This term means that a conductive part is connected via an earthing system to the → Earth (verb) earth. Earthing Earthing is the total of all means and measures used for earthing. Electromagnetic Electromagnetic compatibility (EMC) is the ability of an electrical apparatus to function compatibility fault-free in a specified environment without influencing the environment unduly.
Glossary image. The current process state can also be sampled after a data loss by means of a GI. Global Positioning System. Satellites with atomic clocks on board orbit the earth twice a day in different parts in approx. 20,000 km. They transmit signals which also contain the GPS universal time.
Glossary Internal single point indication → Single point indication Single-point indication fleeting → Transient information, → Single point indication IS_F ISO 9001 The ISO 9000 ff range of standards defines measures used to ensure the quality of a product from the development stage to the manufacturing stage. Link address The link address gives the address of a V3/V2 device.
Glossary Navigation pane The left pane of the project window displays the names and symbols of all containers of a project in the form of a folder tree. Object Each element of a project structure is called an object in DIGSI. Object properties Each object has properties.
Glossary RIO file Relay data Interchange format by Omicron. RSxxx-interface Serial interfaces RS232, RS422/485 SCADA Interface Rear serial interface on the devices for connecting to a control system via IEC or PROFIBUS. Service port Rear serial interface on the devices for connecting DIGSI (for example, via modem). Setting parameters General term for all adjustments made to the device.
Glossary Slave A slave may only exchange data with a master after being prompted to do so by the master. SIPROTEC 4 devices operate as slaves. Time stamp Time stamp is the assignment of the real time to a process event. Topological view DIGSI Manager always displays a project in the topological view.
Index Stator Earth Fault Protection 138 Stator Earth Fault Protection with 3rd Harmonic Vector Jump 123 Vibration and Shock Stress During Steady State Op- Stator Overload Protection 59 eration 303 Switch Elements on the PCBs Vibration and Shock Stress During Transport 303 Switchgear control 221 Voltage Inputs 295 Switching authority 228...