Siemens SIPROTEC 7UM62 Manual Download Page 574

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A Appendix

558

7UM62 Manual

C53000-G1176-C149-3

04576 External trip 3: General picked up (Ext

3 picked up)

External Trip
Functions

OUT

ON
OFF

LED

176

04577 External trip 3: General TRIP (Ext 3

Gen.TRP)

External Trip
Functions

OUT

LED

177

04583 >BLOCK external trip 4 (>BLOCK Ext

External Trip
Functions

LED BI

04586 >Trigger external trip 4 (>Ext trip 4)

External Trip
Functions

ON
OF
F

LED BI

186

04591 External trip 4 is switched OFF (Ext 4

OFF)

External Trip
Functions

OUT

ON
OF
F

LED

191

04592 External trip 4 is BLOCKED (Ext 4

BLOCKED)

External Trip
Functions

OUT

ON
OF
F

ON
OFF

LED

192

04593 External trip 4 is ACTIVE (Ext 4

ACTIVE)

External Trip
Functions

OUT

ON
OF
F

LED

193

04596 External trip 4: General picked up (Ext

4 picked up)

External Trip
Functions

OUT

ON
OFF

LED

196

04597 External trip 4: General TRIP (Ext 4

Gen.TRP)

External Trip
Functions

OUT

LED

197

04822 >BLOCK Restart inhibit motor (>BLK

Re. Inhib.)

Restart Inhibit for
Motors

LED BI

04823 >Emergency start rotor (>Emer. Start

Restart Inhibit for
Motors

ON
OF
F

LED BI

168

04824 Restart inhibit motor is switched OFF

(Re. Inhibit OFF)

Restart Inhibit for
Motors

OUT

ON
OF
F

LED

168

04825 Restart inhibit motor is BLOCKED

(Re. Inhibit BLK)

Restart Inhibit for
Motors

OUT

ON
OF
F

LED

168

04826 Restart inhibit motor is ACTIVE (Re.

Inhibit ACT)

Restart Inhibit for
Motors

OUT

ON
OF
F

LED

168

04827 Restart inhibit motor TRIP (Re. Inhib.

TRIP)

Restart Inhibit for
Motors

OUT

LED

168

04828 >Reset thermal memory rotor (>RM

th.rep.

Restart Inhibit for
Motors

ON
OF
F

LED BI

04829 Reset thermal memory rotor (RM

th.rep.

Restart Inhibit for
Motors

OUT

ON
OF
F

LED

168

04830 Alarm restart inhibit motor (Re.

Inhib.ALARM)

Restart Inhibit for
Motors

OUT

ON
OF
F

LED

F.No.

Description

Function

Type

Infor-

matio

Log-Buffers

Configurable in Matrix

IEC 60870-5-103

rip

lt)

/Of

Osc

ill.

Reco

LED

Fun

ina

-N

SDU)

oga

Summary of Contents for SIPROTEC 7UM62

Page 1: ...function Generator Motor and Transformer Protection Relay 7UM62 V4 1 Manual C53000 G1176 C149 3 Preface Table of Contents Introduction 1 Functions 2 Installation and Commissioning 3 Technical Data 4 Appendix A Index ...

Page 2: ... technical improvements without notice Release V4 10 01 Copyright Copyright Siemens AG 2002 All rights reserved Dissemination or reproduction of this document or evalu ation and communication of its contents is not authorized except where expressly permitted Violations are liable for damages All rights reserved particularly for the purposes of patent application or trademark registration Registere...

Page 3: ...f electrical facilities and power plants Applicability of This Manual This manual is valid for SIPROTEC 4 7UM62 Multifunction Generator Motor and Transformer Protections firmware version 4 1 This product is UL certified with the data as stated in Section 4 1 Indication of Conformity This product complies with the directive of the Council of the European Communities on the approximation of the laws...

Page 4: ...lation operation and maintenance of the product as well as careful operation and servicing of the device within the scope of the warnings and instructions of this manual G Training and instruction or other qualification for switching grounding and designating devices and systems G Training and instruction or other qualification for switching grounding and designating devices and systems G First ai...

Page 5: ...produced by the device or required by other devices or from the switch gear is shown in mono script same point size and placed into quotation marks For diagrams in which the identifier type results from the representation itself text conventions may differ from the above mentioned The following symbols are used in diagrams possible conditions On and Off IL1 GND Fault device internal logical input ...

Page 6: ...with parameter address and T Dynamic triggered pulse timer monoflop Static memory RS flipflop with setting input S 1 Exclusive OR gate output is active if only one of the inputs is active Coincidence gate output is active if both inputs are active simultaneously 0 T 1706 T I2 Timer pick up delayed with parameter address and designator resetting input R output Q and inverted Q designator output Q ...

Page 7: ...s 35 2 4 1 Functional Description 35 2 4 2 Setting Hints 35 2 4 2 1 Settings 35 2 4 2 2 Information 35 2 5 Power System Data 2 36 2 5 1 Functional Description 36 2 5 2 Setting Hints 36 2 5 2 1 Settings 36 2 5 2 2 Information 36 2 6 Definite Time Overcurrent Protection I ANSI 50 51 with Undervoltage Seal In38 2 6 1 Functional Description 38 2 6 2 Setting Hints 39 2 6 2 1 Settings for the Definite T...

Page 8: ...Settings of the Startup Overcurrent Protection 74 2 11 2 2 Information for the Startup Overcurrent Protection 74 2 12 Differential Protection ANSI 87G 87M 87T 75 2 12 1 Functional Description 75 2 12 1 1 Protected Object Generator or Motor Particularities 77 2 12 1 2 Protected Object Transformer Particularities 78 2 12 1 3 Evaluation of Measured Quantities 81 2 12 2 Setting Hints 89 2 12 2 1 Diffe...

Page 9: ... Measuring Principle 137 2 18 1 2 Out of Step Logic 139 2 18 2 Setting Hints 142 2 18 2 1 Settings of the Out of Step Protection 146 2 18 2 2 Information for the Out of Step Protection 147 2 19 Undervoltage Protection ANSI 27 148 2 19 1 Functional Description 148 2 19 2 Setting Hints 149 2 19 2 1 Settings of the Undervoltage Protection 150 2 19 2 2 Information for the Undervoltage Protection 150 2...

Page 10: ...ption 185 2 27 2 Setting Hints 187 2 27 2 1 Settings of the Sensitive Earth Fault Protection 188 2 27 2 2 Information for the Sensitive Earth Current Detection 188 2 28 100 Stator Earth Fault Protection with 3rd Harmonics ANSI 27 59TN 3rd Harm 189 2 28 1 Functional Description 189 2 28 2 Setting Hints 191 2 28 2 1 Settings of the 100 Stator Earth Fault Protection with 3rd Harmonics 192 2 28 2 2 In...

Page 11: ...s 231 2 35 2 1 Settings of the Inadvertent Energizing Protection 232 2 35 2 2 Information for the Inadvertent Energizing Function 232 2 36 DC Voltage DC Current Protection ANSI 59NDC 51NDC 234 2 36 1 Functional Description 234 2 36 2 Setting Hints 236 2 36 2 1 Settings of the DC Voltage Protection 238 2 36 2 2 Information from the DC Voltage Protection 238 2 37 Analog Outputs 239 2 37 1 Functional...

Page 12: ...ption 281 2 44 1 1 Processing Tripping Logic 281 2 44 2 Processing Tripping Logic 282 2 44 2 1 Functional Description 282 2 44 2 2 Settings for the Tripping Logic 283 2 44 3 Fault Display on the LEDs LCD 283 2 44 3 1 Principle of Function 283 2 44 3 2 Settings 283 2 44 4 Statistical Counters 284 2 44 4 1 Functional Description 284 2 44 4 2 Setting Resetting 284 2 44 4 3 Information for the Statist...

Page 13: ...ion 336 3 2 1 Checking the Data Connections of Serial Interfaces 336 3 2 2 Checking the Device Connections 338 3 2 3 Checking the Integration in the Plant 343 3 2 3 1 General Hints 343 3 3 Commissioning 346 3 3 1 Test Mode and Blocking Data Transmission 347 3 3 2 Testing the System Interface 347 3 3 3 Checking the Binary Inputs and Outputs 349 3 3 4 Testing the Breaker Failure Scheme 351 3 3 5 Che...

Page 14: ...urrent Time Protection 389 3 4 11 Triggering Oscillographic Recordings 389 3 5 Final Preparation of the Device 391 4 Technical Data 393 4 1 General Device Data 395 4 1 1 Analog Inputs 395 4 1 2 Power Supply 396 4 1 3 Binary Inputs and Outputs 396 4 1 4 Communications Interfaces 397 4 1 5 Electrical Tests 401 4 1 6 Mechanical Stress Tests 403 4 1 7 Climatic Stress Tests 403 4 1 8 Service Conditions...

Page 15: ...4 25 Rotor Earth Fault Protection R fn ANSI 64R 440 4 26 Sensitive Rotor Earth Fault Protection with 1 to 3 Hz ANSI 64R 441 4 27 Motor Starting Time Supervision ANSI 48 442 4 28 Restart Inhibit for Motors ANSI 66 49Rotor 443 4 29 Breaker Failure Protection ANSI 50BF 444 4 30 Inadvertent Energization ANSI 50 27 445 4 31 DC Voltage DC Current Protection ANSI 59NDC 51NDC 446 4 32 Thermoboxes for Temp...

Page 16: ...s of the User Defined Information 506 A 8 1 Source BI F C Destination BO LED C 506 A 8 2 Destination Indication Buffer System Interface 510 A 9 Default Settings 511 A 9 1 Binary Inputs 511 A 9 2 Binary Outputs output relays 511 A 9 3 LED Indicators 514 A 9 4 Function Keys 514 A 9 5 Establishing a Default Display 515 A 9 6 Spontaneous Display Messages 515 A 9 7 Pre Defined CFC Charts 516 A 10 Inter...

Page 17: ...3 Introduction 1 The SIPROTEC 4 7UM62 devices are introduced in this section An overview of the devices is presented in their application characteristics and scope of functions 1 1 Overall Operation 2 1 2 Applications 5 1 3 Features 7 ...

Page 18: ...o levels appropriate for the internal processing of the 7UM62 Eight current inputs are available in the MI section Three inputs are used on each side of the protected object for measuring of the phase currents 2 current inputs are To PC To SCADA Operator Control Panel Uaux up to 15 Binary Inputs Power Supply MI IA AD µC AV Figure 1 1 Hardware Structure of the Numerical Device 7UM62 Maximum Configu...

Page 19: ...s and control actions and provision of their data for analysis Management of the operating system and the associated functions such as data recording real time clock communications interfaces etc Adaptation of Sampling Frequency The frequency of the measured quantities is continuously measured and used for determination of the actual sampling frequency This ensures that the protection functions ar...

Page 20: ...can be transferred to a central master or main control system through the serial system SCADA interface Various protocols and physical arrangements are available for this interface to suit the particular application A fourth interface is provided for time synchronization of the internal clock by external sources Further communications protocols can be realized via additional interface modules Anal...

Page 21: ...ction The scalable software allows to use the device for a wide range of applications as function packages can be chosen individually for the application in hand For instance one 7UM62 is sufficient to provide for reliable all round protection of generators with a small to medium output about 5 MW Additionally the device forms the basis for the protection of larger generators By adding a 7UM61 fur...

Page 22: ...g the DIGSI 4 software These processes include selecting and modifying the settings allocation of the binary inputs and outputs configuration of the user definable logic functions reading the event and fault data retrieving the measured values obtaining the oscillographic fault records reading the states of the 7UM62 and the measurement quantities and issuing control commands Interfaces on Back Fu...

Page 23: ...signal or system interface command Recording of circuit breaker statistics including the number of trip signals sent and the accumulated interrupted currents of each pole of the circuit breaker Tracking of operating hours time when load is supplied of the equipment being protected Commissioning aids such as connection check status information of binary inputs and relay outputs and start of a fault...

Page 24: ...cs High speed tripping in case of high current faults Integrated matching of transformer vector group Integrated matching of transformation ratio with consideration of different c t rated currents Earth Current Differential Protection Tripping characteristic with restraining current Variable selection of measured quantities for all normal plant conditions High sensitivity Additional stabilisation ...

Page 25: ...th settable voltage dependent time characteristic Overvoltage Protection Two stage overvoltage measurement evaluation of the highest of the three voltages Optionally with phase to phase voltages or with phase to earth voltages Frequency Protection Four elements that are independently adjustable for function underfrequency or overfrequency pickup and time delay Insensitive to harmonics and abrupt p...

Page 26: ... 20 Hz Voltage Injection Evaluation of the 20 Hz measurement 7XT33 and 7XT34 Warning and trip stage R and R Trip stage with earth current High sensitivity also at large stator earth capacitances Rotor Earth Fault Protection 100 protection for the entire excitation circuit Symmetrical capacitive coupling of a system frequency AC voltage into the excitation circuit with consideration of operational ...

Page 27: ...C Voltage DC Current Protection DC voltage detection via integrated isolating amplifier measuring transducer Suited for measurement of small DC currents Can be set for overvoltage overcurrent or undervoltage undercurrent Optional average value or true r m s value formation the latter is suited to AC voltage measurement Analog Outputs Output of up to four analog operational measured values dependin...

Page 28: ...cking conditions Measuring Transducers If the 3 measuring transducers provided in the unit are not needed by the protection functions they can be used to connect any type of analog signals 10 V 20 mA Threshold processing and logical linking of measurement signals possible Monitoring Functions Availability of the 7UM62 is greatly increased because of self monitoring of the internal measurement circ...

Page 29: ...SI 51V 48 2 9 Thermal Overload Protection ANSI 49 55 2 10 Unbalanced Load Negative Sequence Protection ANSI 46 65 2 11 Startup Overcurrent Protection ANSI 51 71 2 12 Differential Protection ANSI 87G 87M 87T 75 2 13 Earth Current Differential Protection ANSI 87GN TN 98 2 14 Underexcitation Loss of Field Protection ANSI 40 106 2 15 Reverse Power Protection ANSI 32R 115 2 16 Forward Active Power Supe...

Page 30: ... Voltage Injection ANSI 64R 1 to 3 Hz 206 2 32 Motor Starting Time Supervision ANSI 48 213 2 33 Restart Inhibit for Motors ANSI 66 49Rotor 217 2 34 Breaker Failure Protection ANSI 50BF 225 2 35 Inadvertent Energization ANSI 50 27 230 2 36 DC Voltage DC Current Protection ANSI 59NDC 51NDC 234 2 37 Analog Outputs 239 2 38 Measured Value Monitoring Functions 241 2 39 Trip Circuit Supervision 254 2 40...

Page 31: ...o the technical requirements of the regions X Selectable option Function not available for this region Table 2 1 Regionalization Function Region DE Germany Region Worldwide Worldwide Region US USA Language German English American English Frequency 50 Hz 50 Hz 60 Hz Default setting 50 Hz 60 Hz Characteristic curves for inverse time overcurrent elements IEC curves ANSI curves X X Default setting IEC...

Page 32: ...e the busbar connection and the unit connection see Figure 2 1 All default settings of the relay are adapted accordingly The allocation of measured quantities to side 1 and 2 respectively is shown in Figure 2 1 Figure 2 1 Reference Systems 7UM62 7UM62 G a Busbar connection b Unit connection UE IL S2 IEE1 UL 6 3 kV 3 500 V 500 A 1 A 5 27 MVA 6 3 kV 6 3 kV 3 100 V 3 5 3 MVA 20 kV 6 3 kV 20 kV IL S2 ...

Page 33: ...of the individual protective functions The calculated setting values are secondary setting values related to the device and can be modified immediately by way of local operation The use of the DIGSI 4 operating program is recommended for complete reparameterization In this way the user has the possibility to specify primary values in addition to secondary settings Within the framework of the 7UM62...

Page 34: ...tion of Functional Scope Configuration settings may be entered using a PC and the software program DIGSI 4 and transferred via the operator interface on the device front or via the rear serial service interface Operation is described in the SIPROTEC 4 System Manual Entry of password No 7 for setting modification is required to modify configuration settings Without the password the settings may be ...

Page 35: ...her by setting Disabled Table 2 2 shows the allocation of device inputs to the protection functions The interdependencies shown here must be kept in mind when configuring the plant This concerns the UE input the two sensitive current inputs IEE1 and IEE2 as well as the 3 measuring transducer inputs TD Where the UE input is used e g by the stator earth fault protection functions it is no longer ava...

Page 36: ...monics ANSI 27 59TN Fixed Fixed Fixed 100 Stator Earth Fault Prot with 20 Hz Voltage Injection 64G 100 Fixed Fixed Rotor Earth Fault Protection REFP ANSI 64R Fixed Fixed Sensitive Rotor Earth Fault Pro tection with 1 to 3 Hz Square Wave Voltage Injection ANSI 64R TD1 TD2 Motor Starting Time Supervision ANSI 48 Fixed Restart Inhibit for Motors ANSI 66 49Rotor Fixed Breaker Failure Protection ANSI 5...

Page 37: ...Differential Protection Figure 2 3 Use as Block Differential Protection Overall Protection For the following application the settings of the generator data under Power System Data 1 must be same as for the transformer data of side 2 Figure 2 4 Use as Transformer Differential Protection 7UM62 G 3 Side 2 Side 1 Address 0120 DIFF PROT Generator Motor 7UM62 G 3 Side 2 Side 1 Address 0120 DIFF PROT 3 p...

Page 38: ...iterion the direction of the earth fault current in the case of machines in busbar connection where the magnitudes of displacement voltage and earth fault current alone are not sufficient to distinguish between system earth faults and machine earth faults Address 0151 O C PROT Iee is used to specify which input will be used for earth fault current measurement IEE1 or IEE2 Address 0170 BREAKER FAIL...

Page 39: ...O C PROT Ip Disabled with IEC characteristic on side 1 with ANSI characteristic on side 1 with IEC characteristic on side 2 with ANSI characteristic on side 2 Disabled Inverse O C Time Protection 116 Therm Overload Disabled Enabled Enabled Thermal Overload Protection 117 UNBALANCELOAD Disabled Enabled Enabled Unbalance Load Negative Sequence 118 O C STARTUP Disabled Enabled Enabled Startup O C pro...

Page 40: ...led non directional only U0 non directional with U0 I0 directional non directional with U0 I0 Stator Earth Fault Protection 151 O C PROT Iee Disabled with Iee1 with Iee2 with Iee2 Sensitive Earth Current Protec tion 152 SEF 3rd HARM Disabled Enabled Enabled Stator Earth Fault Prot 3rd Har monic 153 100 SEF PROT Disabled Enabled Enabled 100 Stator Earth Fault Protec tion 160 ROTOR E F Disabled Enab...

Page 41: ...sitive Sequence Current I1 Negative Sequence Current I2 Positive Sequence Voltage U1 Active Power P Reactive Power Q Frequency f Power Factor p u Temperature of Rotor p u Temperature of Stator Disabled Analog Output B2 Port B 175 ANALOGOUTPUT D1 Disabled Positive Sequence Current I1 Negative Sequence Current I2 Positive Sequence Voltage U1 Active Power P Reactive Power Q Frequency f Power Factor p...

Page 42: ... with 1 Binary Input Disabled Trip Circuit Supervision 185 THRESHOLD Disabled Enabled Enabled Threshold Supervision 186 EXT TRIP 1 Disabled Enabled Enabled External Trip Function 1 187 EXT TRIP 2 Disabled Enabled Enabled External Trip Function 2 188 EXT TRIP 3 Disabled Enabled Enabled External Trip Function 3 189 EXT TRIP 4 Disabled Enabled Enabled External Trip Function 4 190 RTD BOX INPUT Disabl...

Page 43: ...urrent Transformer Sets At address 0201 STRPNT OBJ S1 you specify the polarity of the CTs of plant side 1 i e the location of the CT starpoint with reference to the protected object At address 0210 STRPNT OBJ S2 the polarity of the CTs of side 2 is specified This setting determines the measuring direction of the 7UM62 STRPNT OBJ S2 Yes Forwards line direction Figure 2 6 shows the definition even i...

Page 44: ...T ANGLE W0 a constant correction angle can be entered for the CTs of side 2 The angle fault difference ϕ between the current transformers and voltage transformers is particularly important in this context As a correction the sum of the mean angle errors of the current transformers and voltage transformers is set The corrective value can be determined within the framework of machine commissioning s...

Page 45: ...applies In this context UVT prim is the primary voltage and UE sec is the secondary displacement voltage applied to the device If a voltage divider is used its divider ratio also influences this factor The following equation results for the example in Figure 2 1b with the power system data selected there and an 1 5 voltage divider ratio Table 2 3 Setting Options for the UE Input and their Impact o...

Page 46: ...lue monitoring summation current monitoring in transformer differential protection it is also important for the vector group correction and the treatment of the zero sequence current The setting Isolated can be chosen if the starpoint has no earthing If the transformer starpoint is connected to a Petersen coil or a surge voltage arrester choose the setting Solid Earthed The same applies to low ohm...

Page 47: ...s active if the differential protection in the scope of functions is set to 0120 Disabled or Gen erator Motor It applies for both side 1 and side 2 Rated Frequency The rated system frequency is set at address 0270 Rated Frequency The setting is dependent on the model number of the relay purchased and must be in accordance with the nominal frequency of the power system Phase Rotation Phase Sequence...

Page 48: ...trol Depending on the intended application select at address 0295 TRANSDUCER 1 either 10 V 4 20 mA or 20 mA In the first case the measuring range is between 10 V and 10 V The 4 20 mA interface is designed for operation with sign i e a current of 12 mA corresponds to an input value of 0 see Figure 2 9 With currents in excess of 2 mA the device signals a wire break The alarm drops out at currents be...

Page 49: ...1 is 244 STARPNT SIDE 2 Isolated Solid Earthed Isolated Starpoint of side 2 is 241 UN PRI SIDE 1 0 40 800 00 kV 20 00 kV Rated Primary Voltage Side 1 243 UN PRI SIDE 2 0 40 800 00 kV 6 30 kV Rated Primary Voltage side 2 246 VECTOR GRP S2 0 11 0 Vector Group Numeral of Side 2 249 SN TRANSFOR MER 0 20 5000 00 MVA 5 30 MVA Rated Apparent Power of the Transformer 201 STRPNT OBJ S1 YES NO YES CT Strpnt...

Page 50: ...delta 1 00 3 00 1 73 Matching Ratio Ph VT to Bro ken Delta VT 280 TMin TRIP CMD 0 01 32 00 sec 0 15 sec Minimum TRIP Command Dura tion 281 BkrClosed I MIN 0 04 1 00 A 0 04 A Closed Breaker Min Current Threshold 295 TRANSDUCER 1 10 V 4 20mA 20mA 10 V Transducer 1 296 TRANSDUCER 2 10 V 4 20mA 20mA 10 V Transducer 2 297 TRANSDUCER 3 with filter without filter with filter Transducer 3 Addr Setting Tit...

Page 51: ...tings are made in the setting groups and stored in the device Every time the operating mode changes the applicable setting group is activated usually by a binary input If multiple setting groups are not required Group A is the default selection and the following paragraph is not applicable 2 4 2 Setting Hints If multiple setting groups are desired Grp Chge OPTION Enabled must have been set address...

Page 52: ...ere the item P Systemdata2 The second setting group is accessed in P Group B Active Power Direction Address 1108 ACTIVE POWER is used to specify the active power direction in the normal mode Generator output or Motor input or to adapt it to the power system conditions without any recabling on the device 2 5 2 1 Settings 2 5 2 2 Information Addr Setting Title Setting Options Default Setting Comment...

Page 53: ...Power System Data 2 37 7UM62 Manual C53000 G1176 C149 3 05017 f Frequency at trip F No Alarm Comments ...

Page 54: ... the positive sequence component of the voltages and uses it as an additional criterion for detecting a short circuit The undervoltage influencing can be switched off and made ineffective by means of a binary input 2 6 1 Functional Description I stage Each phase current is compared individually with the I common setting value Currents above these value are recorded and signalled individually As so...

Page 55: ...ted peak load is recommended for generators and a setting equal to 40 over the expected peak load is recommended for transformers and motors The trip time delay parameter 1203 T I must be coordinated with the time grading of the network in order to ensure that the protective equipment closest to the corresponding fault location trips first selectivity The settable time is only an additional time d...

Page 56: ... prim500 A Nominal voltage UN VT prim 6 3 kV Nominal current IN sec 1 A Nominal voltage UN sec 100 V The following secondary setting values result from this specification 2 6 2 1 Settings for the Definite Time Overcurrent Protection Stage I The following list indicates the setting ranges and the default settings of a IN 1 A secondary nominal current For a secondary nominal current of IN 5 A these ...

Page 57: ...K I 01950 Useal in BLK O C prot BLOCK undervoltage seal in 01965 I OFF O C prot stage I is switched OFF 01966 I BLOCKED O C prot stage I is BLOCKED 01967 I ACTIVE O C prot stage I is ACTIVE 01811 I Fault L1 O C fault detection stage I phase L1 01812 I Fault L2 O C fault detection stage I phase L2 01813 I Fault L3 O C fault detection stage I phase L3 01970 U seal in O C prot undervoltage seal in 01...

Page 58: ...mental frequency currents are used for the measurement This makes the measurement insensitive to transient conditions at the inception of a short circuit and to asymmetrical short circuit currents d c component 2 7 1 Functional Description I Stage Each phase to phase current of side 1 or 2 depending on the configuration is compared individually with the I common setting value Currents above these ...

Page 59: ...e fault direction for various types of short circuit faults If the phase to phase voltage used for the direction decision is below the minimum value of approx 7 V the voltage is taken from a voltage memory This voltage also allows an unambiguous direction determination if the short circuit voltage has collapsed short circuit close to generator terminals After the expiration of the storage Table 2 ...

Page 60: ...al The high current stage I of the overcurrent protection is only effective and accessible if it has been assigned within the framework of configuration at address0113 O C PROT I to either side 1 or side e i e if either Non dir Side 1 side 2 Dir Side 1 or Dir side 2 was set Disabled is selected if the function is not needed If you use the direction element make sure that the CT and VT set are cons...

Page 61: ... Phase Direction and 1305 LINE ANGLE are accessible The inclination of the direction straight line see figure 2 14 representing the separating line between the tripping and the blocking zone can be adapted to the network conditions by way of the LINE ANGLE parameter To do this the line angle of the network is set The direction straight line is perpendicular to the set direction angle Together with...

Page 62: ... required to ensure that the effect of the transient phenomena is eliminated Application Example Motor Protection For motors that have no separate current transformers in the starpoint Figure 2 15 shows how to use the I stage as differential protection The configuration of the protection function depends on the transformers Since this application is most likely to be used for replacements in an ex...

Page 63: ...ng Comments 1301 O C I OFF ON Block relay for trip com mands OFF Overcurrent Time Protection I 1302 I 0 05 20 00 A 4 30 A I Pickup 1303 T I 0 00 60 00 sec 0 10 sec T I Time Delay 1304 Phase Direction Forward Reverse Reverse Phase Direction 1305 LINE ANGLE 90 90 60 Line Angle F No Alarm Comments 01721 BLOCK I BLOCK I 01720 BLOCK dir BLOCK direction I stage 01955 I OFF O C prot stage I is switched O...

Page 64: ... to the IEC or ANSI standards The characteristic curves and the corresponding formulas are represented in Technical Data Figures 4 1 to 4 3 in Section 4 3 If one of the inverse characteristics IEC or ANSI are configured the definite time stages I and I can be additionally effective see Section 2 6 and 2 7 Pickup Trip Each phase current is compared individually with the common Ip setting value If a...

Page 65: ...the device by means of the parameter 0213 SCHEME As phase to phase voltages are referred to in any case faulty measurements in case of earth faults are avoided In order to avoid an unwanted operation for a voltage transformer fault a blocking function miniature circuit breaker as well as via the device internal measuring voltages failure detection Fuse Failure Monitor also refer to section 2 38 1 ...

Page 66: ...Time Protection without Undervoltage Influencing Tripping matrix BLOCK O C Ip FNo 01883 1403 T Ip 1403 T Ip 1403 T Ip Pickup IL1 Pickup Pickup FNo 01900 O C Ip TRIP FNo 01892 O C Ip BLOCKED FNo 01897 O C Ip Fault L2 FNo 01896 O C Ip Fault L1 FNo 01898 O C Ip Fault L3 OR FNo 01899 O C Ip pick up OR TMin TRIP CMD ...

Page 67: ...sing voltage loop release is performed on a phase by phase basis according to table 2 5 1403 T Ip 1403 T Ip 1402 Ip Tripping matrix BLOCK O C Ip FNo 01883 1403 T Ip FNo 01900 O C Ip TRIP FNo 01892 O C Ip BLOCKED FNo 01897 O C Ip Fault L2 FNo 01896 O C Ip Fault L1 FNo 01898 O C Ip Fault L3 1402 Ip FAIL Feeder VT FNr 000361 Fuse Failure Loop release IL1 IL2 IL3 UL1 UL2 UL3 1402 Ip FNo 01899 O C Ip p...

Page 68: ...NSI characteristic on side 2 was set Disabled is selected if the function is not needed Ip overcurrent stage Address 1401 O C Ip is used to switch the function ON or OFF or to block only the trip command Block Relay It must be noted that for the inverse O C time protection a safety factor of about 1 1 has been included between the pick up value and the setting value This means that a pickup will o...

Page 69: ...T Ip Disabled or switch the function out by setting 1401 O C Ip OFF during configuration see Section 2 2 The address 1408 serves to predefine the U pick up value for the undervoltage trip of the Ip pickup value for voltage controlled inverse O C time protection AMZ parameter 1407 VOLT INFLUENCE Voltage controlled The parameter is set to a value situated just below the lowest phase to phase voltage...

Page 70: ... V U Threshold for Release Ip Addr Setting Title Setting Options Default Setting Comments F No Alarm Comments 01883 BLOCK O C Ip BLOCK inverse O C time protection 01891 O C Ip OFF O C protection Ip is switched OFF 01892 O C Ip BLOCKED O C protection Ip is BLOCKED 01893 O C Ip ACTIVE O C protection Ip is ACTIVE 01896 O C Ip Fault L1 O C fault detection Ip phase L1 01897 O C Ip Fault L2 O C fault de...

Page 71: ...ork It is also possible however to set the overload protection to Alarm only If this option is set the device only outputs an alarm even if the end temperature is reached The temperature rise is calculated from the highest of the three phase currents Since the calculation is based on the r m s values of the currents it also considers harmonics which contribute to a temperature rise of the stator w...

Page 72: ...If the ambient or coolant temperature is low the machine can support a higher current than it does when the temperature is high Current Limiting In order to avoid that the thermal overload protection reaches extremely short trip times on occurrence of high short circuit currents and on selection of a small time constant and thus perhaps affects the time grading of the short circuit protection it i...

Page 73: ...ripping will be defeated until this time interval elapses The binary input used for emergency starting affects only the tripping signal There is no effect on the fault event protocol nor does the thermal memory reset Behaviour in the Case of a Power Supply Failure For the overload protection together with all other thermal protection functions of the 7UM62 you can set in the Power System Data 1 pa...

Page 74: ...516 O L Q Alarm FNo 01521 ThOverload TRIP FNo 01512 Th Overload BLK FNo 01513 Overload ACT FNo 01511 Th Overload OFF RM th rep O L FNo 01506 Block relay FNo 01517 O L Th pick up FNo 01508 Fail Temp inp Emer Start O L FNo 01507 1616A T EMERGENCY 1615A I Θ FNo 01519 RM th rep O L I kτ x τ CB closed I MAX THERM BkrClosed I MIN 0281 1612A Kt FACTOR 1610A I ALARM 1602 K FACTOR 1603 TIME CONSTANT 1607 T...

Page 75: ...ay for trip commands or set the protection function to Alarm Only In that last case no fault record is created n case of an overload If the overload protection is switched ON tripping is also possible K Factor The overload protection is set in per unit quantities The nominal current IN machine of the object to be protected generator motor transformer is typically used as base current The thermally...

Page 76: ...mer current of the tripping temperature Consequently the warning stage should be set between the final overtemperature with the nominal current in this case 83 and the tripping overtemperature 100 In the present example the thermal memory reaches the following value if the nominal current is applied A current warning level parameter 1610A I ALARM is also available The level is set in secondary amp...

Page 77: ...in C or 1609 in F TEMP SCAL The value set there is equivalent to 100 of the Profibus DP Modbus value or full scale deflection 20 mA of the measuring transducer In the default setting 100 Profibus DP Modbus or 20 mA measuring transducer TD2 correspond to 100 C Is under address 1607 TEMP INPUT the setting temperature of RTD 1 selected the temperature scaling of addresses 1608 1609 is ineffective Nei...

Page 78: ...ndary current Ipre Previous load current ΘN Temperature with nominal current IN address 1605 TEMP RISE I ΘK Coolant temperature input scaling with address 1608 or 1609 Example Machine INMach 483 A ImaxMach 1 15 IN at ΘK 40 C ΘNMach 93 C Temperature at INMach τ 600 s thermal machine time constant Current transformer 500 A 1 A t τ I k IN è ø æ ö2 ΘK 40 C k 2 ΘN Ipre k IN è ø æ ö 2 I k IN è ø æ ö2 ΘK...

Page 79: ...2 100 C 0 1 5 1 1 è ø æ ö 2 80 C 40 C 1 1 2 100 C 1 ln è ø ç ç ç ç æ ö 366 s with ΘK 80 C t 600 s 1 5 1 1 è ø æ ö 2 0 C 40 C 1 1 2 100 C 0 1 5 1 1 è ø æ ö 2 0 C 40 C 1 1 2 100 C 1 ln è ø ç ç ç ç æ ö 637 s with ΘK 0 C Addr Setting Title Setting Options Default Setting Comments 1601 Ther OVER LOAD OFF ON Block relay for trip com mands Alarm Only OFF Thermal Overload Protection 1602 K FACTOR 0 10 4 0...

Page 80: ...r thermal replica O L 01507 Emer Start O L Emergency start O L 01508 Fail Temp inp Failure temperature input 01511 Th Overload OFF Thermal Overload Protection OFF 01512 Th Overload BLK Thermal Overload Protection BLOCKED 01513 Overload ACT Overload Protection ACTIVE 01514 Fail Temp inp Failure temperature input 01519 RM th rep O L Reset memory for thermal replica O L 01515 O L I Alarm Overload Cur...

Page 81: ... I2 is exceeded a warning message I2 Warn is transmitted after a selectable time T WARN see Figure 2 21 Thermal Characteristic The machine manufacturers indicate the permissible unbalanced load by means of the following formula The asymmetry factor depends on the machine and represents the time in seconds during which the generator can be loaded with a 100 unbalanced load This factor is typically ...

Page 82: ...ctions regarding the phase rotation phase sequence provided in Sections 2 3 and 2 43 Figure 2 21 Tripping Zone of the Unbalanced Load Protection Figure 2 22 Logic Diagram of the Unbalanced Load Protection I2 t Thermal trip stage Unbalanced load Tripping zone I2 I2 adm I2 T I2 T WARN Unbalanced load stage I2adm RM th rep I2 FNo 05146 IL1 IL2 IL3 BLOCK I2 FNo 05143 1703 T WARN 1702 I2 1705 I2 1707 T...

Page 83: ...ions of the machine manufacturer It is important to ensure that the values given by the manufacturer represent the primary values of the machine For example if the long time allowable thermal inverse current with respect to the nominal machine current is given this value must be used to calculate the settings for the unbalanced load time overcurrent element For the settings on the protective relay...

Page 84: ...primary can be converted to the secondary side by means of the following formula The calculated asymmetry factor Ksec is set as FACTOR K at address 1704 Setting value at address1704 Figure 2 23 Example of an Unbalanced Load Characteristic Specified by the Machine Manufacturer Example IN Machine 483 A IN CT prim 500 A Factor Kprimary 20 s Ksec Kprimary IN Machine IN CT prim è ø æ ö 2 20 s 483 A 500...

Page 85: ...rformed according to the thermal characteristic in case of a phase failure unbalanced load always less than 100 3 i e I2 58 On the other hand a two pole short circuit can be supposed for an unbalanced load of more than 60 to 65 The delay time T I2 address 1707 must be coordinated with the system grading of phase to phase short circuits Contrary to the time overcurrent protection the I2 stage is ab...

Page 86: ...I2 Time Delay Addr Setting Title Setting Options Default Setting Comments F No Alarm Comments 05143 BLOCK I2 BLOCK I2 Unbalance Load 05146 RM th rep I2 Reset memory for thermal replica I2 05151 I2 OFF I2 switched OFF 05152 I2 BLOCKED I2 is BLOCKED 05153 I2 ACTIVE I2 is ACTIVE 05158 RM th rep I2 Reset memory of thermal replica I2 05156 I2 Warn Unbalanced load Current warning stage 05165 I2 picked u...

Page 87: ...t can occur in the generator during startup a short circuit protection is necessary over the entire frequency range The 7UM62 offers for this a highly useful feature namely its automatic adaption of the sampling frequency to the current generator frequency which ensures the same sen sitivity over the entire frequency range This adaption starts at the transition from 10 Hz to 11 Hz As a result all ...

Page 88: ...ess 118 during configuration of the protection functions Address 1801 O C STARTUP is used to switch the function ON or OFF or to block only the trip command Block relay Pickup Value Figure 2 24 shows that the currents during startup amount to approx 20 of the nom inal currents This allows to set the protection routinely to less than nominal current As can be seen in Figure 2 25 the function is blo...

Page 89: ... may be useful to avoid overfunc tioning This delay time should be based on the lowest detectable frequency of 2 Hz and set to 0 5 s Short Circuit Coordination Figure 2 27 shows the interaction between the short circuit protection functions such as Startup overcurrent function Differential protection I stage as back up stage for 10 Hz and higher The pickup thresholds in this figure are for orienta...

Page 90: ...P OFF ON Block relay for trip com mands OFF Startup O C protection 1802 STARTUP I 0 10 20 00 A 1 30 A I Pickup 1803 STARTUP T I 0 00 60 00 sec 0 50 sec T I Time Delay F No Alarm Comments 05571 BLOCK O C St BLOCK startup O C protection 05572 O C Start OFF Startup O C protection is switched OFF 05573 O C Start BLK Startup O C protection is BLOCKED 05574 O C Start ACT Startup O C protection is ACTIVE...

Page 91: ...is a certain indication of a fault somewhere within the protected zone The secondary windings of current transformers CT1 and CT2 which have the same transformation ratio may be so connected that a closed circuit is formed If now a measuring element M is connected at the electrical balance point it reveals the current difference Under healthy conditions e g on load operation no current flows in th...

Page 92: ...ugh a healthy transformer or external fault I2 reverses its direction i e thus changes its sign i e I2 I1 and consequently I2 I1 Idiff I1 I2 I1 I1 0 Istab I1 I2 I1 I1 2 I1 No tripping effect Idiff stabilization Istab corresponds to twice the through flowing current 2 Internal short circuit e g fed with equal currents each side In this case I2 I1 and consequently I2 I1 Idiff I1 I2 I1 I1 2 I1 Istab ...

Page 93: ...ch side of the protected object 2 12 1 1 Protected Object Generator or Motor Particularities Definition and Matching of Measured Quantities The differential protection function of the 7UM62 can be used as longitudinal or as transverse differential protection The operation modes differ from each other only by the definition of the measured current and the limits of the protected zone Since the curr...

Page 94: ...this type of circuit always if there is a current difference within the phases and only in that case so that a fault current in that phase can be assumed Since in this case unlike the other applications all currents flow into the protected ob ject in healthy operation a wrong polarity is set for one set of CTs as described in Section 2 3 2 under Connection of the Current Transformer Sets Figure 2 ...

Page 95: ...he phase angles between the primary and the secondary side Without adequate correction this phase shift would cause a differential current The following paragraphs describe the main functional blocks of the differential protection that allow to control the above influences Matching the Values of Measured Quantities The digitized currents are matched the transformer rated current The characteristic...

Page 96: ...rthed Transformer Starpoint Figure 2 34 shows an example of a YNd5 vector group with earthed starpoint on the Y side The zero sequence currents are eliminated in this case In Figure 2 34 on the right side the zero sequence currents are automatically eliminated by the current difference formation just as in the transformer there can be no zero sequence currents outside the delta winding On the left...

Page 97: ...for calculation is shown in the left hand matrix in Figure 2 34 Figure 2 35 Example of an Earth Fault Outside the Transformer with Distribution of Currents 2 12 1 3 Evaluation of Measured Quantities The 7UM62 performs the above calculations matching of absolute values vector group matching in the case of transformers at every sampling and derives from them the instantaneous values of differential ...

Page 98: ... by mismatching or by the influence of tap changers in transformers with voltage control In the range of high currents which may give rise to current transformer saturation branch c provides for additional stabilization In the presence of differential currents above branch d a trip command is issued regardless of the stabilizing current and the harmonic stabilization This is the operating range of...

Page 99: ...rrents can exclude that it is an external fault This is always the case when the short circuit current is higher than 1 usc IN Transf Add on StabilizationDuring Current Transformer Saturation During an external fault which produces a high through flowing short circuit current causing current transformer saturation a considerable differential current can be simulated especially when the degree of s...

Page 100: ... limited by the parameter I ADD ON STAB and the first straight line of the characteristic with BASE POINT 1 and SLOPE 1 see Figure 2 38 The saturation indicator makes its decision within the first quarter of a period after fault inception When an external fault is detected the differential protection is blocked for a selectable time The blocking is cancelled as soon as the operating point Idiff Is...

Page 101: ...rents are analyzed with regard to their harmonics content Numerical filters are used to perform a Fourier analysis of the differential current As soon as the harmonics content exceeds the set thresholds a stabilization of the respective phase evaluation is started The filter algorithms are optimized with regard to their transient behaviour such that additional measures for stabilization during dyn...

Page 102: ...proportionally This is done by dividing the DIFF current of the respective phase by the factor START FACTOR before the characteristic monitoring The differential current for fault recording tripping current etc is not affected by this The return of the stabilizing current indicates the startup After a settable time T START MAX the increase of the characteristic is cancelled Figure 2 40 Increase of...

Page 103: ...d Figure 2 42 shows a simplified diagram of the tripping logic Reset is initiated when during 2 periods pick up is no longer recognized in the differential values i e the differential current has fallen below 70 of the set value and the other pickup conditions are no longer fulfilled either If a trip command has not been initiated the fault is considered to be over If a trip command had been initi...

Page 104: ...Diff TRIP FNo Diff TRIP FNo 05692 Diff FNo Diff TRIP Characteristic Inrush stabilization 2nd harm Harmonic stabilization 3rd or 5th Add on stabilization ext fault FNo Diff Bl exF L1 Diff Bl exF L2 Diff Bl exF L3 FNo Diff TRIP FNo Diff TRIP Diff L3 Diff L2 FNo Diff L1 2036A T I DIFF T 1 1 Meas release Meas release Meas release T FNr Diff n Harm L1 Diff n Harm L2 Diff n Harm L3 FNo Diff 2 Harm L1 Di...

Page 105: ...Section 2 3 Also the nominal values SN GEN MOTOR UN GEN MOTOR of the machine to be protected and the primary and secondary nominal currents of the main CTs on both sides must be entered The settings are referred to these values They are also used e g for determining the primary measured values Information as to the treatment of the starpoint on both sides is required for the measured value monitor...

Page 106: ...nerator The tripping characteristic has two more branches Figure 2 43 Address 2041A SLOPE 1 determines the slope of the first branch whose starting point is specified in the parameter 2042A BASE POINT 1 This branch considers current proportional error currents These are mainly transformation errors of the main CTs and of the input CTs If the CTs are identical the default setting of 0 25 can be red...

Page 107: ...dition A precondition for the operation of the transformer differential protection is that during configuration address 0120 DIFF PROT was set to Three phase transf To ensure the correct polarity for the formation of the differential current the polarity of the sets of CTs must be specified This has been done during the configuration when entering the location of the starpoints of the sets of CTs ...

Page 108: ...of the protected transformer winding has no connection to earth not even via a Petersen coil or a surge arrester In this case each double earth fault with one base point in the protected zone will be cleared by the relay regardless of any double earth fault priority see side title Isolated Starpoint and Figure 2 33 Increase of Pickup Value on Startup For additional security against overfunctioning...

Page 109: ...nrush restraint to set the protection such that not only the phase with harmonics content in excess of the permissible value is stabilized but also the other phases of the differential stage are blocked cross block function The duration for which the cross block function is operative after the differential current threshold has been exceeded is set at address 2072A CROSSB n HARM Setting is in mult...

Page 110: ...h the protected object during external short circuits an add on stabilization takes effect that is set at address 2057A I ADD ON STAB stabilization in case of saturation Please note that the stabilizing current is the arithmetical sum of the currents entering and leaving the protected zone i e that it is twice the actually flowing current The default setting of 4 00 I InO should be kept The maximu...

Page 111: ...ec T I DIFF Time Delay 2031 I DIFF 0 5 12 0 I InO 7 5 I InO Pickup Value of High Set Trip 2036A T I DIFF 0 00 60 00 sec 0 00 sec T I DIFF Time Delay 2041A SLOPE 1 0 10 0 50 0 25 Slope 1 of Tripping Characteri stic 2042A BASE POINT 1 0 00 2 00 I InO 0 00 I InO Base Point for Slope 1 of Cha rac 2043A SLOPE 2 0 25 0 95 0 50 Slope 2 of Tripping Characteri stic 2044A BASE POINT 2 0 00 10 00 I InO 2 50 ...

Page 112: ...1 05652 Diff Bl exF L2 Diff prot Blocked by ext fault L2 05653 Diff Bl exF L3 Diff prot Blocked by ext fault L3 05657 DiffCrosBlk2HM Diff Crossblock by 2 Harmonic 05658 DiffCrosBlknHM Diff Crossblock by n Harmonic 05666 Diff in char L1 Diff Increase of char phase L1 05667 Diff in char L2 Diff Increase of char phase L2 05668 Diff in char L3 Diff Increase of char phase L3 05670 Diff I Release Diff C...

Page 113: ... Diff prot Adaptation factor CT side 1 05714 Diff CT S2 Diff prot Adaptation factor CT side 2 05701 Diff L1 Diff current in phase L1 at trip 05702 Diff L2 Diff current in phase L2 at trip 05703 Diff L3 Diff current in phase L3 at trip 05704 Res L1 Restr current in phase L1 at trip 05705 Res L2 Restr current in phase L2 at trip 05706 Res L3 Restr current in phase L3 at trip F No Alarm Comments ...

Page 114: ...e zero se quence current is calculated from the measured phase currents whereas the starpoint current is measured directly This application is the version for transformers and for the generator with direct low ohmic earthing In connection scheme 2 both zero sequence currents are calculated from the mea sured phase currents The protected object is located between the current transform ers This meas...

Page 115: ...ide 2 3I02 Depending on the network earthing conditions there may also be an earthing current 3I01 flowing through the CTs of side 1 to the fault location dashed arrow Due to the definition of the current direction however the zero sequence cur rent 3I01 is more or less in phase with the starpoint current When an earth fault occurs outside the protected zone Figure 2 47 fault location 2 there is a...

Page 116: ...o currents on both sides 3I01 and 3I02 and calculates from them the differential and the restraint current I0 Diff 3I01 3I02 I0 Res 3I01 3I02 Depending on the application the current 3I02 may be the calculated zero sequence current of side 2 or the directly measured starpoint current ISt Under no fault conditions and with ideal CTs the zero sequence currents would be zero and consequently the diff...

Page 117: ...ne another so that their CT error resulting zero sequence current under steady state conditions is minimized Further restraining measures include Additional evaluation of the starpoint current see above Only in the presence of an earth fault can a current flow through the starpoint CTs This helps to avoid under no fault conditions spurious tripping due to transformation errors of the phase current...

Page 118: ...al restraint in the presence of external faults without earth involve ment The zero voltage is calculated from the phase to earth voltages On detection of a zero voltage a release signal is output Logic The logic interconnection of all signals and the most important settings as well as the indications output are shown in Figure 2 50 The function can be blocked with the in put BLOCK REF This input ...

Page 119: ...on of the current direction see also Sec tions 2 3 and 2 12 If the IEE2 input is used the protection device must be told the neutral transformer transformation ratio prim sec and the terminal of the earthing side CT to which the IEE2 input is connected see comments in Section 2 3 BLOCK REF 5803 2102 REF I BLOCK 2103 REF U0 RELEASE 5812 REF BLOCKED 5840 REF I blocked 5841 REF U0 releas 2110 I REF 2...

Page 120: ...l current With low ohmic starpoint earthing the formula is nom inal current earth current resulting from the starpoint resistance The zero voltage release depends on the operating range of the protection function 95 of a generator stator winding is a good value Therefore the secondary side val ue has been set to 5 0 V 2103 REF U0 RELEASE Where the zero voltage release is not used it must be set to...

Page 121: ...0 10 I InO I REF Pickup 2112 T I REF 0 00 60 00 sec 0 00 sec T I REF Time Delay 2113A SLOPE 0 00 0 95 0 25 Slope of Charac I REF f I0 Rest 2114A BASE POINT 0 00 2 00 I InO 0 00 I InO Base Point for Slope of Charac teristic F No Alarm Comments 05803 BLOCK REF BLOCK restricted earth fault prot 05811 REF OFF Restricted earth fault is switched OFF 05812 REF BLOCKED Restricted earth fault is BLOCKED 05...

Page 122: ...e is calculated from the positive sequence system of the currents and voltages In the admittance plane the stability limit of the machine is independent of the voltage thus the protection characteristic can be optimally matched to the stability characteristic of the machine By evaluating the positive sequence system underexcitation conditions are reliably detected even during asymmetrical faults w...

Page 123: ... e g by 10 s or a trip signal are transmitted The delay is necessary to ensure that the voltage regulator is given enough time to increase the excitation voltage Figure 2 52 Stator Criterion Pick Up Characteristic in Admittance Diagram A further characteristic 1 xd CHAR 3 α3 can be matched to the dynamic stability characteristic of the synchronous machine Since stable operation is impossible if th...

Page 124: ...ation voltage is signalled Low Pass Filter As the excitation DC voltage may contain a large amount of superimposed harmonics e g owing to thyristor control an analog low pass is provided on the C I O 6 board in addition to the integrated digital filter This low pass damps especially multiples of the sampling frequency which cannot be suppressed sufficiently by the digital filter The jumper setting...

Page 125: ...n ON or OFF or only block the trip command Block Relay The correct power system data is required according to section 2 3 This is a prerequisite for the setting of the underexcitation protection OR 3003 ANGLE 1 3002 1 xd CHAR 1 Char 1 BLK FNo 05329 3006 ANGLE 2 3005 1 xd CHAR 2 Char 2 BLK FNo 05330 3009 ANGLE 3 3008 1 xd CHAR 3 Char 3 BLK FNo 05327 3013 Uexcit Uexc fail FNo 05328 Exc BLOCK FNo 053...

Page 126: ...tics are set in such a way that the underexcitation limiting of the voltage regulator will intervene before characteristic 1 is reached see figure 2 56 Figure 2 54 Underexcitation Protection Characteristics in the Admittance Plane Characteristic Curve Values If the generator power diagram Figure 2 55 in its preferred representation abscissa positive reactive power ordinate positive active power is...

Page 127: ...d machine voltage UN VT prim Primary rated voltage of the voltage transformers IN CT prim Primary rated current of the current transformers Instead of 1 xd mach the approximate value IK0 IN can be used with IK0 short circuit current at no load excitation Setting example Machine UN mach 6 3 kV IN mach SN 3 UN 5270 kVA 3 6 3 kV 483 A xd mach 2 47 machine manufacturer s indication in Fig 2 55 Current...

Page 128: ...e xd and the transient reactance xd However it should be greater than 1 A value between 80 and 110 is usually selected for the corresponding ANGLE 3 which ensures that only a dynamic instability can lead to a pickup with characteristic 3 The associated time delay is set at address 3010 T CHAR 3 to the value suggested in Table 2 6 Figure 2 56 Admittance Diagram of a Turbo Generator Time Delays If t...

Page 129: ...citation voltage whereUExc No load excitation voltage kVD Transformation ratio of voltage divider Example UExc N 110 V UExc 0 40 V kVD 10 1 2 14 2 1 Settings of the Underexcitation Loss of Field Protection Table 2 6 Setting the Underexcitation Protection Characteristic 1 and 2 static stability not delayed Annunciation Err PU Characteristic 1 and 2 static stability long time delayed T CHAR 1 T CHAR...

Page 130: ... 3 00 1 10 Conductance Intersect Charac teristic 3 3009 ANGLE 3 50 120 90 Inclination Angle of Characteri stic 3 3010 T CHAR 3 0 00 60 00 sec 0 30 sec Characteristic 3 Time Delay F No Alarm Comments 05323 Exc BLOCK BLOCK underexcitation protection 05329 Char 1 BLK BLOCK underexc prot char 1 05330 Char 2 BLK BLOCK underexc prot char 2 05327 Char 3 BLK BLOCK underexc prot char 3 05328 Uexc fail Exc ...

Page 131: ...ponds to the actual load of the drive end The calculated active power value corresponds to the overall active power By taking the error angles of the instrument transformers into account the active power component is calculated even with very high apparent powers and low power factor cos ϕ The correction is performed by a W0 constant correction angle see section 2 3 determined during the commissio...

Page 132: ... is determined by the friction losses to be overcome and are situated in the following range depending on the individual system Steam turbines PReverse SN 1 to 3 Gas turbines PReverse SN 1 to 3 Diesel drives PReverse SN 5 The setting can be acquired through a primary test The reverse power should be measured with the relay Section 3 4 10 2 The user should select a setting of 0 5 times the value of...

Page 133: ...ions the reverse power protection performs a short time delayed trip subsequent to the emergency tripping via an oil pressure switch or a position switch at the emergency trip valve Before tripping it must be ensured that the reverse power is only caused by the missing drive power at the turbine side A time delay is necessary to bridge the active power swing in case of sudden valve closing until a...

Page 134: ...K reverse power protection 05086 SV tripped Stop valve tripped 05091 Pr OFF Reverse power prot is switched OFF 05092 Pr BLOCKED Reverse power protection is BLOCKED 05093 Pr ACTIVE Reverse power protection is ACTIVE 05096 Pr picked up Reverse power picked up 05097 Pr TRIP Reverse power TRIP 05098 Pr SV TRIP Reverse power TRIP with stop valve ...

Page 135: ... be decoupled when a fault in the utility network is not cleared within a critical time As a criterion for decoupling underfrequency undervoltage overcurrent power direction or combinations of these can be used As a result the 7UM62 can also be used for network decoupling 2 16 1 Functional Description Active Power Measuring For power measurement two measurement methods are available Depending on t...

Page 136: ...voltage transformers IN prim Primary rated current of current transformers Address 3202 serves to set the threshold of the forward power to an underrange Pf and address 3203 Pf serves to set it to overrange Addresses 3204 T Pf and 3205 T Pf serve to set the associated time delays In address 3206A MEAS METHOD the user can select whether a fast or a precise measuring procedure must be used for the f...

Page 137: ...K forw power superv Pf stage 05117 Pf BLOCK BLOCK forw power superv Pf stage 05121 Pf OFF Forward power supervis is switched OFF 05122 Pf BLOCKED Forward power supervision is BLOCKED 05123 Pf ACTIVE Forward power supervision is ACTIVE 05126 Pf picked up Forward power Pf stage picked up 05127 Pf picked up Forward power Pf stage picked up 05128 Pf TRIP Forward power Pf stage TRIP 05129 Pf TRIP Forwa...

Page 138: ...wing numeric filtering the currents in each phase are monitored in comparison with a set threshold value A pick up signal is generated for that those phase s in which the set threshold has been exceeded These pickup signals are considered for choosing the measured values The overcurrent fault detector is reset when 95 of the pick up value is fallen below unless it is maintained by the undervoltage...

Page 139: ...rocedure described in the lowest line of Table 2 7 is applied This loop selection type ensures that the fault impedance of system faults is measured correctly via the unit transformer A measuring error occurs with a 1 pole system short circuit as the zero phase sequence system is not transmitted via the machine transformer switching group e g Yd5 Table 2 8 describes the fault modeling and the meas...

Page 140: ...t Model on the Generator Side Loop selection Measuring Errors 3 pole short circuit 3 pole short circuit Phase earth Always correct measuring 2 pole short circuit 3 pole short circuit Phase earth loop with highest current Always correct measuring 1 pole short circuit 2 pole short circuit Phase phase loop Impedance measured too high by the zero impedance Z G ...

Page 141: ... identified by one parameter impedance Z As long as a fault detector has picked up the impedance calculation is effected continuously This is carried out by complex division of the voltage and current phases derived from the loop selection When the calculated fault impedance lies within the set trip characteristic the protection issues a trip command which may be delayed according to the time sett...

Page 142: ...power unit If a consideration of the circuit breaker auxiliary contact is possible a so called ZONE Z1B overreach zone can be switched effective see Figure 2 62 Figure 2 60 Tripping Characteristics of the Impedance Protection 2 17 1 4 Tripping Logic The T END time delay is started subsequent to the protection pickup The fault loop is determined now The loop impedance components are compared with t...

Page 143: ...NE Z2 S Q R Extens Z1B FNo 3956 Imp BLOCK FNo 3953 3309 T Z1B 3307 T Z1 3311 ZONE2 T2 S Q R S Q R TMin TRIP CMD Tripping matrix 3308 ZONE Z1B FNo 3978 Imp Z1B TRIP FNo 3979 Imp Z2 TRIP FNo 3977 Imp Z1 TRIP FNo 3970 Imp I U PU FNo 3969 Imp Fault L3 FNo 3968 Imp Fault L2 FNo 3967 Imp Fault L1 Loop selection Pickup Z IL1 IL2 IL3 U1 IL1 IL2 IL3 UL1 UL2 UL3 FNo 3962 Imp BLOCKED U I OR FNo 3958 Useal in...

Page 144: ...operation e g to U 75 to 80 of the nominal voltage The seal in time address 3305 T SEAL IN must exceed the maximum fault clearance time in a back up case recommended setting address 3312 T END 1 s Impedance Stages As illustrated in figure 2 60 the protection has the following characteristics which may be set independently 1st zone Z1 instantaneous zone with the setting parameters ZONE Z1 Reactance...

Page 145: ...age SN Rated transformer power MVA UN Machine side rated transformer voltage kV The values determined such must be converted for the secondary side of current and voltage transformers In general The nominal current of the protective relay secondary nominal current of the current transformer is automatically considered by the relay You have already communicated the transformation ratios of the curr...

Page 146: ...nce Protection Example Z1B Overreach Zone The Z1B overreach zone address 3308 ZONE Z1B is an externally controlled stage which does not influence the Z1 normal stage Consequently there is no changeover but the overreach zone is switched effective or ineffective depending on the position of the high voltage side circuit breaker Z1secondary 500 A 1 A 6 3 kV 100 V 0 3669 Ω 2 91 Ω Z1secondary 500 A 5 ...

Page 147: ... trip by the impedance protection possible Since a power swing happens much more slowly than a short circuit the rate of change of the impedance is a reliable criterion for its identification Because of its sym metrical nature the positive sequence impedance obtained from the positive se quence components of the currents and voltages is evaluated Logic Figure 2 63 shows the logic diagram of the po...

Page 148: ...agram for the Power Swing Blocking of the Impedance Protection 2 17 3 1 Setting Hints The power swing blocking is only effective if address 3313 POWER SWING has been set to ON A sensible compromise has to be found for the distance between the power swing polygon and the trip polygon parameter P SPOL TPOL address 3314 and for the rate of change parameter dZ dt address 3315 It must be kept in mind t...

Page 149: ... Figure 2 64 Evolution of the Rate of Change fp 1 Hz X 10 Ω For this reason the setting value dZ dt must also be coordinated with the impedance jump occurring at the start of a short circuit To do so you determine the minimum operating impedance ZL min form the differ ence to the setting of the impedance zone e g Z1 and calculate the impedance gra dient taking into account the one cycle measuring ...

Page 150: ...mpedance vector remains inside the trip polygon This time can only be reliably determined by transient calculations If the rate of change in the proximity of 180 is known it can be the basis for a rough estimation of the time T 2 Zcharacteristic dZ dt 180 The above data yield the following value Zcharacteristic Z1 4 Ω dZ dt 180 20 Ω s from Figure 2 64 T 2 4 Ω 20 Ω s 0 4 s This means that for delay...

Page 151: ... Impedance Zone Z1B 3309 T Z1B 0 00 60 00 sec 0 10 sec Impedance Zone Z1B Time Delay 3310 ZONE Z2 0 05 65 00 Ohm 4 16 Ohm Impedanz Zone Z2 3311 ZONE2 T2 0 00 60 00 sec 0 50 sec Impedance Zone Z2 Time Delay 3313 POWER SWING ON OFF OFF Power Swing Blocking 3314 P SPOL TPOL 0 10 30 00 Ohm 8 00 Ohm Distance betw Power Swing Trip Pol 3315 dZ dt 1 0 600 0 Ohm s 300 0 Ohm s Rate of Change of dZ dt 3316A ...

Page 152: ... phase L1 03968 Imp Fault L2 Imp Fault detection phase L2 03969 Imp Fault L3 Imp Fault detection phase L3 03977 Imp Z1 TRIP Imp Z1 TRIP 03978 Imp Z1B TRIP Imp Z1B TRIP 03979 Imp Z2 TRIP Imp Z2 TRIP 03980 Imp T3 TRIP Imp T3 TRIP 03976 Power Swing Power swing detection F No Alarm Comments ...

Page 153: ...he well proven impedance measurement The trajectory of the complex impedance vector is evaluated The impedance is calculated from the positive sequence components of the voltages and currents Trip decision is made dependent of the rate of change of the impedance vector and on the location of the electrical centre of the power swing The out of step condition is illustrated at a simplified equivalen...

Page 154: ...urement location voltage transformer set When the ratio of the voltage magnitudes UN UG is kept constant and the load angle δ varies then circles result as a locus diagram The centre and the radius of the circle are determined by the ratio UN UG The centre points are situated on a line which is determined by Ztot Minimum and maximum of the magnitude of the measured impedance are at load angles δ 0...

Page 155: ... e the non hatched area in Figure 2 67 covers the electrical centre being in the generator block until the unit transformer the hatched area characteristic 2 discriminates the electrical centre being in the network system The point of crossing of the symmetry axis is decisive for the assignment to the characteristic Power swings are three phase symmetrical occurrences The first prerequisite is the...

Page 156: ...ecognized i e when the impedance vector has passed through a power swing characteristic an annunciation is issued which also identifies the characteristic Additionally a counter n1 for characteristic 1 or n2 for characteristic 2 is incremented Out of step protection pick up is indicated when a counter is set to 1 Another out of step indication is given for an adjustable time period each time a cou...

Page 157: ...stic 1 Increment FNo 05069 O S det char 1 FNo 05071 O S TRIP char 1 3512 T SIGNAL FNo 05068 O S char 2 3511 T HOLDING n 0 n 1 n n 1 n n2 3510 REP CHAR 2 Reset Release Characteristic 2 Increment FNo 0507 O S det char 2 FNo 05072 O S TRIP char 2 BLOCK O S O S BLOCKED UL1 UL2 UL3 I2 IL1 IL2 IL3 I1 I1 I2 O S Out of step signal for the duration of T SIGNAL Ch 1 Characteristic 1 Ch 2 Characteristic 2 U1...

Page 158: ...ions of permissible overload should be ex cluded The setting should therefore be set above the maximum anticipated over load current at least 120 IN Depending on network conditions smaller pickup thresholds can be chosen so that the measurement see Figure 2 68 may be released all the time As out of step conditions are symmetrical occurrences the pickup threshold of the negative sequence component ...

Page 159: ...teristic 2 the remaining portion of the transformer impedance is set at 3507 Zd Zc if necessary complemented by the impedance of the additional line section to be monitored Table 2 11 shows typical values of the impedances of unit transformers XSC for secondary rated currents IN 1 A and IN 5 A the relationship of the values is according to the following equation Xd UN Gen 3 IN Gen xd üct üvt Table...

Page 160: ...gure 2 70 Power Swing Polygon and Impedance Vectors with Power Swing Angle δ Maximum Power Swing Frequency The polygon width Za determines also the maximum detectable power swing frequency The consideration that at maximum power swing frequency at least two impedance measurements must have been carried out within the power swing polygon leads to the following approximative formula for the maximum ...

Page 161: ...ing that the characteristic should cover 85 of the transformer reactance the setting of Zc results in 0 85 4 2 Ω 3 6 Ω Assuming that the remaining transformer reactance 0 15 4 2 Ω and the covered system reactance should be 10 Ω the setting of 3507 results in Zd Zc 6 4 Ω The width Za of the polygon is determined by the total impedance Ztot In this calculation example the total impedance Ztot is tha...

Page 162: ...est slip frequency Settings between 20 s and 30 s are good values Each time one of the counters n1 or n2 is incremented the holding time is restarted and an annunciation Out of step characteristic 1 or Out of step characteristic 2 is issued These annunciations disappear after the time which is set at address 3512 T SIGNAL If this time is set higher that the time between two power swings the annunc...

Page 163: ...ing Comments F No Alarm Comments 05053 BLOCK O S BLOCK out of step protection 05061 O S OFF Out of step protection is switched OFF 05062 O S BLOCKED Out of step protection is BLOCKED 05063 O S ACTIVE Out of step protection is ACTIVE 05067 O S char 1 Out of step pulse of characteristic 1 05068 O S char 2 Out of step pulse of characteristic 2 05069 O S det char 1 Out of step characteristic 1 picked ...

Page 164: ... up due to a secondary voltage failure each stage can be blocked individually or both stages can be blocked in common via binary input s e g by a voltage transformer miniature circuit breaker m c b In addition to this the integrated Fuse Failure Monitor blocks both stages see section 2 38 1 4 When the undervoltage protection has picked up while the relay changes to the operational condition 0 i e ...

Page 165: ... The user must select a value for the 4003 T U time setting that ensures that voltage dips affecting the operating stability are disconnected On the other hand the time delay must be long enough to avoid disconnection in case of permissible short time voltage dips For the second stage a lower pickup threshold 4004 U e g 65 V should be combined with a shorter trip time 4005 T U e g 0 5 s to perform...

Page 166: ...0 V 65 0 V U Pickup 4005 T U 0 00 60 00 sec 0 50 sec T U Time Delay 4006A U DOUT RATIO 1 01 1 20 1 05 U Drop Out Ratio F No Alarm Comments 06503 BLOCK U V BLOCK undervoltage protection 06506 BLOCK U BLOCK undervoltage protection U 06508 BLOCK U BLOCK undervoltage protection U 06530 Undervolt OFF Undervoltage protection switched OFF 06531 Undervolt BLK Undervoltage protection is BLOCKED 06532 Under...

Page 167: ... is performed with a longer time delay In this way the voltage regulator can take the voltage back into the nominal range The user can specify the voltage limit values and the time delays individually for both stages Each stage can be blocked individually and or both stages can be blocked in common via binary input s Figure 2 72 shows the logic diagram of the overvoltage protection Figure 2 72 Log...

Page 168: ...e increases first in relation to the transient voltage Only by this time the voltage regulator reduces it again to its nominal value The U stage is set as short time stage in a way that the transient procedure in case of a full load rejection does not lead to a tripping For example for 4104 U about 130 UN with a 4105 T U delay of zero to 0 5 s are typical values All setting times are additional ti...

Page 169: ...ge protection U 06565 Overvolt OFF Overvoltage protection switched OFF 06566 Overvolt BLK Overvoltage protection is BLOCKED 06567 Overvolt ACT Overvoltage protection is ACTIVE 06568 U picked up Overvoltage U picked up 06571 U picked up Overvoltage U picked up 06570 U TRIP Overvoltage U TRIP 06573 U TRIP Overvoltage U TRIP F No Alarm Comments ...

Page 170: ... functions within the system The parameterization determines the individual application purpose of the corresponding stage For the f4 frequency stage the user can specify independently of the parameterized limit value if this stage shall function as decrease or increase stage For this reason it can also be used for special applications if for example the user desires a signalization in case of a f...

Page 171: ...erfrequency protection Set the pickup threshold lower than nominal frequency if the element is to be used for underfrequency protection and higher than nominal frequency if it is to be used for overfrequency protection For the f4 frequency stage the previously explained circumstances are only relevant if the 4214 THRESHOLD f4 parameter is set to Automatic default setting If desired this parameter ...

Page 172: ... current input but also endangers stable operation For this reason only a short time frequency reduction down to about 48 Hz for fN 50 Hz or 58 Hz for fN 60 Hz is permissible A frequency increase can for example occur due to a load shedding or malfunction of the speed regulation e g in an island network In this way the frequency increase protection can for example be used as overspeed protection S...

Page 173: ... 65 00 Hz 59 50 Hz f3 Pickup 4210 T f3 0 00 100 00 sec 20 00 sec T f3 Time Delay 4211 f4 PICKUP 40 00 65 00 Hz 52 00 Hz f4 Pickup 4212 f4 PICKUP 40 00 65 00 Hz 62 00 Hz f4 Pickup 4213 T f4 0 00 100 00 sec 10 00 sec T f4 Time Delay 4214 THRESHOLD f4 Freq prot stage automatic Freq prot stage overfre qency Freq prot stage underfre qency Freq prot stage automatic Handling of Threshold Stage f4 4215 Um...

Page 174: ...al C53000 G1176 C149 3 05233 f2 picked up f2 picked up 05234 f3 picked up f3 picked up 05235 f4 picked up f4 picked up 05236 f1 TRIP f1 TRIP 05237 f2 TRIP f2 TRIP 05238 f3 TRIP f3 TRIP 05239 f4 TRIP f4 TRIP F No Alarm Comments ...

Page 175: ...ase to phase voltages The frequency range from 10 Hz to 70 Hz can be monitored in this way Transformer Adaptation A perhaps existing deviation between the primary nominal voltage of the voltage transformers and the object to be protected is compensated by means of the internal correction factor UN prim UN mach For this reason pick up values and characteristics do not need to be converted to second...

Page 176: ...lustrates the behaviour of the protection on the assumption that within the framework of configuration the setting for the pickup threshold parameter 4302 U f was chosen higher or lower than the first setting value of the thermal characteristic Figure 2 74 Tripping Time Characteristic of the Overexcitation Protection 1 0 1 10 1 20 1 30 1 40 T U f 1 05 t 1 05 T Pickup threshold U f parameter 4302 1...

Page 177: ...ation block is switched off at full load operation and the voltage regulator does not respond at all or does not respond fast enough to avoid the related voltage increase Similarly a decrease in frequency speed e g in island systems can endanger the transformer because of increased induction In this way the U f protection monitors the correct function both of the voltage regulators and of the spee...

Page 178: ...dard transformer was selected as a presetting for the parameters 4306 to 4313 If the manufacturer of the object to be protected did not include any instructions on this subject the preset standard characteristic should be used Otherwise any trip characteristic can be specified by point wise entering of parameters by maximally 7 straight lengths To do this the trip times of the overexcitation value...

Page 179: ...00 sec T U f Time Delay 4306 t U f 1 05 0 20000 sec 20000 sec U f 1 05 Time Delay 4307 t U f 1 10 0 20000 sec 6000 sec U f 1 10 Time Delay 4308 t U f 1 15 0 20000 sec 240 sec U f 1 15 Time Delay 4309 t U f 1 20 0 20000 sec 60 sec U f 1 20 Time Delay 4310 t U f 1 25 0 20000 sec 30 sec U f 1 25 Time Delay 4311 t U f 1 30 0 20000 sec 19 sec U f 1 30 Time Delay 4312 t U f 1 35 0 20000 sec 13 sec U f 1...

Page 180: ...f a voltage time integral action characteristic If a motor falls into the unstable area below the curve it will stall or run at substantially reduced speed even if full voltage is restored after a short time Only squirrel cage machines for which the torque characteristic of the driven machine lies below the motor characteristic at all speeds will regain their rated speed All other machines will be...

Page 181: ...ase quantities terminal voltage 3 For the pickup values no hard and fast rules can be laid down But since the protection is used mainly to protect consumers induction machines from the consequences of voltage drops and to prevent loss of stability the pickup value is normally set to approx 75 of the nominal machine voltage i e address 4402 Up PICKUP is set to 75 V In exceptional cases where the vo...

Page 182: ...UP 10 0 125 0 V 75 0 V Up Pickup 4403 T MUL 0 10 5 00 sec 0 1 00 sec Time Multiplier for Characteristic 4404 T Up 0 00 60 00 sec 0 00 sec T Up Time Delay F No Alarm Comments 06520 BLOCK Up BLOCK inverse undervoltage protection 06522 Up OFF Inv Undervoltage prot is switched OFF 06523 Up BLOCK Inv Undervoltage protection is BLOCKED 06524 Up ACTIVE Inv Undervoltage protection is ACTIVE 06525 Up picke...

Page 183: ...ecks for phase angle jumps etc help to avoid overfunctioning Frequency Increase Decrease The rate of frequency change protection has four stages from df1 dt to df4 dt This al lows to adapt the function variably to all power system conditions The stages can be set to detect either frequency decreases df dt or frequency increases df dt The df dt stage is only active for frequencies below the rated f...

Page 184: ... as an absolute value at address 4503 STAGE df1 dt The setting of address 4502 informs the protection function of the applicable sign The pickup value depends on the application and is determined by power system con ditions In most cases a network analysis will be necessary A sudden disconnection of loads leads to a surplus of active power The frequency rises and causes a positive frequency change...

Page 185: ...is will be the case with high setting values For the monitoring of small changes 1Hz s on the other hand a small delay time can be useful to avoid overfunctioning The delay time is set at address 4504 T df1 dt and the time set there is added to the protection operating time Release by the Frequency Protection The parameter df1 dt f1 address 4505 is used to set the release of the stage from a certa...

Page 186: ...ating Voltage Umin 4519A df1 2 HYSTERES 0 02 0 99 Hz s 0 10 Hz s Reset Hysteresis for df1 dt df2 dt 4520A df1 2 M WINDOW 1 25 Cycle 5 Cycle Measuring Window for df1 dt df2 dt 4521A df3 4 HYSTERES 0 02 0 99 Hz s 0 40 Hz s Reset Hysteresis for df3 dt df4 dt 4522A df3 4 M WINDOW 1 25 Cycle 5 Cycle Measuring Window for df3 dt df4 dt 4502 df1 dt df dt negative rate of freq change df dt positive rate of...

Page 187: ... 0 Hz s Pickup Value of df4 dt Stage 4516 T df4 dt 0 00 60 00 sec 0 00 sec Time Delay of df4 dt Stage 4517 df4 dt f4 OFF ON OFF AND logic with pickup of stage f4 F No Alarm Comments 05503 df dt block BLOCK Rate of frequency change prot 05504 df1 dt block BLOCK df1 dt stage 05505 df2 dt block BLOCK df2 dt stage 05506 df3 dt block BLOCK df3 dt stage 05507 df4 dt block BLOCK df4 dt stage 05511 df dt ...

Page 188: ...e voltage In case of a failure of the incoming feeder the abrupt current interruption causes a phase angle jump in the voltage This jump is detected by means of a delta process As soon as a preset threshold is exceeded an opening command for the generator or bustie coupler circuit breaker is issued This means that the vector jump function is mainly used for network decoupling Figure 2 79 shows the...

Page 189: ...ing a Load Shedding The function features a number of additional measures to avoid spurious tripping such as Correction of steady state deviations from rated frequency Frequency operating range limited to fN 3 Hz Detection of internal sampling frequency changeover Minimum voltage for release Blocking on voltage connection or disconnection Logic Figure 2 81 shows the logic diagram The phase angle c...

Page 190: ...causes the voltage to drop abruptly to a low value the reset input is immediately activated to block the function The vector jump function is thus prevented from causing a trip Figure 2 81 Logic Diagram of the Vector Jump Detection 2 25 2 Setting Hints General The vector jump function is only effective and accessible if address 0146 VECTOR JUMP has been set to Enabled during configuration Address ...

Page 191: ... indication with a delay to a logic CFC or to leave enough time for an external blocking to take effect After expiry of the timer T RESET address 4604 the protection function is automat ically reset The reset time depends on the decoupling philosophy It must have ex pired before the circuit breaker is reclosed Where the automatic reset function is not used the timer is set to The reset signal must...

Page 192: ...ts 05581 VEC JUMP block BLOCK Vector Jump 05582 VEC JUMP OFF Vector Jump is switched OFF 05583 VEC JMP BLOCKED Vector Jump is BLOCKED 05584 VEC JUMP ACTIVE Vector Jump is ACTIVE 05585 VEC JUMP Range Vector Jump not in measurement range 05586 VEC JUMP pickup Vector Jump picked up 05587 VEC JUMP TRIP Vector Jump TRIP ...

Page 193: ...splacement a voltage divider 500 V 100 V is to be connected in such cases If the displacement voltage can not be directly applied to the device the device calculates the displacement voltage from the phase to ground voltages Address 0223 UE CONNECTION serves for specifying the way the displacement voltage is to be measured or calculated In all kinds of displacement voltage formation the components...

Page 194: ...d between the machine and the network During a machine earth fault the earth fault current of the network is available However since the network conditions generally vary according to the switching status of the network a loading resistor which supplies an increased earth fault current on the occurrence of a displacement voltage is used in order to obtain definite measurement conditions independen...

Page 195: ...l border between machine direction and network direction can be altered in the 7UM62 refer to Figure 2 85 The protection feature detects a machine earth fault if all three of the following two criteria met Displacement voltage larger than set value U0 Earth fault current across the measurement location larger than set value 3I0 Earth fault current is flowing in the direction of the protected machi...

Page 196: ...IEE1 If the rotor earth fault protection see Section 2 30 is used it occupies the additional voltage input the displacement voltage U0 for the stator earth fault protection is therefore calculated from the phase earth voltages in that case Earth Fault Detection Earth Differential Protection with Tripping via Displacement Voltage In the industrial sector busbar systems are implemented with high or ...

Page 197: ...and the machine earth fault is only possible by way of the earth current If the 90 stator earth fault protection is used as earth differential protection address 0150 S E F PROT non dir U0 I0 is selected Set Disabled if the function is not required Address 5001 S E F PROT is used to switch the function ON or OFF or to block only the trip command Block Relay Displacement Voltage The criterion for t...

Page 198: ...he protected zone the earth current safely exceeds the setting Since the residual earth current in a compensated network is very small an earthing transformer with an ohmic loading resistor is normally provided to increase the residual wattmetric current in the event of an earth fault This arrangement also makes the protection independent of network conditions Instructions for the dimensioning of ...

Page 199: ...V this results in Setting value U0 10 V The time delay must lie below the 50 A capability time of the loading resistor i e below 20 s The overload capability of the earthing transformer must also be considered if it lies below that of the loading resistor 2 26 2 1 Settings of the 90 Stator Earth Fault Protection Voltage divider 500 V 100 V Toroidal c t 60 A 1 A Protected zone 90 500 V 10 Ω 50 A IE...

Page 200: ...5182 S E F BLOCKED Stator earth fault protection is BLOCK 05183 S E F ACTIVE Stator earth fault protection is ACTIVE 05189 Uearth L1 Earth fault in phase L1 05190 Uearth L2 Earth fault in phase L2 05191 Uearth L3 Earth fault in phase L3 05186 U0 picked up Stator earth fault U0 picked up 05188 3I0 picked up Stator earth fault I0 picked up 05187 U0 TRIP Stator earth fault U0 stage TRIP 05193 S E F T...

Page 201: ...ansformer Note The sensitive earth current protection as well as for the directional or non directional stator earth fault protection of busbar connected machines may use the same current measuring input IEE2 That means that both protection functions use identical input currents if address 0150 S E F PROT is set to directional or non dir U0 I0 Application as Rotor Earth Fault Protection Alternativ...

Page 202: ...rth protection 3PP13 from UPU 150 V resistors in the 7XR61 must be shorted Figure 2 89 Logic Diagram of the Sensitive Earth Fault Protection 7UM62 7XR61 UE UE IEE UV 3PP13 5102 IEE BLOCK Sens E FNo 01231 5104 IEE 5106 IEE FNo 01224 IEE picked up FNo 01221 IEE picked up FNo 01226 IEE TRIP FNo 01223 IEE TRIP 5103 T IEE 5105 T IEE FNo 01233 IEE BLOCKED FNo 05396 Fail REF Iee 2s Tripping matrix BLOCK ...

Page 203: ...ency bias voltage UV 42 V must be applied to the rotor circuit by means of the 7XR61 series device in Figure 2 88 In this case the measured current is determined by the magnitude of the bias voltage and the capacitance of the coupling capacitors of the rotor circuit which can be measured in order to ensure a closed measuring circuit address 5106 IEE Approximately 2 mA is a typical pickup value The...

Page 204: ...sitive Earth Fault Protection 2 27 2 2 Information for the Sensitive Earth Current Detection Addr Setting Title Setting Options Default Setting Comments 5101 O C PROT Iee OFF ON Block relay for trip com mands OFF Sensitive Earth Current Protec tion 5102 IEE 2 1000 mA 10 mA Iee Pickup 5103 T IEE 0 00 60 00 sec 5 00 sec T Iee Time delay 5104 IEE 2 1000 mA 23 mA Iee Pickup 5105 T IEE 0 00 60 00 sec 1...

Page 205: ...ls increases see figure 2 90 The 3rd harmonic forms a zero phase sequence system and can thus also be determined by means of the voltage transformer switched in star delta or by calculating the zero phase sequence system from the phase earth voltages Figure 2 90 Profile of the 3rd Harmonic along the Stator Winding Moreover the level of the 3rd harmonic depends on the operating point of the generat...

Page 206: ...Ue Connected to Neutral Transformer As an earth fault in the starpoint causes a reduction of the measured 3rd harmonic compared with the faulty case the protective function is implemented as undervoltage stage 5202 U0 3 HARM This arrangement is the preferred application Ue Connected to Broken Delta Winding If no neutral transformer exists the protective function is based on the zero component of t...

Page 207: ...age available to the protective relay as a measured quantity calculated quantities are used and the parameter must be set to not connected The option UE connected to any VT is selected if the 7UM62 voltage input shall be used for measuring any other voltage instead of using it for earth fault protection In this case the function 100 stator earth fault protection is blocked The option Ue connected ...

Page 208: ...e generator the working area of the 100 stator earth fault protection is only tripped above the active power threshold set via 5205 P min and on exceeding a minimum positive phase sequence voltage 5206 U1 min Recommended setting Pmin 40 P SN U1 min 80 UN Delay Time The tripping in case of an earth fault is delayed by the time set at address 5204 T SEF 3 HARM The set time is an additional time dela...

Page 209: ...00 Stator Earth Fault Protection with 3rd Harmonics F No Alarm Comments 05553 SEF 3H BLOCK BLOCK SEF with 3 Harmonic 05561 SEF 3H OFF SEF with 3 Harm is switched OFF 05562 SEF 3H BLOCK SEF with 3 Harm is BLOCKED 05563 SEF 3H ACTIVE SEF with 3 Harm is ACTIVE 05567 SEF 3H pick up SEF with 3 Harm picked up 05568 SEF 3H TRIP SEF with 3 Harm TRIP ...

Page 210: ...protection is therefore a basic function for large generators 2 29 1 Functional Description Basic Principle Figure 2 92 shows the basic protection principle An external low frequency alternat ing voltage source 20 Hz injects into the generator starpoint a voltage of max 1 of the rated generator voltage If an earth fault occurs in the generator starpoint the 20 Hz voltage drives a current through t...

Page 211: ...loading resistor The 20 Hz voltage is connected in this case via a voltage transformer and the starpoint current is directly measured The connection scheme and hints on circuit design can be found in the Appendix A 5 Figure A 43 Measuring Procedure From the two measured quantities USEF and ISEF in Figure 2 93 the 20 Hz current and voltage vectors are calculated and from the resulting complex imped...

Page 212: ...alarm stage and a trip stage Both stages can be de layed with a timer The earth current detection acts only on the trip stage The evalu ation of the earth resistance measurement is blocked between 10 Hz and 40 Hz be cause in this frequency range a zero voltage can also be generated by generators starting up or slowing down Such a zero voltage would then superimpose the con nected 20 Hz voltage cau...

Page 213: ...5301 100 SEF PROT is used to switch the function ON or OFF or to block only the trip command Block relay Fault Resistances The final setting values are determined in the primary test as described in Section 3 3 Please note that the protection calculates the earth resistance from the secondary val ues USEF and ISEF which are present at the device terminals The association between this calculated va...

Page 214: ...ge a primary resistance of 3 kΩ yields a setting value of R SEF ALARM 360 Ω Earth Current Stage The earth current stage has a backup protection function It is set to a protected zone of approx 80 Referenced to the maximum secondary fault current the pickup threshold is at approx 20 and the setting value is calculated as follows The delay time T SEF TRIP address 5305 which is also relevant for the ...

Page 215: ...nce by the zero voltage when the generator circuit breaker is open The 20 Hz source is connected via the neutral transformer in the generator starpoint With the generator circuit breaker closed the protection measures the load ing resistance on the unit transformer side which can be mistaken for an earth resis tance The advanced parameter address 5311A allows to set this additional loading resista...

Page 216: ...ure 20Hz bias voltage S E F 05481 SEF100 OFF S E F 100 protection is switched OFF 05482 SEF100 BLOCKED Stator earth flt prot 100 is BLOCKED 05483 SEF100 ACTIVE Stator earth flt prot 100 is ACTIVE 05486 Failure SEF Failure stator earth flt prot 100 05487 SEF100 Alarm Stator earth flt prot 100 Alarm stage 05488 SEF100 PICKUP Stator earth flt prot 100 picked up 05489 SEF100 TRIP Stator earth flt prot...

Page 217: ...rically coupled to the excitation circuit via the capacitors of the coupling unit and simultaneously connected to the measurement input of the 7UM62 The capacitors CK of the 7XR6100 coupling unit are protected by series resistors Rseries and in case high harmonics content is expected in the excitation circuit e g excitation by thyristor circuits by an additional filter choke for a connection examp...

Page 218: ... set value Note The rotor earth fault protection uses for the detection of the voltage URE the UE voltage input of the device Therefore the displacement voltage U0 for the 90 stator earth fault protection see Section 2 26 is in that case calculated from the phase to earth voltages Measuring Circuit Supervision Since a current flows even during healthy operation namely the capacitive charging curre...

Page 219: ...nsulation resistance Delays The time delay for the warning stage 6004 T WARN RE is usually set to approximately 10 s and the delay for the trip stage 6005 T TRIP RE to approximately 0 5 s The set times are additional time delays not including the operating times measuring time drop out time of the protective function Data for the Coupling to the Rotor Circuit The setting of the coupling reactance ...

Page 220: ...3 3 7 The values calculated and displayed by the relay may become negative due to CT angle errors wrong settings of the coupling impedance or malfunctions of the excitation equipment In that case a check is performed whether the current IRE is more than 7 mA in which case a tripping decision is made If the current is 7 mA the measurement is marked as invalid and the rotor earth resistance RRotor i...

Page 221: ... Ire Addr Setting Title Setting Options Default Setting Comments F No Alarm Comments 05383 BLOCK R E F BLOCK rotor earth fault prot R fn 05391 R E F OFF Rotor earth fault prot R fn swit OFF 05392 R E F BLOCKED Rotor earth fault prot R fn BLOCKED 05393 R E F AKTIVE Rotor earth fault prot R fn is ACTIVE 05394 R E F U block Rot earth flt prot R fn block by U 05397 R E F warning Rot earth flt prot R f...

Page 222: ...rough a resistor unit 7XR6004 or 7XR6003 and is symmetrically coupled to the excitation circuit via high resistance re sistors and at the same time connected to the earthing brush potential to earth via a low resistance measuring shunt RM see also Appendix Figure A 36 The voltage picked up at the measuring shunt and the control voltage are fed into the protection device via measuring transducers T...

Page 223: ...ent circuit which depends on the intensity of the excitation voltage and on the location of the earth fault in the excitation winding and the other are considerable high frequency voltage peaks that may superimpose the DC excitation voltage These peaks are damped by a numerical filter To eliminate the interference from the superimposed DC voltage component the po larity of the voltage Ug is revers...

Page 224: ...protection function offers an external test option using a test re sistor included in the 7XR6004 and 7XR6003 The test mode is activated via a binary input and the fault resistor is connected to a slip ring with an external relay The pro tection function must be informed of the pertinent test resistance The protection func tion issues appropriate indications showing the test results It is also abl...

Page 225: ...c Figure 2 100 shows the logic diagram It comprises the following elements Monitoring of the control unit 7XT71 Supervision of the measurement circuit Two stage protection function Effects of the rotor earth fault protection test If the earth resistance drops below the high resistance stage RE a warning message will normally be issued If it drops below the second low resistance stage RE a trip sig...

Page 226: ... 296 TRANSDUCER 2 4 20 mA 1 Edge detector òdt Qc RE 5401 Fail REF 1 3Hz 5403 REF 1 3Hz Warn T Interference 10 s T Edge 5 s OR Test mode REF 1 3Hz BLK 5381 Tripping matrix Tmin TRIP CMD 6106 Qc 6102 RE WARN 6103 RE TRIP 6104 T WARN RE 6105 T TRIP RE UMeas Ig UControl Ug Test REF 1 3Hz 5386 5395 REF 1 3Hz open 5407 REF 1 3Hz Trip 5406 REF 1 3Hz Fault 5388 REF 1 3Hz BLK ...

Page 227: ...d the coolant Care must be tak en to allow a sufficient margin between the setting value and the actual insulation re sistance As interference from the excitation system cannot be excluded the setting for the warning stage is not finally determined until the primary tests Time Delays The time delay for the warning stage 6102 T WARN RE is usually set to approxi mately 10 s and the delay for the tri...

Page 228: ...kup Value of open Rotor Cir cuit Qc 6107A TEST RESISTOR 1 0 10 0 kOhm 3 3 kOhm Testing Resistor F No Alarm Comments 05381 REF 1 3Hz BLK BLOCK rotor earth fault prot 1 3Hz 05386 Test REF 1 3Hz Test rotor earth fault prot 1 3Hz 05387 REF 1 3Hz OFF REF protection 1 3Hz is switched OFF 05388 REF 1 3Hz BLK REF protection 1 3Hz is BLOCKED 05389 REF 1 3Hz ACT REF protection 1 3Hz is ACTIVE 05395 REF 1 3H...

Page 229: ...d at address 6505 I MOTOR START This current releases the calculation of the tripping characteristic One characteristic is definite time while the other one is inverse time Inverse Time Overcurrent Tripping Characteristic The inverse time overcurrent characteristic is designed to operate only when the rotor is not blocked The inverse time characteristic allows motor starting time monitoring to adj...

Page 230: ...tarted and is a normal operating condition that is neither entered in the operational annunciations buffer nor output to the control center nor causes the creation of a fault record The locked rotor delay time LOCK ROTOR TIME is ANDed with the binary input Rotor locked If the binary input is still high after the locked rotor time has elapsed tripping is performed immediately regardless of whether ...

Page 231: ...d A current above the threshold I MOTOR START address 6505 is interpreted as a motor startup Consequently this value must be chosen such that it is reliably attained by the actual starting current under any load or voltage conditions during motor startup but not during a permissible short time overload Example Motor with the following data The setting for address START CURRENT is calculated as fol...

Page 232: ...e multiplied by 5 Consider the current transformer ratios when setting the device with primary values 2 32 2 2 Information for the Motor Starting Time Supervision TTrip IStartCurr I è ø æ ö 2 TStartmax TTrip 624 A 0 8 624 A è ø æ ö 2 8 5 s 13 3 s Addr Setting Title Setting Options Default Setting Comments 6501 STARTUP MOTOR OFF ON Block relay for trip com mands OFF Motor Starting Time Supervision ...

Page 233: ...ot be measured directly the stator current must be used to generate a thermal profile of the rotor The r m s values of the currents are generated for this The excessive rotor temperature ΘR is calculated using the highest of the three phase currents The thermal limit values for the rotor winding are based on manufacturer s data regarding the nominal starting current maximum permissible starting ti...

Page 234: ...n the protection as follows After each motor shutdown a temperature equilibrium time address 6604 T EQUAL is started which takes into account the different temperatures of different motor parts at the moment of shutdown During the rotor temperature equilibrium time the thermal profile is not updated but kept constant to model the equilibrium taking place in the rotor After that the thermal profile...

Page 235: ... is longer Behaviour in Case of a Power Supply Failure Depending on the setting of parameter 0274A ATEX100 the value of the thermal profile is either reset on a failure of the power supply voltage or cyclically buffered in a non volatile memory until the power supply voltage returns In the second case the thermal replica uses the last buffered value for calculation and matches it to the operating ...

Page 236: ...hib Re Inhibit ACT Emer Start QR ON OFF 1 I kτat Stop x τ IL1 IL2 IL3 BLK Re Inhib Imax ΘL 0 S Q R T 0 ΘL t Calculator Re Inhib TRIP Re Inhibit OFF Re Inhibit BLK OR kτat Running x τ Block relay Re Inhib ALARM RM th rep QR S Q R T 0 Tripping matrix WES RS th Abb 6609 Kt at RUNNING 6608 Kt at STOP 6604 T EQUAL 0281 BkrClosed I MIN 6602 IStart IMOTnom 6603 T START MAX 6606 MAX WARM STARTS 6607 COLD ...

Page 237: ...ced cooling at motor stop can be accounted for by entering at address 6608 the reduced ventilation expressed by the factor Kt at STOP As soon as the current no longer exceeds the current flow monitoring setting entered at address 0281 BkrClosed I MIN a motor standstill is assumed and the time constant is increased by the set factor If no difference between the time constants is to be used e g exte...

Page 238: ...lt settings is given in the tables at the end of this section and in the Appendix Temperature Behaviour during Changing Operating States For better understanding of the above considerations two of the many possible operating states will be discussed in the following paragraph The examples use the settings indicated above 3 cold and 2 warm startup attempts have resulted in a restart limit of 66 7 F...

Page 239: ... effective The fact that the restarting limit is exceeded for a short time does not mean a thermal overload It rather signals that a thermal overload of the rotor would arise if the motor were shut down immediately and restarted Figure 2 107 Two Warm Restart Followed by Continuous Running 2 33 2 1 Settings of the Restart Inhibit for Motors 0 0 2 200 0 4 0 6 0 8 1 0 400 800 600 1000 t s p u Tempera...

Page 240: ...rm Comments 04822 BLK Re Inhib BLOCK Restart inhibit motor 04828 RM th rep ΘR Reset thermal memory rotor 04823 Emer Start ΘR Emergency start rotor 04824 Re Inhibit OFF Restart inhibit motor is switched OFF 04825 Re Inhibit BLK Restart inhibit motor is BLOCKED 04826 Re Inhibit ACT Restart inhibit motor is ACTIVE 04829 RM th rep ΘR Reset thermal memory rotor 04827 Re Inhib TRIP Restart inhibit motor...

Page 241: ...rrent criterion is perhaps not expressive e g frequency protection voltage protection rotor earth fault protection If the circuit breaker has not opened after a programmable time delay breaker failure a higher level circuit breaker can initiate the disconnection refer to Figure 2 108 as an example Figure 2 108 Functional Principle of the Breaker Failure Protection Function Initiation The breaker f...

Page 242: ...her enhance the security against unwanted operation This means that no initiation is possible unless both binary inputs are activated The two channel feature is also effective for an internal initiation Logic If the breaker failure protection has picked up a corresponding message is transmitted and a parameterized time delay starts If the pickup criteria are still fulfilled on expiration of this t...

Page 243: ...lemented by reading the switching statuses of the corresponding output relays BO12 7002 TRIP INTERN BO12 or by a logic link created in CFC CFC annunciation 1442 int start B F The internal source can be completely deactivated 7002 TRIP INTERN OFF In this case the breaker failure protection can only be initiated by external sources via binary input Note Be aware that only the potential free binary o...

Page 244: ... a typical breaker failure scenario Figure 2 110 Timing for a Typical Breaker Failure Scenario 2 34 2 1 Settings for Breaker Failure Protection The following list indicates the setting ranges and the default settings of a IN 1 A secondary nominal current For a secondary nominal current of IN 5 A these values must be multiplied by 5 Consider the current transformer ratios when setting the device wi...

Page 245: ...start 1 breaker failure prot 01441 ext start2 B F ext start 2 breaker failure prot 01442 int start B F int start breaker failure prot 01451 BkrFail OFF Breaker failure is switched OFF 01452 BkrFail BLOCK Breaker failure is BLOCKED 01453 BkrFail ACTIVE Breaker failure is ACTIVE 01443 int start B F Breaker fail started intern 01444 B F I Breaker failure I 01455 B F picked up Breaker failure protecti...

Page 246: ...at it picks up during normal operation This blocking is delayed to avoid that the protection is blocked immediately by the time of an unwanted connection Another pickup delay is necessary to avoid an unwanted operation in case of high current faults with a heavy voltage dip A dropout time delay allows for a measuring limited in time As the inadvertent energizing protection must intervene very quic...

Page 247: ...d yet The parameter 7103 RELEASE U1 serves to define these nominal conditions The typical setting is about 50 to 70 of the nominal voltage A 0 V setting deactivates the voltage tripping However this should only be used if 7102 I STAGE shall be used as 3rd time overcurrent protection stage at a very high setting The parameter 7104 PICK UP T U1 parameter represents the time delay for the release of ...

Page 248: ...ertent Energizing Function Trip IL Release of U1 Machine stopped Inadvertent energization T U1 Dropout T U1 Pickup a Trip after inadvertent energization b Unit connection Machine running Short circ close to gen Trip Start T U1 Pickup INADV EN short circuit protection Addr Setting Title Setting Options Default Setting Comments 7101 INADVERT EN OFF ON Block relay for trip com mands OFF Inadvertent E...

Page 249: ... 7UM62 Manual C53000 G1176 C149 3 05543 I En ACTIVE Inadvert Energ prot is ACTIVE 05546 I En release Release of the current stage 05547 I En picked up Inadvert Energ prot picked up 05548 I En TRIP Inadvert Energ prot TRIP F No Alarm Comments ...

Page 250: ...sured AC quantities are present operating condition 0 the DC voltage protection is still operative The mean value is then calculated over 4 x 32 measured value samples If in special cases an AC voltage should be measured via this analog input the RMS value should be set on the protection The factor 1 11 between r m s and mean value is recognized within the protection function Optionally this funct...

Page 251: ...d into a voltage in a shunt and fed via a shunt converter to the measuring transducer of the device Shunt converters can be measuring transducers such as the 7KG6131 For short distances between the shunt converter and the protective device a voltage input may be used For longer distances use the version with current input 20 to 20 mA or 4 to 20 mA Figure 2 114 DC Voltage Protection Used to Detect ...

Page 252: ...n ON or OFF or to block only the trip command Block Relay Measuring Procedure Normally an integrated average value filter is switched on A high ripple content or non periodic peaks in the measurement voltage are averaged in this manner The polarity of the measured voltages is of no concern since the absolute value is taken Alternatively a sinusoidal AC voltage can be measured address 7202 MEAS MET...

Page 253: ...ormally between about 3 and 4 A For a startup converter having a startup transformer with UN AT 1 4 kV and a 6 pulse bridge circuit there will be a DC voltage of UDC 1 35 UN AT 1 89 kV In case of an earth fault in the intermediate circuit the displacement voltage will be half of the DC voltage UDC fault 0 5 UDC 945 V If we assume that the earthing transformer has an ohmic winding resistance of R 1...

Page 254: ...DC Voltage Current Stage DC DC Voltage Current Stage DC DC Voltage Cur rent Stage DC Method of Operation DC 7204 U DC 0 1 8 5 V 2 0 V DC Voltage Pickup 7205 I DC 0 2 17 0 mA 4 0 mA DC Current Pickup 7206 T DC 0 00 60 00 sec 2 00 sec Time Delay for Trip of DC Pro tection F No Alarm Comments 05293 BLOCK DC Prot BLOCK DC protection 05301 DC Prot OFF DC protection is switched OFF 05302 DC Prot BLOCKED...

Page 255: ...tor in percent referred to 1 00 Measured value rotor temperature ΘR ΘR max in percent of the maximum permissible rotor temperature Measured value stator temperature ΘS ΘS TRIP in percent of the tripping temperature Operating nominal quantities are the nominal values set at addresses 0251 UN GEN MOTOR and 0252 SN GEN MOTOR see also Section 2 3 For measured values that can be negative power power fa...

Page 256: ... is 22 0 mA in case of an overflow value outside the maximum permissible range 22 5 mA is output Example You want to output the positive sequence currents at analog output B1 location B 10 mA are the value at nominal operational current consequently 20 mA mean 200 Values below 1 mA are invalid Settings Address 7301 20 mA B1 200 0 Address 7302 MIN VALUE B1 1 0 mA 2 37 3 Settings of the Analog Outpu...

Page 257: ...e of the AD analog digital converter The protection is suspended if the voltages deviate outside an allowable range and lengthy deviations are reported Error A D conv Buffer Battery The buffer battery which ensures the operation of the internal clock and the storage of counters and messages if the auxiliary voltage fails is periodically checked for charge status If it is less than an allowed minim...

Page 258: ... the side for which the starpoint has been configured as Isolated in the power system data addresses 0242 0244 Figure 2 116 Current Sum Monitoring Measured Value Acquisition Voltages In the voltage path there are four input transformers If three of them are used for phase earth voltages and one input for the displacement voltage e n voltage from the broken delta winding or neutral transformer of t...

Page 259: ...rom service and the red Error LED lights up The readiness relay opens and indicates device malfunction with its normal contact 2 38 1 3 Monitoring of External Current Transformer Circuits Interruptions or short circuits in the secondary circuits of the current transformers or voltage transformers as well as faults in the connections important for start up are detected and reported by the device Th...

Page 260: ...re 2 118 Current Symmetry Monitoring Voltage Symmetry During normal system operation i e the absence of a short circuit fault symmetry among the input voltages is expected From the phase to ground voltages the protection generates the rectified average values and checks the symmetry of their absolute values The smallest phase voltage is related to the highest Asymmetry is recognized if Umin Umax B...

Page 261: ...IN For counter clockwise phase sequence the annunciations Fail Ph Seq U FNo 176 or FailPh Seq I S1 FNo 00265 are output for side 1 or FailPh Seq I S2 FNo 00266 for side 2 as well as an OR link for these annunciations Fail Ph Seq FN 00171 For applications where the phase rotation of the measured quantities is counter clockwise phase in normal operation this must be set in the device with the parame...

Page 262: ... too small positive sequence system an unwanted operation by inaccuracies of the measuring voltages failure detection the function is blocked below a minimum threshold of the positive sequence systems of U1 10 V and current I1 0 1 IN 3 Pole Fuse Failure A 3 pole voltage transformer failure cannot be detected via the positive and negative phase sequence system but requires a monitoring of the curre...

Page 263: ...device is taken out of service as well The live status contact operates to indicate the device is malfunctioning Also the red LED ERROR lights up on the front cover if the internal auxiliary voltage is present and the green RUN LED goes out If the internal power supply fails then all LEDs are dark Table 2 13 shows a summary of the monitoring functions and the malfunction responses of the relay FFM...

Page 264: ... out of service Annunciation ERROR LED Err1A 5AwrongS1 FNo 000210 DOK2 drops out 1 A 5 A changeover Side 2 Jumper for 1 A 5 A for side 2 misconnected Relay goes out of service Annunciation ERROR LED Err1A 5AwrongS2 FNo 000211 DOK2 drops out Voltage current changeover at TD1 Jumper setting for meas uring transducer 1 does not match parameter 0295 Relay goes out of service Annunciation ERROR LED Err...

Page 265: ...ummation current monitoring picks up see Figure 2 116 absolute component only referred to IN Consequently address 8112 SI THRESHOLD S2 is valid for side 2 The relative component referred to the maximum phase current for the pickup of the summation current monitoring Figure 2 116 is set for side 1 at address 8111 SI FACTOR S1 and for side 2 at 8113 SI FACTOR S2 Current symmetry Side 2 External powe...

Page 266: ...2 38 2 1 Settings The following list indicates the setting ranges and the default settings of a IN 1 A secondary nominal current For a secondary nominal current of IN 5 A these values must be multiplied by 5 Consider the current transformer ratios when setting the device with primary values Note In the power system data 1 the voltage earth path and its matching factor Uph Udelta have been specifie...

Page 267: ... Fail Current symm supervision side 2 00164 Fail U Superv Failure General Voltage Supervision 00165 Fail Σ U Ph E Failure Voltage Summation Phase Earth 00167 Fail U balance Failure Voltage Balance 00171 Fail Ph Seq Failure Phase Sequence 00265 FailPh Seq I S1 Failure Phase Sequence I side 1 00266 FailPh Seq I S2 Failure Phase Sequence I side 2 00176 Fail Ph Seq U Failure Phase Sequence Voltage 001...

Page 268: ...ent Alarm Summary Event 00193 Alarm NO calibr Alarm NO calibration data available 00147 Error PwrSupply Error Power Supply 00177 Fail Battery Failure Battery empty 00068 Clock SyncError Clock Synchronization Error F No Alarm Comments Table 2 14 Sum Events Sum events Content FNo Designation FNo Designation FNo Meaning 0160 Error sum event minor malfunction or configuration error does not affect the...

Page 269: ...ights up all protective functions blocked 0210 0211 0194 0212 0213 0214 0190 0185 0187 0188 Err1A 5AwrongS1 Err1A 5AwrongS2 Error neutralCT Err TD1 Jumper Err TD2 Jumper Err TD3 Jumper Error BG0 C CPU 2 Error BG3 C I O 2 Error BG5 C I O 6 Error BG6 C I O 1 0191 Error Offset 0264 Error Thermobox 1 0267 Error Thermobox 2 Table 2 14 Sum Events Sum events Content FNo Designation FNo Designation FNo Me...

Page 270: ...rol voltage of over 38 V Figure 2 121 Principle of Trip Circuit Monitor with Two Binary Inputs not Connected to Common Potential Monitoring with binary inputs not only detects interruptions in the trip circuit and loss of control voltage it also monitors the response of the circuit breaker using the position of the circuit breaker auxiliary contacts Depending on the conditions of the trip contact ...

Page 271: ...B auxiliary contact 1 Figure 2 123 Principle of Trip Circuit Monitor with two Binary Inputs Connected to Common Potential Table 2 15 Condition Table for Binary Inputs depending on RTC and CB Position No Trip Contact Circuit Breaker AuxCont 1 AuxCont 2 BI 1 BI 2 1 Open CLOSED Closed Open H L 2 Open OPEN Open Closed H H 3 Closed CLOSED Closed Open L L 4 Closed OPEN Open Closed L H TripC trip rel Tri...

Page 272: ...mality after 1 8 s an annunciation is reported see Figure 2 122 The repeated measurements help to determine the delay of the alarm message and to avoid that an alarm is output during short time transition phases When the fault in the trip circuit has been cleared the annunciation is automatically reset Monitoring with One Binary Input The binary input is connected according to Figure 2 124 in para...

Page 273: ...hecked 500 times before an annunciation is sent A condition check takes place about every 600 ms so trip circuit monitoring is only activated during an actual malfunction of the trip circuit after 300 s When the fault in the trip circuit has been cleared the annunciation is automatically reset Figure 2 125 Logic Diagram for Trip Circuit Monitoring with One Binary Input Figure 2 126 shows the logic...

Page 274: ...trip signal has elapsed and generates an alarm only if there is a real malfunction in the trip circuit Monitoring with One Binary Input Note When using only one binary input BI for the trip circuit monitor some malfunctions such as interruption of the trip circuit or loss of battery voltage can indeed be detected but malfunctions with closed trip contacts cannot Therefore the measurement must take...

Page 275: ...lt of the calculation is Rmax Rmin the calculation must be repeated with the next lowest pickup threshold UBI min for this threshold one or more jumpers must be set in the device see Section 3 1 3 For the power consumption of the resistance Example IBI HIGH Constant current with BI on 1 8 mA UBI min Minimum Control Voltage for BI 19 V for delivery setting for nominal voltage of 24 48 60 V 88 V for...

Page 276: ...ing Title Setting Options Default Setting Comments 8201 TRIP Cir SUP OFF ON OFF TRIP Circuit Supervision F No Alarm Comments 06851 BLOCK TripC BLOCK Trip circuit supervision 06853 TripC brk rel Trip circuit supervision breaker relay 06852 TripC trip rel Trip circuit supervision trip relay 06861 TripC OFF Trip circuit supervision OFF 06862 TripC BLOCKED Trip circuit supervision is BLOCKED 06863 Tri...

Page 277: ...d values The threshold values are que ried once per cycle Table 2 17 Measured Values Measured Value Scaling Comments P Active power P SN sec 100 normalized with addr 252 The positive sequence system quantities for U and I are formed once per cycle from the sampled values From the result P is calculated The measuring result is subject to the angle correction address 204 CT ANGLE W0 in the current p...

Page 278: ...rom the phase currents on the basis of the definition equation for symmetrical components The calculation is perfomed once per cycle I2 Negative sequence current system side 2 I2 IN S2 sec 100 The negative sequence current is determined from the phase currents on the basis of the definition equation for symmetrical components The calculation is perfomed once per cycle ϕ Power angle ϕ 180 100 The p...

Page 279: ...stage 2 40 2 Setting Hints General The threshold supervision function is only effective and accessible if address 185 THRESHOLD has been set to Enabled during the configuration of the protection func tions Pickup Values The pickup values are set as percentages Please note the scaling factors listed in Ta ble 2 17 8502 THRESHOLD MV1 8512 THRESHOLD MV6 7960 Meas Value1 7965 Meas Value6 PHI Disabled ...

Page 280: ...r Processing of Indications The indications of the 6 measured value monitoring blocks see list of information are available in the configuration matrix for further logical processing by the CFC see System Manual Chapter 5 2 40 2 1 Settings of the Threshold Supervision Note The measured values U1 U2 I0 I1 and I2 are always greater than 0 Care should be taken here to use only positive threshold valu...

Page 281: ...Power Delta P Positive Sequence Voltage U1 Negative Sequence Voltage U2 Zero Sequence Current I0 Positive Sequence Current I1 Negative Sequence Current I2 Power Angle PHI Disabled Measured Value for Threshold MV3 8506 THRESHOLDMV3 200 200 100 Pickup Value of Measured Value MV3 8507 MEAS VALUE 4 Disabled Active Power P Reactive Power Q Change of Active Power Delta P Positive Sequence Voltage U1 Neg...

Page 282: ...ve Power P Reactive Power Q Change of Active Power Delta P Positive Sequence Voltage U1 Negative Sequence Voltage U2 Zero Sequence Current I0 Positive Sequence Current I1 Negative Sequence Current I2 Power Angle PHI Disabled Measured Value for Threshold MV6 8512 THRESHOLDMV6 200 200 100 Pickup Value of Measured Value MV6 F No Alarm Comments 07960 Meas Value1 Measured Value MV1 picked up 07961 Meas...

Page 283: ...f one external trip command channel is illustrated in Figure 2 128 In total the relay incorporates four such channels i e four times this logic The illustrated function numbers are valid for the first external trip command channel Figure 2 128 Logic Diagram of One External Trip Command Channel 2 41 2 Setting Hints General External trip commands via binary inputs are only effective and accessible i...

Page 284: ...p com mands OFF External Trip Function 4 8902 T DELAY 0 00 60 00 sec 1 00 sec Ext Trip 4 Time Delay F No Alarm Comments 04523 BLOCK Ext 1 Block external trip 1 04526 Ext trip 1 Trigger external trip 1 04531 Ext 1 OFF External trip 1 is switched OFF 04532 Ext 1 BLOCKED External trip 1 is BLOCKED 04533 Ext 1 ACTIVE External trip 1 is ACTIVE 04536 Ext 1 picked up External trip 1 General picked up 045...

Page 285: ...ternal trip 3 General picked up 04577 Ext 3 Gen TRP External trip 3 General TRIP 04583 BLOCK Ext 4 BLOCK external trip 4 04586 Ext trip 4 Trigger external trip 4 04591 Ext 4 OFF External trip 4 is switched OFF 04592 Ext 4 BLOCKED External trip 4 is BLOCKED 04593 Ext 4 ACTIVE External trip 4 is ACTIVE 04596 Ext 4 picked up External trip 4 General picked up 04597 Ext 4 Gen TRP External trip 4 Genera...

Page 286: ...e of each measuring point from the resistance value of the temperature detectors connected with a two or three wire line Pt100 Ni100 or Ni120 and converts it to a digital value The digital values are output at a serial interface Communication with the Protection Device The protection device can communicate with up to 2 thermoboxes via its service port port C or D Up to 12 temperature measuring poi...

Page 287: ...nit C or F has been set in Power System Data 1 at ad dress 0276 TEMP UNIT Settings on the Protection Device The settings to be made on the protection device are the same for each input they are described here as an example for measuring input 1 For RTD1 temperature detector for measuring 1 the type of temperature detector is set at address 9011A RTD 1 TYPE Setting options are Pt 100 W Ni 120 W and...

Page 288: ...e 6 in the thermobox and enter the resistance value for the desired detector range 0 to 50 6 Ω For temperature detectors with a 3 wire line no extra settings are required The information is exchanged with a baud rate of 9600 bits s The parity is even The bus number is set to 0 in the factory Changes can be made in mode 7 on the ther mobox The following convention applies More information can be fo...

Page 289: ... 482 F 248 F RTD 1 Temperature Stage 2 Pickup 9021A RTD 2 TYPE not connected Pt 100 Ohm Ni 120 Ohm Ni 100 Ohm not connected RTD 2 Type 9022A RTD 2 LOCATION Oil Ambient Winding Bearing Other Other RTD 2 Location 9023 RTD 2 STAGE 1 50 250 C 100 C RTD 2 Temperature Stage 1 Pickup 9024 RTD 2 STAGE 1 58 482 F 212 F RTD 2 Temperature Stage 1 Pickup 9025 RTD 2 STAGE 2 50 250 C 120 C RTD 2 Temperature Sta...

Page 290: ...ge 2 Pickup 9046 RTD 4 STAGE 2 58 482 F 248 F RTD 4 Temperature Stage 2 Pickup 9051A RTD 5 TYPE not connected Pt 100 Ohm Ni 120 Ohm Ni 100 Ohm not connected RTD 5 Type 9052A RTD 5 LOCATION Oil Ambient Winding Bearing Other Other RTD 5 Location 9053 RTD 5 STAGE 1 50 250 C 100 C RTD 5 Temperature Stage 1 Pickup 9054 RTD 5 STAGE 1 58 482 F 212 F RTD 5 Temperature Stage 1 Pickup 9055 RTD 5 STAGE 2 50 ...

Page 291: ...4 RTD 7 STAGE 1 58 482 F 212 F RTD 7 Temperature Stage 1 Pickup 9075 RTD 7 STAGE 2 50 250 C 120 C RTD 7 Temperature Stage 2 Pickup 9076 RTD 7 STAGE 2 58 482 F 248 F RTD 7 Temperature Stage 2 Pickup 9081A RTD 8 TYPE not connected Pt 100 Ohm Ni 120 Ohm Ni 100 Ohm not connected RTD 8 Type 9082A RTD 8 LOCATION Oil Ambient Winding Bearing Other Other RTD 8 Location 9083 RTD 8 STAGE 1 50 250 C 100 C RTD...

Page 292: ...103 RTD10 STAGE 1 50 250 C 100 C RTD10 Temperature Stage 1 Pickup 9104 RTD10 STAGE 1 58 482 F 212 F RTD10 Temperature Stage 1 Pickup 9105 RTD10 STAGE 2 50 250 C 120 C RTD10 Temperature Stage 2 Pickup 9106 RTD10 STAGE 2 58 482 F 248 F RTD10 Temperature Stage 2 Pickup 9111A RTD11 TYPE not connected Pt 100 Ohm Ni 120 Ohm Ni 100 Ohm not connected RTD11 Type 9112A RTD11 LOCATION Oil Ambient Winding Bea...

Page 293: ...TD 1 Temperature stage 2 picked up 14121 Fail RTD 2 Fail RTD 2 broken wire shorted 14122 RTD 2 St 1 p up RTD 2 Temperature stage 1 picked up 14123 RTD 2 St 2 p up RTD 2 Temperature stage 2 picked up 14131 Fail RTD 3 Fail RTD 3 broken wire shorted 14132 RTD 3 St 1 p up RTD 3 Temperature stage 1 picked up 14133 RTD 3 St 2 p up RTD 3 Temperature stage 2 picked up 14141 Fail RTD 4 Fail RTD 4 broken wi...

Page 294: ... 9 Temperature stage 1 picked up 14193 RTD 9 St 2 p up RTD 9 Temperature stage 2 picked up 14201 Fail RTD10 Fail RTD10 broken wire shorted 14202 RTD10 St 1 p up RTD10 Temperature stage 1 picked up 14203 RTD10 St 2 p up RTD10 Temperature stage 2 picked up 14211 Fail RTD11 Fail RTD11 broken wire shorted 14212 RTD11 St 1 p up RTD11 Temperature stage 1 picked up 14213 RTD11 St 2 p up RTD11 Temperature...

Page 295: ... system data at address 0271 PHASE SEQ The binary input Reverse Rot sets the phase rotation for the opposite of the setting see figure 2 130 Figure 2 130 Message Logic of the Phase Sequence Reversal For safety reasons the device accepts the phase rotation reversal only by a time when no usable measured quantities exist The binary input is only inquired if operational condition 1 is not present If ...

Page 296: ...rating measurement values are not falsified As stated before this function influences the unbalance load protection function directional overcurrent protection function and some of the monitoring functions see Subsection 2 38 1 3 that issue messages if the required and calculated phase rotations do not match 2 43 2 Setting Hint The normal phase sequence has been set at the address 0271 see Section...

Page 297: ... fault messages are entered in the trip log Initialization of Oscillographic Records The storage and maintenance of oscillographic values can also be made dependent on the general device pickup Generation of Spontaneous Messages Certain fault messages are displayed in the device display as so called spontaneous messages see below Spontaneous Messages These display messages can also be made depende...

Page 298: ...ated after all protection Functions drop out AND the minimum trip signal duration expires Finally it is possible to latch the trip signal until it is manually reset lockout function This allows to lock the circuit breaker against reclosing until the cause of the malfunction has been clarified and the lockout has been manually reset The reset takes place either by pressing the LED reset key or by a...

Page 299: ...no tripping decide whether the new fault remains stored or is reset Figure 2 132 Creation of the reset command for the memory of the LED and LCD messages 2 44 3 2 Settings Pickup of a new protective function generally turns off any previously set light displays so that only the latest fault is displayed at any time It can be selected whether the stored LED displays and the spontaneous messages on ...

Page 300: ...hases in kA individually for side 1 and side 2 if tripping has been initiated by the differential protection the differential and restraint currents of all three phases are indicated the three phase earth voltages in kV primary active power P in kW MW or GW precisely averaged power primary reactive power Q in kVA MVA or GVA precisely averaged power frequency in Hz Operating Hours The operating hou...

Page 301: ...est mode Test mode 00016 DataStop Stop data transmission DataStop Stop data transmission UnlockDT Unlock data transmission via BI Light on Back Light on 00051 Device OK Device is Operational and Protecting 00052 ProtActive At Least 1 Protection Funct is Active 00055 Reset Device Reset Device 1 00056 Initial Start Initial Start of Device 2 00067 Resume Resume 3 00069 DayLightSavTime Daylight Saving...

Page 302: ...y voltage Please observe the following If necessary clear stored indications by pressing the LED Reset key Remotely using a binary input Using one of the serial interfaces Automatically at the beginning of a new pickup Condition messages should not be stored Also they cannot be reset until the criterion to be reported is cleared This applies to messages from monitoring functions or similar A green...

Page 303: ...tion number FNo can be found in the Appendix The lists also indicate where each message can be sent The lists are based on a SIPROTEC 4 device with the maximum complement of functions If functions are not present in the specific version of the device or if they are set as Disabled in device configuration then the associated messages cannot appear 2 45 1 1 Operational Annunciations Operating messag...

Page 304: ... are displayed immediately no triggered or cyclic refreshment is required 2 45 1 5 Statistical Counters The messages in switching statistics are counters for the accumulation of interrupted currents by each of the breaker poles the number of trips issued by the device to the breaker and the operating hours of the breaker and protected equipment The interrupted currents are in primary terms Switchi...

Page 305: ...perational measured values listed in Table 2 19 may be available The displacement voltage 3U0 is calculated from the phase earth voltages 3U0 UL1 UL2 UL3 All three voltage inputs must be phase ground connected for this Table 2 19 Conversion Formulae between Secondary Values and Primary Percentage Values Measured Val Secondary Primary IL1 S2 IL2 S2 IL3 S2 I1 S2 I2 S 3I0 S2 Isec S2 IL1 S1 IL2 S1 IL3...

Page 306: ... Uerr no primary value Table 2 19 Conversion Formulae between Secondary Values and Primary Percentage Values Measured Val Secondary Primary FACTOR UE UE sec UN VT PRIMARY UN VT SECONDARY UE sec UE prim UN GEN PRIMARY 3 100 Pprim UN VT PRIM UN VT SEC IN PRI I CT S2 IN SEC I CT S2 P sec Powerprim 100 SN GEN MOTOR f in Hz fnom 100 in U f UN fN UN VT PRIMARY UN GEN MOTOR U f UN fN UN VT PRIMARY UN GEN...

Page 307: ... currents IDiff L1 IDiff L2 IDiff L3 IStab L1 IStab L2 IStab L3 I 0Diff I 0Stab 3I0 1 3I0 2 in percent of the nominal values of the protected object The phase angle of the three currents on both sides of the protected object is φIL1S1 φIL2S1 φIL3S1 φIL1S2 φIL2S2 φIL3S2 Thermal Measured Values ΘS ΘSTrip Overload protection measured values of the stator winding depending on the phase in of the tripp...

Page 308: ...ow a message is generated that is output as an operational annunciation and can like all operational annunciations be masked to both output relays and LEDs and transmitted through the interfaces In contrast to the actual protective functions such as time overcurrent protection or overload protection this monitoring program executes in the background and may not respond promptly in case of a fault ...

Page 309: ...nce or RMS values from the measured values A selection may be made as to whether the currents and voltages are represented as primary or secondary values Binary signal traces marks of particular events e g fault detection tripping are also represented If the device has a serial system interface the fault recording data can be passed on to a central device via this interface The evaluation of the d...

Page 310: ...system interface can be blocked during the testing block data transmission Data transmission block can be accomplished by controlling binary inputs by using the operating panel on the device or with a PC and DIGSI 4 via the operator interface The CFC link for changeover to binary input is predefined in the device see Figure A 48 in the Appendix A 9 7 The SIPROTEC 4 System Manual describes in detai...

Page 311: ...n without having to create the indications masked to it This procedure is described in detail in Section 3 3 3 2 45 5 4 Creating a Test Oscillographic Recording At the end of commissioning an investigation of the stability of the protection during closing operations For this closing test should be carried out Oscillographic event recordings obtain the maximum information about the behaviour of the...

Page 312: ...stantaneous values 80 s for recording of r m s values see address 0104 A total of 8 records can be saved Note These times apply for 50 Hz They will be different with another frequency If RMS values are stored the times stated for parameters 0403 to 0406 will be 16 times longer An oscillographic record can be triggered and saved by a change in status of a binary input or via the operator interface ...

Page 313: ...07 Frq MiMa Reset Frq MIN MAX Buffer Reset 00394 UE3h MiMa Res UE 3rd Harm MIN MAX Buffer Reset 00857 I1 Min Positive Sequence Minimum 00858 I1 Max Positive Sequence Maximum 00874 U1 Min U1 positive sequence Voltage Minimum 00875 U1 Max U1 positive sequence Voltage Maximum 00876 PMin Active Power Minimum 00877 PMax Active Power Maximum 00878 QMin Reactive Power Minimum 00879 QMax Reactive Power Ma...

Page 314: ...d in the SIPROTEC 4 System Manual Order No E50417 H1176 C151 and in particular in the CFC Manual Order No E50417 H1176 C098 A logic circuit is created with a PC using the DIGSI 4 software the serial or service port is used for this When the device is delivered from the factory it contains two standard CFC charts see Appendix A 9 7 One chart is used to allow switching of an annunciation measured va...

Page 315: ...ot directly operate binary outputs They serve to initiate internal functions simulate changes of state or to acknowledge changes of state Manual overwriting commands to manually update information on process dependent objects such as annunciations and switching states e g if the communication with the process is interrupted Manually overwritten objects are marked as such in the information status ...

Page 316: ...nds are denied or delayed Equipment Present at Output If a circuit breaker or other operable equipment is not configured to a binary output then the command is denied Output Block if an output block has been programmed for the circuit breaker and is active at the moment the command is processed then the command is denied Component Hardware Malfunction Command in Progress only one command can be pr...

Page 317: ...he command processing If a condition is not fulfilled the command is rejected marked with a minus sign e g CO and a message to that effect is output Table 2 20 shows the types of possible commands to switchgear and the associated annunciations appear in this form only on the device as operational indications in DIGSI 4 as spontaneous messages A sign in the annunciation means a confirmation of the ...

Page 318: ...atically reject a restart command given to the motor Therefore a restart inhibit must be provided by other means e g by a bay interlocking using Double Operation Parallel switching operations are interlocked against one another while one command is processed a second cannot be carried out Switching Authority LOCAL When this interlocking check is enabled in the Object Properties dialog box the stat...

Page 319: ...rotection blockingy n Double oper block y n Sw Auth LOCAL y n Sw Auth REMOTEy n LOCAL REMOTE1 DIGSI AUTO Switching Authority Switch mode LOCAL Switching mode 52 Close 52 Open Feedback ON OFF ON OFF Switching Authority Switching Mode Event Condition of command SCHED ACT y n interlocked non interl interlocked non interl 1 Source REMOTE also includes SAS LOCAL Command using substation controller REMO...

Page 320: ...he device for three switchgear items with the relevant abbreviations explained in Table 2 21 All parametrized interlocking conditions are indicated see Figure 2 137 Figure 2 137 Example of Configured Interlocking Conditions Table 2 21 Interlocking Commands Interlocking Commands Abbreviation Message Switching Authority L L System Interlock S S Zone Controlled Z Z Target State Present State check sw...

Page 321: ...e options Local and Remote are available in the display after entering a password The switching authority condition DIGSI allows commands to be initiated using DIGSI 4 Commands are allowed for both a remote and a local DIGSI 4 connection When a local or remote DIGSI PC logs on to the device it enters its Virtual Device Number VD The device only accepts commands having that VD with switching author...

Page 322: ...LOCAL REMOTE or DIGSI interlocked or non interlocked switching Here deactivation of interlocking is accomplished via a separate command The position of the key switch is irrelevant Auto For commands from CFC SC AUTO the notes in the CFC handbook should be referred to e g component BOOL to command Zone Controlled Field Interlocking Zone Controlled field interlocking includes the verification that p...

Page 323: ...as Block TRIP commands blocks TRIP signals Operations in progress will also be aborted by the pickup of a protective element Device Position Scheduled Actual For switching commands a check takes place whether the selected switching device is already in the scheduled desired position Open Closed scheduled actual comparison This means if a circuit breaker is already in the CLOSED position and an att...

Page 324: ...tion recording Monitoring of Feedback Information The processing of commands monitors the command execution and timing of feed back information for all commands At the same time the command is sent the moni toring time is started monitoring of the command execution This time controls whether the device achieves the required final result within the monitoring time The monitoring time is stopped as ...

Page 325: ... Connections for the device are discussed Hardware modifications that might be needed in certain cases are explained Connection verifications required before the device is put in service are also given Commissioning tests are provided For primary testing the protected object generator motor transformer must be started up and in put into service 3 1 Installation and Connections 310 3 2 Checking Con...

Page 326: ... the ground wire must be greater than or equal to the cross sectional area of any other control conductor connected to the device Furthermore the cross sectional area of the ground wire must be at least AWG 13 G Connect the plug terminals and or the threaded terminals on the rear side of the device according to the elementary diagram for the panel When using spade lugs or directly connecting wires...

Page 327: ...e Housing Elongated Holes SIEMENS SIPROTEC 1 2 6 3 0 5 4 7 8 9 7UM621 RUN ERROR MENU ESC LED ENTER F4 F1 F2 F3 Annunciations Measured values MAIN MENU 01 04 Annunciations 1 Measured values 2 Alarm SIEMENS SIPROTEC 1 2 6 3 0 5 4 7 8 9 7UM622 RUN ERROR MENU ESC LED ENTER F4 F1 F2 F3 Annunciations Masured values MAIN MENU 01 04 Annunciations 1 Measured values 2 Alarm Elongated Holes ...

Page 328: ... become accessible G Fasten the device to the mounting brackets with four or six screws G Replace the four or six covers G Tighten the mounting brackets to the rack using eight screws G Connect the ground on the rear plate of the device to the protective ground of the panel Use at least one M4 screw for the device ground The cross sectional area of the ground wire must be greater than or equal to ...

Page 329: ...r screws Refer to Figure 4 16 and 4 17 in Section 4 35 for dimensions G Connect the ground of the device to the protective ground of the panel The cross sectional area of the ground wire must be greater than or equal to the cross sectional area of any other control conductor connected to the device Furthermore the cross sectional area of the ground wire must be at least AWG 13 G Solid low impedanc...

Page 330: ...the transformation ratio between the primary and the secondary side of the summation current transformer when the sensitive current input of side 2 in Figure is used Likewise factor 0205 FACTOR IEE1 applies when the input of side 1 is used Example Summation current transformer 60 A 1 A Matching factor for sensitive earth fault current detection FACTOR IEE2 60 if the input on side 2 is used If the ...

Page 331: ...shows in an exemplary way how the rotor earth fault protection is connected to a generator with static excitation The earthing must be connected to the earthing brush The coupling device 7XR61 must be complemented by the external resistors 3PP1336 if the circulating current is apt to exceed 0 2 A due to the 6th harmonic component in the excitation voltage This can be the cause with excitation volt...

Page 332: ...hat the response times are as long as approx 300 s Section 2 39 2 shows how the resistance is calculated 3 1 3 Hardware Modifications 3 1 3 1 General Hardware adjustments might be necessary or desired For example a change of the pickup threshold for some of the binary inputs might be advantageous in certain applications Terminating resistors might be required for the communication bus In either ca...

Page 333: ...sary Each binary input has a pickup voltage that can be independently adjusted therefore each input can be set according to the function performed A jumper position is changed to adjust the pickup voltage of a binary input The physical arrangement of the binary input jumpers in relation to the pickup voltages is explained below Sub section 3 1 3 3 Changeover Contacts Input output modules can have ...

Page 334: ...cribed in Section 3 1 3 3 under the side title Processor Printed Circuit Board C CPU 2 for the C CPU 2 processor module and in Section 3 1 3 4 under the side title Serial Interfaces with Bus Capability for the interface modules Both jumpers must always have the same setting As delivered from the factory the resistors are switched out Spare Parts Spare parts can be the battery that provides for sto...

Page 335: ...of the plug connector Carefully pull off the front cover o Disconnect the ribbon cables between the C CPU 2 board and the I O boards to depending on the variant ordered o Remove the boards and set them on the grounded mat to protect them from ESD damage A greater effort is required to withdraw the CPU board especially in versions of the device for surface mounting because of the communication conn...

Page 336: ... Removing the Front Cover Simplified and Reduced 1 3 Slot 5 Slot 19 Slot 33 Binary Inputs BI BI1 to BI6 and C I O 2 Input Output p c b C I O 6 Input Output p c b C CPU 2 Processor p c b 1 3 BI5 BI7 4 4 1 42 1 42 Slot 5 Slot 33 Binary Inputs BI BI6 and 1 3 Slot 19 Slot 33 BI8 to Slot 19 4 2 BI7 BI15 BI1 to BI5 1 3 C I O 2 Input Output p c b C I O 6 Input Output p c b C CPU 2 Processor p c b 4 C I O...

Page 337: ... through BI5 according to Table 3 3 and of the integrated RS232 RS485 interface according to Tables 3 4 through 3 6 The location and ratings of the miniature fuse F1 and of the buffer battery G1 are shown in Figure 3 7 Figure 3 7 C CPU 2 Board Showing the Jumpers for the Power Supply Binary Inputs BI1 To BI5 and the Battery and Miniature Fuse Simplified G1 Cable binder Battery X21 2 1 X51 3 1 2 X5...

Page 338: ...er Nominal Voltage 60 110 125 VDC 110 125 220 250 VDC 115 VAC 24 48 VDC X51 1 2 2 3 Jumpers X51 X52 X53 and X55 are not used X52 1 2 and 3 4 2 3 X53 1 2 2 3 X55 not used 1 2 Can be interchanged Not changeable Table 3 2 Jumper Settings for the Non Energized Position of the Live Status Contact on the C CPU 2 Board Jumper Non Energized Position Open Non Energized Position Closed Factory Setting X40 1...

Page 339: ...em connection cable converter 9 pole on 25 pole Note For a direct connection to DIGSI 4 with interface RS232 jumper X111 must be plugged in position 2 3 If there are no external matching resistors in the system the last devices on a RS485 bus must be configured via jumpers X103 and X104 Note Both jumpers must always be set for the same position Jumper X90 has currently no function The factory sett...

Page 340: ...3 Installation and Commissioning 324 7UM62 Manual C53000 G1176 C149 3 Figure 3 8 Terminating Resistors External 390 Ω 220 Ω 390 Ω 5 V A A B B ...

Page 341: ...e layout of the p c b for the C I O 1 board is shown in Figure 3 9 Figure 3 9 Jumpers on the C I O 1 Board for the Binary Inputs BI8 to BI15 Simplified H L M X22 X21 H L M X24 X23 H L M X26 X25 H L M X28 X27 H L M X30 X29 H L M X32 X31 H L M X34 X33 H L M X36 X35 X40 3 1 2 X71 AD0 H L X72 AD1 X73 AD2 ...

Page 342: ...shows the factory setting of the jumpers The physical location of the modules is shown in Figures 3 5 and 3 6 Table 3 7 Jumper Settings for the Contact of Relay R13 Binary Output BO 13 Jumper Non Energized Position Open NO Contact Non Energized Position Closed NC Contact Factory Setting X40 1 2 2 3 1 2 Table 3 8 Factory Jumper Settings for the Pickup Voltages of the Binary Inputs BI 8 through BI 1...

Page 343: ...specific relay BO 6 the contact type can be changed from normally open to normally closed see overview diagrams in section A 2 of the Appendix Table 3 10 Jumper Settings for Choosing the Contact Type of Binary Output BO 6 on the C I O 2 Board Jumper NO Contact NC Contact Factory Setting X41 1 2 2 3 1 2 X61 1A 5A 3 2 1 T8 T6 T7 T5 X64 1A 5A 3 2 1 X63 5A 1A 1 2 3 X62 5A 1A 1 2 3 X60 1A 5A 3 2 1 X41 ...

Page 344: ... X64 for each of the input transformers and the common jumper X60 However In the version with sensitive earth fault current input input transformer T8 there is no jumper X64 Jumpers X71 X72 and X73 on the C I O 2 board are used to set the bus address and must not be changed Table 3 11 shows the factory setting of the jumpers Table 3 11 Factory Jumper Setting on the C I O 2 Board Jumper Factory Set...

Page 345: ... for devices with power supply voltages of 110 VDC to 220 VDC and 115 VAC Table 3 12 Factory Jumper Settings for the Pickup Voltages of the Binary Inputs BI 6 and BI 7 on the C I O 6 board Binary Input Jumper 17 VDC Pickup1 73 VDC Pickup2 BI 6 X21 L M BI 7 X22 L M T8 T10 T11 T9 X60 AD2 L X64 1A 5A 1 2 3 X73 1 2 3 AD1 X72 1 2 3 AD0 X71 H 1A 5A 1 2 3 X21 L M H X41 3 1 2 X61 1A 5A 1 2 3 X63 1A 5A 1 2...

Page 346: ...n the C I O 6 Board Binary Output Jumper NO Contact NC Contact Factory Setting BO 11 X41 1 2 2 3 1 2 BO 12 X42 1 2 2 3 1 2 Table 3 14 Jumper Settings for the Input Characteristic U I of Measuring Transducer 1 Jumper Voltage Input 10 V Current Input 4 20 20 mA Factory Setting X94 1 2 2 3 1 2 X95 1 2 2 3 1 2 X67 1 2 2 3 1 2 Table 3 15 Jumper Settings for the Input Characteristic U I of Measuring Tra...

Page 347: ...set at addresses 0295 0296 volt age or current input and 0297 with without filter If they do not the device is blocked and outputs an alarm After any changes to the jumper settings you should therefore immediately change the corresponding parameter settings using DIGSI 4 Table 3 17 Factory Jumper Setting on the I O 6 Board Jumper Factory Setting X71 AD0 1 2 H X72 AD1 2 3 L X73 AD2 1 2 H Note Measu...

Page 348: ...ith Interface Modules Please observe the following The interface modules can only be exchanged in devices for panel flush mounting and cubicle mounting Devices for panel surface mounting with two tier terminals can only be converted in the factory You can fit only those interface modules that are also part of the standard configurations of the device as specified in the Ordering Data in the Append...

Page 349: ...ly on the p c b of the CPU 2 board see Section 3 1 3 3 under the side title Processor Printed Circuit Board C CPU 2 Table 3 6 Figure 3 12 shows a view of the C CPU 2 board with the location of the modules The module for the RS485 interface is shown in Figure 3 13 the module for the Profibus interface in Figure 3 14 On delivery the jumpers are set so that the terminating resistors are switched out ...

Page 350: ...5 and vice versa by setting the jumpers on the interface cards Figure 3 13 shows the physical location of the jumpers Table 3 19 shows which jumper settings are associated to RS232 and RS485 respectively When the device is delivered from the factory the jumper setting corresponds to the configuration ordered and need not be changed Jumpers X5 through X10 must be set on the same position X3 1 3 2 X...

Page 351: ...en the I O board s and the C CPU 2 board Be especially careful not to bend any of the connector pins Do not use any force Be sure that the plug connectors latch o Connect the ribbon cable between the C CPU 2 board and the front cover Be especially careful not to bend any of the connector pins Do not use any force Be sure that the plug connectors latch o Close the locking clips of the plug connecto...

Page 352: ...hannel and the receive channel is important In the RS232 and the FO interface each connection is dedicated to one transmission direction The data output of one device must be connected to the data input of the other device and vice versa The data cable connections must conform to DIN 66020 and ISO 2110 see also Table 3 20 TxD data transmit RxD data receive RTS request to send CTS request to send G...

Page 353: ...the terminating resistors provided on the interface card must be switched out If the bus is extended make sure again that only the last device on the bus has the terminating resistors switched in and that all other devices on the bus do not Analog Output The two analog values are output as currents on a 9 pin DSUB female connector The outputs are isolated Table 3 20 Installation of the D Subminiat...

Page 354: ... 2 2 Checking the Device Connections General The device connections must be checked to ensure the correct integration of the device e g in the cubicle The check includes among others the wiring and the functionality as specified in the set of drawings the visual inspection of the protection system and a simplified functional test of the protective device Auxiliary Voltage Supply Before applying po...

Page 355: ...s and voltages should be continuously controllable The accuracy which can be achieved during testing depends on the accuracy of the testing equipment The accuracy values specified in the Technical data can only be reproduced under the reference conditions set down in IEC 60255 resp VDE 0435 part 303 and with the use of precision measuring instruments Tests can be performed using the currently set ...

Page 356: ...he matching factor is reached When the test current falls below approximately 0 7 times the pickup value the relay drops off In the method described above the pickup values for single ended infeed are tested It is also possible to check the entire characteristic Since trip current and restraint current cannot be fed in separately they can however be read out separately in the test measurements a s...

Page 357: ...er rated current Thus the pickup value referred to the rated relay current complies with the set IDIFF of the relay when three or two phase testing is performed kVG 1 for reference winding With single phase testing and zero sequence current elimination a pickup value 1 5 times higher must be expected The following applies for the secondary winding Table 3 23 Correction Factor kVG Depending on Vect...

Page 358: ...re that the device does not pick up immediately after applying the auxiliary power supply as a result of the measuring voltage that is not yet present at the moment of power up However the device does pick up as soon as operating state 1 measuring quantities exist has been attained LED Indications After tests which cause LED indications to appear these should be reset at least once by each of the ...

Page 359: ...xiliary Voltage Supply Check the voltage magnitude and polarity at the input terminals Visual Inspection Check the cubicle and the devices for damage Check the earthing of the cubicle and of the protective device Check the external cabling for condition and completeness Warning The following procedures are carried out with dangerous voltages present Therefore only qualified people who are familiar...

Page 360: ...transducer connection Binary Inputs and Outputs See also section 3 3 3 G Setting the binary inputs Check the jumper settings for the pick up thresholds and modify if necessary see section 3 1 3 Figures 3 7 3 9 and 3 11 as well as Tables 3 3 3 8 and 3 12 Check the pick up threshold if possible with a variable d c voltage source G Check the tripping circuits from the command relays and the tripping ...

Page 361: ...ed the message FAIL Feeder VT ON should appear in the Event Log When the voltage is restored the message FAIL Feeder VT OFF should occur If one of these messages does not appear then the connections and the configuration settings should be checked If the ON and OFF messages are exchanged then the breaker auxiliary contact type should be checked and corrected if necessary ...

Page 362: ...d to the substation ground before any other connections are made Hazardous voltages can exist in the power supply and at the connections to current transformers voltage transformers and test circuits Hazardous voltages can be present in the device even after the power supply voltage has been removed i e capacitors can still be charged After removing voltage from the power supply wait a minimum of ...

Page 363: ...ervice on a live system Note After termination of the test mode the device will reboot Thereby all annunciation buffers are erased If required the events in these buffers should be extracted with DIGSI 4 prior to the test The interface test can be done using DIGSI 4 in the online operating mode G Open the Online directory by double clicking the operating functions for the device appear G Click on ...

Page 364: ...ral or master station of the plant Further tests remain possible while the dialog box is open Test in the Transmission Direction For all information that has to be transmitted to the control system open the drop down list in the column SETPOINT status and test the alternatives listed there G Ensure that any switching operations that may result from these tests can be executed without danger see ab...

Page 365: ...log box is horizontally divided into three groups BI for binary inputs REL for output relays and LED for light emitting diodes Each of these groups is associated with an appropriately marked switching area By clicking in an area components within the associated group can be turned on or off In the Status column the present conditions of the hardware components are symbolically shown The present ph...

Page 366: ...for any output relay all output relays are separated from the device functionality and can now only be operated by the Hardware Test function This means for example that a switching command that is caused by a protection function or by a control command from the operator panel will not be executed G Make sure that there is no risk involved in carrying out the switching operations triggered by the ...

Page 367: ...n function or in case of an LED reset from the device front panel Updating the Display When the dialog box Hardware Test is opened the present conditions of the hardware components at that moment are read in and displayed An update occurs for each component if a command to change the condition is successfully performed for all hardware components if the Update field is clicked for all hardware com...

Page 368: ...he rotor earth fault protection can be checked with the machine at stand still The coupling unit however must be supplied with an external a c voltage 100 V to 125 V or 230 V 50 Hz or 60 Hz Please refer also to connection diagram Figure 2 95 in Section 2 30 1 Switch rotor earth fault protection address 6001 ROTOR E F to Block Relay In the case of machines with rotating rectifier excitation Figure ...

Page 369: ...red The rotor earth fault protection initiates a pick up signal and after 6005 T TRIP RE 0 5 s when delivered from factory a trip annunciation LED 1 and binary output 2 in both cases this is a group indication Device Trip In the case of machines with excitation via slip rings the above test is repeated for the other slip ring Remove earth fault resistor Figure 3 19 Types of Excitation Lift measure...

Page 370: ...ency of the injected square wave voltage The fre quency can be set by a jumper in the 7XT71 The default setting is approx 1 5 Hz tolerance approx 10 Ugen xx x V This measured value indicates the current amplitude of the injected square wave voltage It amounts to approx 50 V tolerance of the 7XT71 can be up to 4 V Igen X xx mA This measured value is nearly zero in fault free condition If a fault re...

Page 371: ...10 s the indication REF 1 3Hz open is issued not masked on delivery Re close the measuring circuit If you want to perform an automatic test by means of a test resistor this mechanism needs to be tested as well To do so connect the test resistor at the slipring to the earth and activate the test via binary input Test REF 1 3Hz Next check the indications for the following four test steps to be perfo...

Page 372: ... now be read out in the earth fault measured values in DIGSI under Ins earth fault measured values U SEF xx x V I SEF xx x mA Please note that these measurements are pure r m s values which only correspond to the 20 Hz quantities if the generator is standing still The voltage measured is influ enced by the loading resistor RL the 20 Hz resistance of the band pass RBP approx 8 Ω the voltage divider...

Page 373: ... PHI I SEF address 5309 should be slightly modified for a better match You can also use for this the operational measured value PHI SEF It may also be necessary to slightly change SEF Rps Finally the fault resistance is read out and set as the tripping value at address 5304 R SEF TRIP Now the primary side earth resistor for the alarm stage e g 5 kΩ is inserted and the fault resistance R SEF is rea...

Page 374: ...de with the ma chine standing still and switch the 20 Hz generator on Multiply the operational mea sured value I SES with the transformation ratio of the miniature CT e g 400 A 5 A The current flow must be higher than 3 A If the current is noticeably less the reso nance frequency of the band pass has changed It can be better matched by adding or removing capacitors see also operating instructions ...

Page 375: ...7UM62 should be checked during the testing Be sure the 7UM62 always indicates the true position of the equipment in the device messages The procedure for the control is described in SIPROTEC 4 System Manual Make sure that the switching authority is set according to the source of commands that is used The switching mode can be chosen as interlocked or non interlocked Note that non interlocked switc...

Page 376: ...ransformers and test circuits Hazardous voltages can be present in the device even after the power supply voltage has been removed i e capacitors can still be charged After removing voltage from the power supply wait a minimum of 10 seconds before re energizing the power supply This wait allows the initial conditions to be firmly established before the device is re energized The limit values given...

Page 377: ...on function is operative and outputs annunciations and measured values However the trip command is blocked and it is not transmitted to the trip matrix Protection function ON The protection function is operative and outputs annunciations and measured values The trip command activates the trip relays which have been marshalled to the protection function If the protection command is not marshalled t...

Page 378: ...the measuring quantities applied are high enough Where tests are performed with reduced pick up values the pick up value may appear to deviate from the setting value e g in the unbalance stage or the earth fault protection if the measuring quantities are too small to block the protection function i e if operating state 1 protection function active is not yet attained However this effect will not i...

Page 379: ... 21 Currents Flowing through the Protected Object For a test of the differential protection the differential and restraint currents are en tered in the characteristic The characteristic shown is a function of the settings for the differential protection In Figure 3 22 a load current has been simulated A small dif ferential current in phase L3 is visible Figure 3 22 Differential and Restraint Curre...

Page 380: ...rst time Absolute Current Values The currents are stated among the operational measured values They are read out from the device front panel or from the PC via the operator interface and compared with the actual measured values If significant deviations are found the CT connections are not correct Phase Rotation The phase rotation must conform with the configured phase sequence address 0271 PHASE ...

Page 381: ...econdary values depend on the rated relay current 1 A or 5 A In the case of the transformer impedance the following results Primary transformer impedance with usc percent impedance voltage of transformer UN rated voltage of transformer SN rated apparent power of transformer In secondary values with NCT current transformer ratio NVT voltage transformer ratio If substantial deviations or wrong sign ...

Page 382: ...nstalled outside the protected zone and allows the symmetrical test current to flow On power station unit transformers and synchronous machines the checks are performed during the current tests with the generator itself supplying the test current Figure 3 24 The current is produced by a three pole short circuit bridge which is installed outside the protected zone and is capable of carrying rated c...

Page 383: ...rences are referred to winding L1 of side 1 Check the angles that are output by the device for side 1 at Measurement Secondary Values Angles All angles are referred to IL1S1 Consequently a clockwise phase rotation should produce roughly the following results ϕL1S1 0 ϕL2S1 240 ϕL3S1 120 If the angles are not correct wrong polarity or phase interchange at side 1 is the cause Disconnect the protected...

Page 384: ...0249 and 0211 matching and vector group of winding 2 For generator or motor protection as per Section 2 12 2 2 addresses 0251 and 0252 matching of machine ratings The symmetrical current tests are now completed Disconnect the protected object shut down generator and earth it remove the test equipment Switch the differential protection to being operative address 2001 DIFF PROT ON it works now as a ...

Page 385: ...igure 3 25 The test current must not exceed the permissible negative sequence current If this current amounts e g to I2perm 10 IN G the test current must be less than 30 IN G On the other hand the current is determined by the low resistance starpoint earthing 10 of the rated generator current are sufficient for testing Figure 3 25 Testing the Earth Current Differential Protection on the Generator ...

Page 386: ... in Power System Data 1 Repeat measurement If the earth current differential protection is used on a transformer a comparative test is performed see Figure 3 26 Measured value 3I0 1 is allocated to side 1 and 3I0 2 to the earth current IEE2 The test method is similar to the one described above For the test current it is essential to ensure that on the generator side the continuously permissible un...

Page 387: ...asurement of the Zero Sequence Currents in a Wye Delta Transformer Figure 3 28 Measurement of the Zero Sequence Currents in a Delta Delta Transformer with Compensating Winding Figure 3 29 Measurement of the Zero Sequence Currents in a Zigzag Winding 7UM62 Test source Test source 7UM62 7UM62 Test source ...

Page 388: ...aint current are equal the polarity of one CT must be wrong Minor deviations are caused by CT errors When checking the phase CTs of the allocated side the measured values device Measurement Operational values secondary per phase will be 1 3 each of the applied zero sequence current The phase angle is the same in all 3 phases due to the zero sequence current If there are deviations a connection err...

Page 389: ...individual protection functions of the device Earthing of the Voltage Transformers When checking the voltage transformers particular attention should be paid to the open delta windings because these windings may only be earthed in one phase Preparation Set the overvoltage protection function to about 110 of the rated generator voltage and give the trip on excitation Switch frequency protection add...

Page 390: ...equency protection function is verified by a plausibility check of the instantane ous machine speed and the associated operational measured value that is indicated Overexcitation The frequency protection function is verified by a plausibility check of the instantaneous machine speed and the associated operational measured value that is indicated The voltage tests are completed after the generator ...

Page 391: ...ceed 10 A if possible Figure 3 31 Unit Connection with Earthing Transformer Calculation of Protected Zone Coupling capacitance CC and loading resistor RB represent a voltage divider equivalent circuit diagram Figure 3 32 whereby RB is the resistance RB referred to the machine terminal circuit Figure 3 32 Equivalent Diagram and Vector Diagram UE RB 7UM62 RT CC CTr CL CG RB Loading resistor RT Volta...

Page 392: ...ltage of The pick up value for the neutral displacement voltage U0 should amount to at least twice the value of this interference voltage Example Network UNU 110 kV fN 50 Hz CC 0 01 µF Voltage transformer 10 kV 0 1 kV Earthing transformer TR 36 Loading resistor RB 10 Ω 10 V has been chosen as the setting value for U0 in address 5002 which corresponds to a protective zone of 90 Figure 3 33 Note Whe...

Page 393: ...f applicable deviating rated primary voltage of earthing transformer or neutral earthing transformer must be taken into account This value also corresponds with the setting value U0 under address 5002 If the plant comprises more voltage transformers with broken delta windings the voltage UE must be measured on them as well For protection zone Z the following applies Example Machine voltage at pick...

Page 394: ...ection is used for stator earth fault protection switch it to be operative as well address 5101 O C PROT Iee ON 3 4 6 2 Busbar Connection Firstly the correct functioning of the loading equipment must be checked sequencing time limit etc as well as the plant data the earthing transformer and the value of the load resistor tapping Switch stator earth fault protection address 5001 to Block relay If t...

Page 395: ...nd IEE under OPERATIONAL MEASURED VALUES If the connections are correct this value corresponds with the machine terminal voltage in percent referred to rated machine voltage if applicable deviating rated primary voltage of earthing transformer or neutral earthing transformer must be taken into account This value also corresponds to the setting value U0 in address 5002 The measured value IEE2 shoul...

Page 396: ... fault bridge Directional Check with Toroidal CTs without Loading Resistor If loading equipment is not available and if an earth fault test with the network is not possible then the following test can be performed with secondary measures however with the symmetrical primary load current With current supplied from a toroidal residual current transformer a voltage transformer e g L1 is by passed whi...

Page 397: ...nner as in the above circuit Only the current of that current transformer which is in the same phase as the by passed voltage transformer in the delta connection is fed into the current path In case of active power in generator direction the same conditions apply for the relay in principle as with an earth fault in generator direction in a compensated network and vice versa Figure 3 36 Directional...

Page 398: ... the 100 Stator Earth Fault Protection The 100 stator earth fault connection is tested together with the 90 stator earth fault protection see Section 3 4 6 1 Unit Connection Set the 100 stator earth fault connection address 5301 100 SEF PROT to Block relay if you have not done so already Also the accessories of the protec tion device must be operational The tests to be performed are described in m...

Page 399: ...r the 90 stator earth fault protection are described in Section 3 4 6 1 side title Checking for Generator Earth Fault For the 100 stator earth fault protection read out the operational measured value I SEF This value is extrapolated to approx 1 3 times the rated machine voltage The current thus extrapolated should not exceed half the pick up value SEF I address 5306 in order to achieve the desired...

Page 400: ...ed in section 3 4 5 for healthy insulation For generators with excitation via slip rings the test is repeated for the other slip ring Shut down generator Remove earth fault resistor The sensitive earth fault detection used for rotor earth fault protection is then set to be operative O C PROT Iee ON in address 5101 3 4 9 Checking the Rotor Earth Fault Protection During Operation 3 4 9 1 Rotor Earth...

Page 401: ...between the measurement slip rings in machines with excitation via slip rings Figure 3 19 right between one slip ring and earth Start up the generator and excite to the rated voltage If applicable place measure ment brushes into operation Check the operational measured value Rearth and the pickup indication REF 1 3Hz Fault and after T TRIP RE 10 s on delivery has expired check the trip indi cation...

Page 402: ...uired for motors The motoring power is as an active power almost constant and independent of the reactive power i e independent of the excitation current However the protection relay may calculate different active power values dependent of the excitation because of possible angle errors of the current and voltage transformers The motoring power curve then would not be a straight line in parallel t...

Page 403: ...rmination of the Correction Angle W0 The read out measured values P1 and P2 are now used to carry out angle error correction Calculate according to the following formula The power values must be inserted with their correct polarity as read out Otherwise faulty result This angle ϕcorr is entered with reversed sign as the new correction angle under address 0204 CT ANGLE W0 New setting CT ANGLE W0 ϕc...

Page 404: ... generator by activating the reverse power protection on Switch ON the reverse power protection address 3101 and if used the forward power supervision address 3201 3 4 10 4 Checking the Underexcitation Protection Underexcitation The angle error correction value CT ANGLE W0 which has been determined in section 3 4 10 2 and configured under address 0204 for use with the angle error correction applie...

Page 405: ...01 O C I to Block relay and the pick up value I address 1302 to the most sensitive value 0 05 A with a rated current of 1 A and 0 25 A with a rated current of 5 A Increase the load current ohmic or ohmic inductive until it exceeds the pick up value and as soon as the pick up annunciations FNo 1801 through 1803 have appeared read out the annunciations 01806 I forward and 01807 I backward Compare th...

Page 406: ... exception that data are not given in the fault messages The externally triggered record has a number for establishing a sequence Triggering with DIGSI 4 To trigger oscillographic recording with DIGSI 4 click on Test in the left part of the window Double click the entry Test Wave Form in the list in the right part of the window to trigger the recording See Figure 3 38 A report is given in the bott...

Page 407: ...y apply for actual system events and faults To clear the buffers press MAIN MENU Annunciation Set Reset Refer to the SIPROTEC 4 System Manual if further assistance is needed The numbers in the switching statistics should be reset to the values that were existing prior to the testing or to values in accordance with the user s practices Set the statistics by pressing MAIN MENU Annunciation Statistic...

Page 408: ...3 Installation and Commissioning 392 7UM62 Manual C53000 G1176 C149 3 ...

Page 409: ... 4 7 Differential Protection for Generators and Motors ANSI 87G 87M 417 4 8 Differential Protection for Transformers ANSI 87T 419 4 9 Earth Current Differential Protection ANSI 87GN TN 422 4 10 Underexcitation Loss of Field Protection ANSI 40 423 4 11 Reverse Power Protection ANSI 32R 424 4 12 Forward Power Supervision ANSI 32F 425 4 13 Impedance Protection ANSI 21 426 4 14 Out of Step Protection ...

Page 410: ...ion with 1 to 3 Hz ANSI 64R 441 4 27 Motor Starting Time Supervision ANSI 48 442 4 28 Restart Inhibit for Motors ANSI 66 49Rotor 443 4 29 Breaker Failure Protection ANSI 50BF 444 4 30 Inadvertent Energization ANSI 50 27 445 4 31 DC Voltage DC Current Protection ANSI 59NDC 51NDC 446 4 32 Thermoboxes for Temperature Detection 447 4 33 Additional Functions 448 4 34 Operating Ranges of the Protection ...

Page 411: ... A continuous Dynamic impulse 750 A for 0 5 cycle Voltage Inputs Secondary Nominal Voltage 100 V to 125 VAC Measuring Range 0 V to 170 VAC Burden at 100 V Approx 0 3 VA AC Voltage Input Overload Capacity Thermal rms 230 V continuous Measuring Transducers Measuring range between 10 V and 10 V or 20 mA and 20 mA Input resistance for DC voltage Approx 1 MΩ Input resistance for DC Current Approx 10 Ω ...

Page 412: ...7UM621 quiescent Approx 5 5 VA 7UM622 Approx 5 5 VA 7UM621 energized Approx 13 VA 7UM622 Approx 15 VA Bridging Time for Failure Short Circuit 200 ms 4 1 3 Binary Inputs and Outputs Binary Inputs Number 7UM621 7 configurable 7UM622 15 configurable Nominal Voltage Range 24 VDC to 250 VDC bipolar Current Consumption Energized Approx 1 8 mA independent of the control voltage Switching Thresholds Adjus...

Page 413: ...ontact or NO contact switch selectable Switching Capability MAKE 1000W VA BREAK 30 W VA 40 W resistive 25 W at L R 50 ms Switching Voltage 250 V Permissible Current per Contact 5 A continuous and Total Current on Common path 30 A for 0 5 s 1 UL listed with the following nominal value 120 VAC Pilot duty B300 240 VAC Pilot duty B300 240 VAC 5 A General Purpose 24 VDC 5 A General Purpose 48 VDC 0 8 A...

Page 414: ...3280 feet 0 62 mile SCADA Interface IEC 60870 5 103 RS232 RS485 Floating interface for data transfer Depends on order code to a master terminal RS232 Connection for Flush Mounted Case Rear panel mounting location B 9 pin DSUB port For Panel Surface At the terminal on the case bottom Mounted Case Test Voltage 500 VAC Transmission Speed Min 4800 Bd max 38400 Bd Factory Setting 38400 Bd Maximum Dista...

Page 415: ... 1640 feet 0 31 mile at 187 5 kBd 200 m 660 feet at 1 5 MBd 100 m 330 feet at 12 MBd DNP3 0 RS485 Connection for Flush Mounted Case rear panel mounting location B 9 pin DSUB Port RS 485 For Panel Surface Mounted Case on the case bottom Test Voltage 500 VAC Transmission Speed up to 19200 Baud Maximum Distance of Transmission 1 km 3280 feet 0 62 mile MODBUS RS485 Connection for Flush Mounted Case re...

Page 416: ... 95 miles MODBUS Fibre Optical Link Connection ST Connector For Flush Mounted Case Rear panel mounting location B For Panel Surface Mounted Case On the case bottom Transmission Speed Up to 19200 Baud Optical Wavelength λ 820 nm Laser Class 1 Under EN 60825 1 2 Using glass fiber 50 125 µm or Using glass fiber 62 5 125 µm Optical Link Signal Attenuation Max 8 dB with glass fiber 62 5 125 µm Channel ...

Page 417: ...eak 1 2 50 µs 0 5 Ws 3 positive All Circuits Except Communications and 3 negative impulses in intervals of 5 s and Time Synchronization Interfaces Analog Outputs Class III EMC Tests for Immunity Type Tests Standards IEC 60255 6 and 22 Product standards EN 50082 2 Generic standard DIN 57 435 Part 303 ANSI IEEE C37 90 1 and C37 90 2 High Frequency Test 2 5 kV Peak 1 MHz τ 15 µs IEC 60255 22 1 Class ...

Page 418: ...kV 42 Ω 0 5 µF Line Conducted HF Amplitude Modul 10 V 150 kHz to 80 MHz 80 AM 1 kHz IEC 61000 4 6 Class III Power System Frequency Magnetic 30 A m continuous 300 A m for 3 s 50 Hz Field IEC 61000 4 8 Class IV 0 5 mT 50 Hz IEC 60255 6 Oscillatory Surge Withstand Capability 2 5 to 3 kV Peak Value 1 MHz to 1 5 MHz ANSI IEEE C37 90 1 damped wave 50 surges per s duration 2 s Ri 150 Ω to 200 Ω Fast Tran...

Page 419: ...al axis 8 Hz to 35 Hz 0 5 g acceleration vertical axis Frequency Sweep Rate1 Octave min 1 cycle in 3 orthogonal axes Vibration and Shock Stress During Transport Standards IEC 60255 21 and IEC 60068 2 Vibration Sinusoidal IEC 60255 21 1 Class 2 5 Hz to 8 Hz 7 5 mm Amplitude IEC 60068 2 6 8 Hz to 150 Hz 2 g acceleration Frequency sweep rate1 Octave min 20 cycles in 3 orthogonal axes Shock Half sine ...

Page 420: ...roper installation procedures should be followed to ensure electromagnetic compatibility EMC In addition the following are recommended All contactors and relays that operate in the same cubicle cabinet or relay panel as the numerical protective device should as a rule be equipped with suitable surge suppression components For substations with operating voltages of 100 kV and above all external cab...

Page 421: ...lush Mounting 1 2 of 19 16 5 pounds 7 5 kg In Case for Flush Mounting 1 1 of 19 22 pounds 9 5 kg In Case for Surface Mounting 1 2 of 19 26 5 pounds 12 kg In Case for Surface Mounting 1 1 of 19 33 pounds 15 kg International Protection Under IEC 60529 In the Surface Mounted Case IP 51 in the Flush Mounted Case and in Model with the Detached Operator Interface Front IP 51 Back IP 50 For Human Safety ...

Page 422: ...50 1 50 2 Current 2 x Pickup Value Approx 35 ms Current 10 x Pickup Value Approx 25 ms Dropout Times 50 1 50 2 Approx 50 ms Dropout Dropout Pickup Ratio 50 1 Approx 0 95 for I IN 0 3 Dropout Pickup Ratio 50 2 0 90 to 0 99 Increments 0 01 Dropout Pickup Ratio U Approx 1 05 Pickup Value Dropout Value ϕ 2 electrical Tolerances Pickup Current 50 1 50 2 1 of setting value or 50 mA1 Undervoltage Seal In...

Page 423: ... Pickup Threshold Approx 1 10 Ip Dropout Threshold Approx 1 05 Ip for Ip IN 0 3 Tolerances Pickup Currents Ip 1 of setting value or 50 mA1 Voltage Threshold U 1 of setting value or 0 5 V Trip Time for 2 I Ip 20 5 of reference calculated value 1 current tolerance respectively 40 ms Influencing Variables for Pickup Power Supply Direct Voltage in Range 0 8 UPS UPS nominal 1 15 1 Temperature in Range ...

Page 424: ...1 1 2 3 5 10 20 100 20 10 5 2 0 5 0 2 0 05 Normal inverse Very inverse Type B Tp t s t s I Ip I Ip 1 0 3 0 1 1 2 3 5 10 20 100 20 10 5 2 0 5 0 2 0 05 s s 1 2 3 5 10 20 0 3 0 1 100 20 10 2 0 05 5 s 0 2 0 5 1 t s 3 3 30 30 3 t 0 14 I I p 0 02 1 T p Type A t 13 5 I I p 1 1 T p t 80 I I p 2 1 T p 0 8 0 1 0 2 0 4 1 6 3 2 0 05 0 8 7 Tp 0 1 0 2 0 4 1 6 3 2 0 8 Tp 0 05 t Trip time in seconds Tp Setting va...

Page 425: ...alue 1 current tolerance respectively 40 ms Influencing Variables for Pickup Power Supply Direct Voltage in Range 0 8 UPS UPS nominal 1 15 1 Temperature in Range 23 F ϑamb 131 F 0 3 10 F 5 C ϑamb 55 C 0 5 10 K Frequency in Range 0 95 f fN 1 05 1 1 For IN 1 A divide all limits and increments by 5 t 8 9341 I Ip 2 0938 1 0 17966 è ø ç æ ö D INVERSE VERY INVERSE EXTREMELY INVERSE For all Characteristi...

Page 426: ... t 3 922 I I p 2 1 0 0982 è ø ç ç æ ö D MODERATELY INVERSE t 0 0103 I Ip 0 02 1 0 0228 è ø ç ç æ ö D D s I Ip 1 2 5 10 15 0 5 2 3 5 10 20 0 3 0 1 500 20 10 2 0 05 5 0 2 0 5 1 t s 30 100 200 3 50 1 s 0 3 0 1 500 20 10 2 0 05 5 0 2 0 5 1 t s 30 100 200 3 50 5 2 1 0 5 10 D s 15 I Ip 1 2 3 5 10 20 t 8 9341 I I p 2 0938 1 0 17966 è ø ç ç æ ö D INVERSE s t trip time in seconds D setting value of the tim...

Page 427: ...0 5 2 3 5 10 20 0 3 0 1 500 20 10 2 0 05 5 0 2 0 5 1 t s 30 100 200 3 50 1 EXTREMELY INVERSE t 5 64 I I p 2 1 0 02434 è ø ç ç æ ö D s D s I Ip 1 2 5 15 0 5 1 2 3 5 10 20 DEFINITE INVERSE s t 0 4797 I I p 1 5625 1 0 21359 è ø ç ç æ ö D 0 3 0 1 500 20 10 2 0 05 5 0 2 0 5 1 t s 30 100 200 3 50 10 t Trip time in seconds D Setting value of the time factor I Fault current Ip Setting value of the pickup ...

Page 428: ... A1 Increments 0 05 A 1 Emergency Time 10 s to 15000 s Increments 1 s Trip Characteristic Curve See also Figure 4 4 Dropout Relations Θ Θtrip Drops out with ΘAlarm Θ ΘAlarm Approx 0 99 I IAlarm Approx 0 95 Tolerances Referring to k IN 2 or 50 mA1 2 class per IEC 60255 8 Thermal Trip and Alarm Times 3 or 1 s for I k IN 1 25 3 class per IEC 60255 8 Influencing Variables Referring to k IN Power Suppl...

Page 429: ... 1 0 3 0 1 100 20 10 5 2 0 5 0 2 0 05 min 3 30 30 3 Parameter Setting Value of Time Constant 20 200 500 100 50 10 5 2 1 4 6 7 8 50 t τ I k IN è ø æ ö 2 I k IN è ø æ ö 2 1 ln without pre load and with IMax therm 8 k IN I k IN 1 2 3 5 10 12 4 6 7 8 with 90 pre load and with IMax therm 8 k IN t τ I k I N è ø æ ö 2 Ipre k I N è ø ç æ ö2 I k IN è ø æ ö 2 1 ln 50 Parameter Setting Value of Time Constant...

Page 430: ...I2 Tripping Stage I2 Approx 50 ms Dropout Warning Stage I2 Tripping Stage I2 Approx 0 95 Thermal Replica drop off at I2 I2 perm Tolerances Pickup Values I2 I2 3 of setting value or 0 3 unbal load Delay Times T 1 of setting value or 10 ms Thermal Replica for 2 I2 I2 perm 20 5 of reference calculated value 1 current tolerance or 600 ms Influencing Variables for Pickup Power Supply Direct Voltage in ...

Page 431: ...racteristics of the Thermal Negative Sequence Protection Stage 1 2 3 4 5 6 7 8 9 10 1 2 3 4 6 10 20 30 40 100 I2 In 0 05 0 07 0 1 0 2 0 3 0 4 0 5 0 7 1 s t 1 2 4 10 20 40 100 200 400 1000 2000 10000 Schieflast t f I2 In t K I2 IN 2 Parameter Setting value FACTOR K 40 s 30 s 20 s 15 s 10 s 5 s 2 s Negative Sequence ...

Page 432: ...ency Dropout Times I 120 ms or higher dep on signal frequency Dropout Current Threshold I 80 or 0 05 I In Tolerances Current Threshold I 10 f 3 Hz I IN 5 Delay Times T 1 or 10 ms Influencing Variables for Pickup Power Supply Direct Voltage in Range 0 8 UH UHN 1 15 1 Temperature in Range 5 C ϑamb 55 C 0 5 10 K Frequency in Range 2 Hz f 10 Hz 10 Harmonics Up to 10 3rd Harmonics 100 Considered in cal...

Page 433: ...ime 0 0 to 180 0 s Increments 0 1 s Add On Stabilization I IN Gen 2 00 to 15 00 Increments 0 01 Duration of Add On Stabilization 2 to 250 dur of period system frequ or does not expire Tripping time delay 0 00 s to 60 00 s Increments 0 01 s for IDIFF and IDIFF or ineffective Pickup Times without parallel operation of other protection functions Dropout Pickup Ratio Approx 0 7 Tolerances With Preset ...

Page 434: ...12 13 14 15 16 17 18 1 2 3 4 5 6 7 8 9 10 SLOPE 2 2031 I DIFF 2021 I DIFF BASE POINT 2 BASE POINT 1 Tripping a b c d Idiff IN Istab IN Fault characteristic Blocking Add On Stabilization SLOPE 1 0 10 20 30 40 0 2 0 1 0 3 2 0 6 0 4 IDIFF IN settable 50 60 70 1 f Hz IXf Setting value e g 0 1 80 Blocking Tripping Legend IDIFF Differential current I1 I2 IfN Current at system frequency IXf Current at an...

Page 435: ...ush Stabilization I2fN IfN 10 to 80 Increments 1 Harmonics see also Figure 4 9 Stabilization nth harm InfN IfN 10 to 80 Increments 1 n 3rd or 5th Harmonics see also Figure 4 10 Release of Blocking I IN Transf 0 5 to 12 0 Increments 0 1 by Higher Order Harmonics Tripping Delay Time 0 00 s to 60 00 s Increm 0 01 s for IDIFF and IDIFF or ineffective Duration of Add On Stabilization 2 to 250 dur of pe...

Page 436: ...ansformer Differential Protection Figure 4 9 Restraining Influence of 2nd Harmonics in Transformer Differential Protection 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 1 2 3 4 5 6 7 8 9 10 SLOPE 2 2031 I DIFF 2021 I DIFF BASE POINT 2 BASE POINT 1 Tripping a b c d Idiff IN Istab IN Fault characteristic Blocking Add On Stabilization SLOPE 1 0 0 1 0 2 0 3 0 4 0 5 0 2 0 5 0 1 1 0 10 0 5 0 2 0 Can be s...

Page 437: ...0 1 0 Can be set to e g 5th harmonic 40 Can be set to e g IDIFF IN 0 2 Can be set to e g IDIFF max n IN 4 Tripping Blocking I5f IfN IfN IN 0 2 0 5 0 05 1 0 12 5 2 Setting value e g 0 15 IDIFF IN settable IDIFF IN settable Tripping 0 3 3 10 0 15 Blocking Blocking IXf Setting value e g 5 0 Legend IDIFF Differential current I1 I2 IfN Current at system frequency IXf Current at any frequency within spe...

Page 438: ...o 100 0 Increments 0 1 V oder disabled Inherent Operating Times Pickup Times Approx 25 to 55 ms Dropout Times Approx 60 ms Dropout Pickup Characteristic Approx 0 90 Dropout Pickup Ratio Approx 0 95 Tolerances Pickup Characteristic 5 of setpoint value or 0 02 I InO Phase Current Blocking I 1 of setting value or 0 01 I InO Zero Voltage Release U0 1 of setting value or 0 5 V Delay Times T 1 of settin...

Page 439: ...kup Times Stator Criterion 1 xd CHAR α Approx 60 ms Rotor Criterion Uexc Approx 60 ms Undervoltage Lock Out U1 Approx 50 ms Dropout Stator Criterion 1 xd CHAR α Approx 0 95 Rotor Criterion Uexc Approx 1 05 or 0 5 V Undervoltage Lock Out U1 Approx 1 1 Tolerances Stator Criterion 1 xd CHAR 3 of setting value Stator Criterion α 1 electrical Rotor Criterion Uexc 1 or 0 1 V Undervoltage Lock Out U1 1 o...

Page 440: ...60 Hz Drop Off Times Reverse Power Pr Approx 360 ms at 50 Hz Approx 300 ms at 60 Hz Dropout Reverse Power Pr Approx 0 6 Tolerances Reverse Power Pr 0 25 SN 3 of set value at Q 0 5 SN SN rated apparent power Q reactive power Delay Times T 1 of setting value or 10 ms Influencing Variables for Pickup Power Supply Direct Voltage in Range 0 8 UPS UPS nominal 1 15 1 Temperature in Range 23 F ϑamb 131 F ...

Page 441: ... Times Forward Power Pf Pf Approx 360 ms at 50 Hz with high accu Approx 300 ms at 60 Hz racy measure ment Approx 60 ms at 50 Hz with high speed Approx 50 ms at 60 Hz measure ment Dropout Forward Power Pf Approx 1 10 or 0 5 of SN Pf Approx 0 90 or 0 5 of SN Tolerances Forward Power Pf Pf 0 25 SN 3 of set value with high accuracy measurement 0 5 SN 3 of set value with high speed measurement SN rated...

Page 442: ...ondary values for IN 5 A for IN 1 A multiply all values by 5 the increment is always 0 01 Ω Power Swing Blocking Difference Power Swing Polygon 0 10 Ω to 30 00 Ω Increments 0 01 Ω Trip Polygon Based onIN 1 A2 Rate of Change dz dt 1 0 Ω s to 600 0 Ω s Increments 0 1 Ω s Based onIN 1 A2 Power Swing Blocking Action Time 0 00 s to 60 00 s Increments 0 01 s 2 Secondary values for IN 1 A for IN 5 A devi...

Page 443: ...rem 0 01 Ω Angle of Inclination of the Polygon 60 0 to 90 0 Increments 0 1 Number of Permissible Power Swings Characteristic 1 1 to 4 Characteristic 2 1 to 8 Measuring Tolerances acc to VDE 0435 ê Z Z ê 5 for 30 ϕK 90 or 10 mΩ with Sinusoidal Quantities 1 Secondary values for IN 5 A for IN 1 A multiply all values by 5 the increment is always 0 01 Ω Times Holding Time of Pickup TH 0 20 s to 60 00 s...

Page 444: ...ting Times Pickup Times Approx 50 ms Dropout Times Approx 50 ms Dropout Pickup Ratio Based on the pickup value of the 1 01 or 0 5 V absolute inverse characteristic Tripping Characteristic for Inverse Function see also Figure 4 12 Tolerances Pickup Voltages 1 of set value or 0 5 V Delay Times T TUp 1 of set value or 10 ms Voltage Time Characteristic 1 based on U or 30 ms Influencing Variables Power...

Page 445: ...oltage Protection ANSI 27 429 7UM62 Manual C53000 G1176 C149 3 Figure 4 12 Tripping Times of the Inverse Undervoltage Protection for Setting Value Up 75 V Without Additional Trip Delay TUp 0 Tripping Time Voltage ...

Page 446: ... 1 59 2 Delay Time T U T U 0 00 s to 60 00 s Increments 0 01 s 59 Delay or does not expire The set time are pure delay times Inherent Operating Times Pickup Times Approx 50 ms Dropout Times Approx 50 ms Tolerances Pickup Voltages 1 of set value or 0 5 V Delay Times T 1 of set value or 10 ms Influencing Variables Power supply DC voltage VDC in Range 0 8 UPS UPS nominal 1 15 1 Temperature in Range 2...

Page 447: ...tage The set times are pure delay times Inherent Operating Times Pickup Times f f Approx 100 ms 81 O or 81 U Dropout Times T f f Approx 100 ms 81 O or 81 U Dropout Frequency f Pickup Value Dropout Value Approx 20 mHz Dropout Voltage Dropout Ratio for Undervoltage Blocking Approx 1 05 Tolerances Pickup Frequencies f f 10 mHz at U UN f fN 81 O or 81U Undervoltage Blocking 1 of set value or 0 5 V Del...

Page 448: ...TCOOL DOWN 0 s to 20000 s Increments 1 s Inherent Operating Times Warning Stage and Stepped Characteristic Pickup Times at 1 1 Times Approx 60 ms setting value Dropout Times Approx 60 ms Dropout Dropout Pickup Approx 0 95 Tripping time characteristic Thermal Replica acc to Presettings Refer to Figure 4 13 Tolerances Pickup on U f 3 of setting value Delay Times T 1 of setting value or 10 ms Thermal...

Page 449: ...C53000 G1176 C149 3 Figure 4 13 Tripping Time Characteristic of Thermal Replica and of Stepped Stage of the Overexcitation Protection Pre settings 1 1 1 2 1 3 1 4 1 2 3 5 10 20 30 50 100 200 300 500 1000 2000 3000 10000 t s U f UN fN T U f Pickup warning stage U f U f ...

Page 450: ...es df dt Approx 150 ms to 500 ms dep on window length Dropout Times df dt Approx 150 ms to 500 ms dep on window length Dropout Dropout Difference f dt 0 02 to 0 99 Hz s settable Dropout Pickup Ratio Approx 1 05 Tolerances Frequency Rise Measuring Window 5 Approx 5 or 0 15 Hz s at U 0 5 UN Measuring Window 5 Approx 3 or 0 1 Hz s at U 0 5 UN Undervoltage Lock Out 1 of setting value or 0 5 V Delay Ti...

Page 451: ...pire Undervoltage Lock Out U1 10 0 to 125 0 V Increments 0 1 V Inherent Operating Times Pickup Times ϕ Approx 75 ms Dropout Times ϕ Approx 75 ms Dropout Tolerances Angle Jump 0 5 at U 0 5 UN Undervoltage Lock Out 1 of setting value or 0 5 V Delay Times T 1 or 10 ms Influencing Variables Power Supply Direct Voltage in Range 0 8 UH UHN 1 15 1 Temperature in Range 5 C ϑamb 55 C 0 5 10 K Frequency in ...

Page 452: ... IE Approx 50 ms Direction Approx 70 ms Dropout Times UE Approx 50 ms IE Approx 50 ms Direction Approx 70 ms Dropout Displacement Voltage UE Approx 0 70 Residual Current IE Approx 0 70 Hysteresis of directional characteristic Approx 10 tow line Tolerances Displacement Voltage UE 1 of setting value or 0 5 V Residual Current IE 1 of setting value or 0 5 mA Delay Times T 1 of setting value or 10 ms I...

Page 453: ...ffective Inherent Operating Times Pickup Times Approx 60 ms Dropout Times Approx 50 ms Measured Value Supervision Approx 2 s Dropout Overcurrent Pick Up IEE IEE Approx 0 95 or 1 mA Measured Value Superv IEE Approx 1 10 or 1 mA Tolerances Overcurrent Pick Up 1 of setting value or 0 5 mA Delay Times T 1 of setting value or 10 ms Influencing Variables for Pickup Power Supply Direct Voltage in Range 0...

Page 454: ... 10 to 100 Increments 1 or 0 ineffective U U1 min 50 0 V to 125 0 V Increments 0 1 V or 0 ineffective Inherent Operating Times Pickup Times Approx 80 ms Dropout Times Approx 80 ms Dropout Undervoltage Stage U0 3rd HARM Approx 1 10 or 0 1 V Overvoltage Stage U0 3rd HARM Approx 0 90 or 0 1 V Release Thresholds P Pmin Approx 0 90 U U1 min Approx 0 95 Tolerances Displacement Voltage 3 of setting value...

Page 455: ...expire Supervision Threshold of 20 HZ Voltage U20 0 3 to 15 0 V Increments 0 1 V I20 5 to 40 mA Increments 1 mA Correction Angle 60 to 60 Increments 1 Inherent Operating Times Pickup Time RSEF RSEF 1 3 s Pickup Time ISEF 250 ms Dropout Time RSEF RSEF 0 8 s Dropout Time ISEF 120 s Dropout Dropout Pickup Ratio Approx 1 2 to 1 7 Tolerances Resistance Approx 5 or 2 Ω Current 3 or 3 mA Delay Time 1 or ...

Page 456: ...rth Fault Current Permissible Rotor Earth Capacity CE For the tolerances stated and for detecting an interruption of the measuring circuit 0 15 µF CE 3 0 µF Permissible Operating Range of the 20 V to 100 V Injected Voltage Warning U RE at U 20 V Times Pickup Times Warning Stage Tripping Stage 80 ms Dropoff Times Warning Stage Tripping Stage 80 ms Dropoff Pickup Ratios RE WARN RE TRIP Approx 1 25 A...

Page 457: ...ments Open Rotor Circuit 0 01 mAs Inherent Operating Times Pickup Time Approx 1 to 1 5 s depends on 7XT71 Dropout Time Approx 1 to 1 5 s Dropout Resistance RE Approx 1 25 Charge QC 1 2 or 0 01 mAs Tolerances Resistance Approx 5 or 0 5 kΩ at 0 15 µF CE 1 µF Approx 10 or 0 5 kΩ at 1 µF CE 3µF Charge 5 or 0 005 mAs Delay Time 1 or 10 ms Permissible Rotor Earth Capacitance 0 15 to 3 µF Influencing Var...

Page 458: ...tio Irms IMOTOR START approx 0 95 Tolerance Pickup Threshold 1 of set value or 50 mA1 Time Delay 5 or 30 ms Influencing Vari ables for Pickup Power Supply Direct Voltage in Range 0 8 UPS UPS nominal 1 15 1 Temperatur in range 23 F ϑamb 131 F 0 3 10 F 5 C ϑamb 55 C 0 5 10 K Frequency in range 0 95 f fN 1 05 1 Harmonic currents Up to 10 3 Harmonic 1 Up to 10 5 Harmonic 1 1 for IN 1 A divide all limi...

Page 459: ...on of Time kτRUNNING 1 0 to 100 0 Increments 0 1 Constant at Motor Running Minimum Restart Inhibit Time 0 2 to 120 0 min Increm 0 1 min Restart Threshold RestartTimes ΘRe Inh ΘL max perm nCOLD 1 nCOLD TRe Inh τ ln ΘHist ΘRe Inh τ ln ΘHist nCOLD nCOLD 1 TWait time TEqual TRe In Meaning ΘRe Inh Temperature threshold below which a restart is possible ΘL max perm Maximum permissible rotor overtemperat...

Page 460: ...itiates For Internal Start Approx 50 ms Using Controls Approx 50 ms For External Start Approx 50 ms Reset Time Approx 50 ms Tolerances Pickup Current BF I 1 of set value or 50 mA1 Delay Time TRIP Timer 1 or 10 ms Influencing Variables Power Supply DC voltage UDC in Range 0 8 UPS UPS nominal 1 15 1 Temperature in Range 23 F ϑamb 131 F 0 3 10 F 5 C ϑamb 55 C 0 5 10 K Frequency in Range 0 95 f fN 1 0...

Page 461: ... 0 01 s or does not expire Inherent Operating Times Pickup Times Approx 25 ms Dropout Times Approx 35 ms Dropout I Approx 0 80 or 250 mA1 Release Threshold U1 Approx 1 05 Tolerances Overcurrent pick up I 5 of setting value or 100 mA1 Release U1 1 of setting value or 0 5 V Delay Times T 1 of setting value or 10 ms Influencing Variables Power Supply DC Voltage UDC in Range 0 8 UPS UPS nominal 1 15 1...

Page 462: ...set times are pure delay times Times Pickup Times Increase U I in Operating State 1 60 ms at f fN in Operating State 0 200 ms Decrease U I in Operating State 1 60 ms at f fN in Operating State 0 200 ms Dropout Times Same as pickup times Dropout Pickup Ratios Voltage Increase U Approx 0 95 or 0 05 V Voltage Decrease U Approx 1 05 or 0 05 V Current Increase I Approx 0 95 or 0 1 mA Current Decrease I...

Page 463: ...or 2 Number of Temperature Detectors per Thermobox max 6 Type of Measurement Pt 100 Ω oder Ni 100 Ω oder Ni 120 Ω Location Setting Oil or Ambient or Winding or Bearing or Other Alarm Threshold Values For Each Measuring Point Stage 1 50 C to 250 C Increments 1 C 58 F to 482 F Increments 1 F or No event Stage 2 50 C to 250 C Increments 1 C 58 F to 482 F Increments 1 F or No event ...

Page 464: ...fL1 IDiffL2 IDiffL3 IStabL1 IStabL2 IStabL3 in I INO Range 10 to 200 IN Tolerance 3 of measured value or 10 mA 1 Digit Operating Measured Values UL1 N UL2 N UL3 N for Voltages Phase Ground in kV primary in V secondary or in of UNom Range 10 to 120 UNom Tolerance 0 2 of measured value or 0 2 V 1 Digit Operating Measured Values UL1 L2 UL2 L3 UL3 L1 for Voltages Phase Phase in kV primary in V seconda...

Page 465: ...l 91 2 digits 31 bit in the unit 7UM62 Tolerance 1 1 Digit Operating Measured Values f in Hz for Frequency Range 40 Hz f 65 Hz Tolerance 10 mHz at U 0 5 UN Thermal Measurement Overload Protection Θ ΘTrip Θ ΘTrip L1 Θ ΘTrip L2 Θ ΘTrip L3 Thermal Measurement Stator Overload Protection ΘS ΘL1Trip ΘS ΘL2Trip ΘS ΘL3Trip Unbalanced Load Protection Θi2 ΘTrip Overexcitation Protection U f ΘU f ΘTrip of Ro...

Page 466: ... 1 0 Stator Earth Resistance sec RSEF in Ω Range 0 Ω to 9999 Ω Tolerance 5 or 2 Ω Stator Earth Resistance prim RSEFP in Ω Range 0 00 to 9999 99 Ω Tolerance 5 or 5 Ω conversion factor Min Max Report Report of Measured Values With date and time Reset Automatic Time of day adjustable in minutes Time frame and starting time adjustable in days 1 to 365 days and Reset Manual Using binary input Using key...

Page 467: ... Current Sum iL1 iL2 iL3 I sum threshold value adjustable Voltage Sum UL1 UL2 UL3 kU UE SUM thres U with kU Uph Udelta Current Phase Sequence Clockwise L1 L2 L3 counter clockwise L1 L3 L2 Voltage Phase Sequence Clockwise L1 L2 L3 counter clockwise L1 L3 L2 Limit Value Monitor Can be configured with CFC IL Limit value LV ANSI 37 1 Trip Log Recording of indication of the last 8 power system faults T...

Page 468: ...IEE1 IEE2 P Q ϕ R X f fN Statistics Circuit Breaker Saved Number of Trips Up to 9 digits Accumulated Interrupted Current Up to 4 digits kA per pole Operating Hours Counter Operating Hours Range Up to 6 digits Criterion to Count Current exceeds an adjustable current threshold BkrClosed I MIN Trip Circuit Monitor ANSI 74TC With one or two binary inputs Commissioning Start up Aids Phase Rotation Chec...

Page 469: ...onversion X X X DIV Division X DM_DECODE Double Point decoding X X X X DYN_OR Dynamic OR Gate X X X X LIVE_ZERO Live Zero monitoring non linear curve X LONG_TIMER Timer max 1193 h X X X X LOOP Signal loop X LOWER_SETPOINT Lower limit X MUL Multiplication X NAND NAND Gate X X X NEG Negator X X X NOR NOR Gate X X X OR OR Gate X X X RS_FF RS Flipflop X X X SQUARE_ROOT Radizierer X SR_FF SR Flipflop X...

Page 470: ...ion Parameters Number of Available Setting Groups 2 parameter group A and B Switchover Performed Using the keypad DIGSI 4 using the front operator interface with protocol via system interface using binary input Run Time Level Limits in TICKS MW_BEARB Measured value processing 10000 PLC1_BEARB Slow PLC processing 1900 PLC_BEARB Fast PLC processing 200 SFS_BEARB Interlocking 10000 Individual Element...

Page 471: ...e2 Overvoltage protection 59 active active active active Overfrequency protection 81 O inactive active active inactive3 Underfrequency protection 81 U inactive active active inactive Overexcitation protection U f 24 inactive1 active active inactive1 Inverse undervoltage protection 27 inactive2 active active inactive2 Rate of frequency change protection 81R inactive active4 active inactive Jump of ...

Page 472: ...ctive at rated frequency 3 Hz Operational Condition 1 The frequency follow up circuit can operate only when at least one a c measured quantity is present at one of the the analog inputs uL1 uL2 uL3 iL1 iL2 iL3 currents on side 2 with an amplitude of at least 5 of rated value operational condition 1 Operational Condition 0 If no suitable a c measured values are present or if the frequency is below ...

Page 473: ...Dimensions 7UM621 for Panel Flush Mounting or Cubicle Installation size 1 2 Rear view 221 2 5 or M4 6 Panel cut out 255 8 0 3 245 1 180 0 5 206 5 0 3 13 2 7 3 5 4 244 266 2 29 5 172 34 Mounting plate Side view with screwed terminals 244 266 2 29 5 172 34 Mounting plate 29 30 Side view with clamp terminals Dimensions in mm 225 220 A C R Q K J F D B ...

Page 474: ...r Cubicle Installation size 1 1 Rear view 244 266 2 29 5 172 34 Monting plate Side view with screwed terminals 244 266 2 29 5 172 34 Mounting plate 29 30 Side view with clamp terminals Dimensions in mm 450 445 Panel cut out 446 2 5 or M4 6 255 8 0 3 245 1 216 1 0 3 13 2 7 3 5 4 13 2 425 5 0 3 13 2 6 6 5 or M4 6 5 or M4 5 or M4 A R Q P N K J F D C B view from the device front ...

Page 475: ...ing size 1 2 Panel Mounting Housing size 1 1 Figure 4 17 Dimensions 7UM622 for Panel Mounting size 1 1 n n n n 280 240 219 225 320 344 10 5 260 29 5 71 266 Front view Side view 9 1 25 26 50 51 75 76 100 Dimensions in mm 260 29 5 71 266 280 465 444 450 320 344 10 5 9 1 50 51 100 200 101 151 150 Front view Side view Dimensions in mm ...

Page 476: ...4 Technical Data 460 7UM62 Manual C53000 G1176 C149 3 ...

Page 477: ...ion available in a 7UM62 equipped with all options are provided A 1 Ordering Information and Accessories 462 A 2 General Diagrams IEC 482 A 3 General Diagrams ANSI 486 A 4 Connection Examples 488 A 5 100 Stator Earth Fault Protection with Primary Load Resistor 499 A 6 Definition of the Active Power Measurement 502 A 7 Current Transformer Requirements 504 A 8 Overview of the Masking Features of the...

Page 478: ... IEC ANSI English language may be changed B Region US 60 Hz ANSI US English language may be changed C SCADA Interface or Analog Output Port B no SCADA interface 0 IEC protocol electrical RS232 1 IEC protocol electrical RS485 2 IEC protocol optical 820 nm ST plug 3 Analog outputs 2 x 0 to 20 mA 7 For more interface options see Additional Information L 9 Additional Information L Port B Profibus DP S...

Page 479: ...rator Protection consisting of B Basic Generator elements comprising Impedance protection Z ANSI 21 100 stator earth fault protection with 3rd harmonic U0 3 Harm ANSI 59TN 27TN3 H Inadvertent energization protection I U ANSI 50 27 Full Generator Protection consisting of C Standard Generator protection comprising Out of step protection Z t ANSI 78 DC voltage DC current protection Udc ANSI 59N DC 51...

Page 480: ...23 1 DNP3 0 RS485 C53207 A351 D631 1 DNP3 0 820 nm C53207 A351 D633 1 Analog output AN20 C53207 A351 D661 1 Covering cap for terminal block type Order No 18 terminal voltage 12 terminal current block C73334 A1 C31 1 12 terminal voltage 8 terminal current block C73334 A1 C32 1 Short circuit links for purpose terminal type Order No Voltage connections 18 terminal or 12 terminal C73334 A1 C34 1 Curre...

Page 481: ...tection R fn Order No Series resistor 2 x 105 Ω 3PP1336 0DZ 013002 Voltage divider Order No Voltage divider 5 1 5 2 3PP1336 1CZ 013001 Voltage divider 10 1 20 1 3PP1326 0BZ 012009 Controller unit Order No In housing for panel surface mounting with terminals at both sides 7XT7100 0BA00 In housing for panel flush mounting with terminals at the rear side 7XT7100 0EA00 Resistor unit Order No In housin...

Page 482: ...erating protective devices via a modem and possibly a star connector using DIGSI 4 Option package of the complete version of DIGSI 4 SIMATIC CFC 4 Graphical software for setting interlocking latching control conditions and creating additional function is SIPROTEC 4 devices Option package for the complete version of DIGSI 4 Interface cable between PC or SIPROTEC device Order No Cable with 9 pin mal...

Page 483: ...oupling Unit 7XR6100 0 A00 Figure A 2 Schematic Diagram of Series Resistor 3PP1336 0DZ 013002 Figure A 3 Schematic Diagram of Voltage Divider 5 1 5 2 3PP1336 1CZ 013001 1A1 1A3 1A4 1B1 1B4 1B3 1B2 2A1 2B1 3B1 4B1 3A1 4A1 0 V 230 V 100 to 125 V 0 V 60 V 36 V 49 V 33 Ω 50 W 0 75 H 4 µF 1 2 105 Ω 3 4 105 Ω 1 2 11 6 Ω 3 4 500 Ω 5 500 Ω 6 250 Ω 500 V 100 V 0 V ...

Page 484: ...eneral Diagram of Resistor Unit 7XR6004 0 A00 1 2 500 Ω 3 500 Ω 4 9000 Ω UControl Auxiliary voltage 230 VAC UMeas Flush mounting housing Surface mounting housing 120 125 VAC X 7 7UM 7XR60 9 9 7 17 15 25 27 19 21 21 19 27 25 17 15 11 11 L N UOutput 100 115 VAC Factory Set 100 125 VAC 230 VAC 2 4 6 8 10 12 14 16 18 1 3 5 7 9 11 13 15 17 3 33 kΩ 20 kΩ 20 kΩ B A 20 kΩ 20 kΩ 2 4 6 8 10 12 1 3 5 7 9 11 ...

Page 485: ...149 3 Figure A 7 General Diagram of 20 Hz Generator 7XT3300 0 A00 2A1 1A1 Surface mounting case Flush mounting case 2A3 1A2 1A3 20 Hz 4A1 4A3 3A1 3A2 3A3 DEVICE OPERATIVE BI L t o 7 X T 4 3 B a n d p a s s EXTERNAL BLOCK 1A4 L L1 L2 L3 U U U U UH UH L1 N to 7XT34 Band pass ...

Page 486: ...General Diagram of 20 Hz Band Pass Filter 7XT3400 0 A00 1A1 Surface mounting case Flush mounting case 1A4 1B4 1B3 1B1 600 mH 1A2 1A3 47 mF 47 mF 10 mF 0R68 4 x 50 W 330R 50 W 330R 50 W 330R 50 W 330R 50 W 330R 50 W INPUT BANDPASS VOLTAGE DIVIDER OUTPUT BANDPASS ...

Page 487: ... Side view Rear view Panel cut out 266 29 5 172 30 Mounting plate 105 0 5 131 5 0 3 13 2 7 3 5 4 244 146 2 5 or M4 Dimensions in mm B A 4 3 2 1 1 2 Connector modules 1 Current connectors Screwed terminal for max 4 mm2 Twin spring crimp connector in parallel for max 2 5 mm max torque value 1 2 Nm 2 Further connectors Screwed terminal for max 1 5 mm2 Twin spring crimp connector in parallel for max 1...

Page 488: ...e A 10 Dimensions of Coupling Unit 7XR6100 0BA0 for Panel Surface Mounting Dimensions on the mounting plate Dimensions in mm 120 0 3 300 0 3 6 4 15 Mounting plate Side view 266 312 8 244 209 5 30 150 145 Rear view B A 4 3 2 1 1 2 Connector modules 5 or M4 ...

Page 489: ... 013001 5 2 1 for series resistor 3PP1336 0DZ 013002 Drip proof roof Space required for removing the cover Cover Table A 1 3PP1 Degree of Protection IP 20 with Drip Proof Roof IP 23 Dimensions in mm Type a b c d e f g h i k l m z 3PP1 32 267 187 3 x 16 7 160 230 10 110 50 30 10 196 33 3PP1 33 267 187 3 x 16 7 160 230 10 146 50 30 10 196 33 Drip proof roof Space required for removing the cover Cove...

Page 490: ...r bolts 4 mm diameter max major diameter 9 mm type e g PIDG of Messrs Tyco Electronics AMP for copper wires with cross section 1 0 mm2 to 2 6 mm2 AWG 17 to 13 solid bare copper wire directly cross section 0 5 mm2 to 2 6 mm2 AWG 20 to 13 flexible wire requires end sleeves max torque value 1 8 Nm or 16 in lbs Dimensions in mm 266 55 100 77 280 300 260 29 5 31 2 30 1 180 recommended space to the next...

Page 491: ...lts 4 mm diameter max major diameter 9 mm type e g PIDG of Messrs Tyco Electronics AMP for copper wires with cross section 1 0 mm2 to 2 6 mm2 AWG 17 to 13 Snap in terminal for copper wires with cross section 0 5 mm2 to 2 5 mm2 AWG 20 to 13 max torque value 1 8 Nm or 16 in lbs Dimensions in mm Mounting plate Connections terminals Panel cut out 29 5 70 71 56 5 7 3 2 0 3 5 or M4 6 172 37 75 2 4 4 2 6...

Page 492: ...R6004 0CA00 for Panel Flash Mounting 225 220 255 8 0 3 245 1 6 Side view with screwed terminals Rear view Panel cut out 266 29 5 172 34 Mounting plate 180 0 5 206 5 0 3 13 2 7 3 5 4 244 221 2 5 or M4 Dimensions in mm 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 1 2 3 4 5 6 7 8 9 10 11 12 B A ...

Page 493: ...sistor Unit 7XR6004 0BA00 for Panel Surface Mounting Rear view Fixing points of the 225 220 Dimensions in mm 200 0 3 4 5 300 0 3 6 4 12 5 100 0 3 Mounting plate Side view with screwed terminals 266 312 8 244 209 5 34 mounting plate 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 1 2 3 4 5 6 7 8 9 10 11 12 B A ...

Page 494: ...00 0CA00 for Panel Flash Mounting Mounting plate 4 3 2 1 4 3 2 1 4 3 2 1 4 3 2 1 Connector modules Panel cut out 29 5 180 206 5 13 2 7 3 0 5 0 3 5 or M4 6 221 2 30 172 225 220 B A Dimensions in mm Connectors Screwed terminal for max 1 5 mm2 Twin spring crimp connector in paral lel for max 1 5 mm2 ...

Page 495: ...0 Hz Generator 7XT3300 0BA00 for Panel Surface Mounting 4 3 2 1 4 3 2 1 4 3 2 1 4 3 2 1 220 B 12 5 30 225 A 244 266 209 5 312 300 0 3 100 0 3 3 ø4 5 oder M5 6 4 200 0 3 Connector modules Dimensions in mm Connectors Screwed terminal for max 1 5 mm2 Twin spring crimp connector in paral lel for max 1 5 mm2 3 ...

Page 496: ...ary since the mounting rails of the device are not sufficient for the high weight of the device Fix the set squares to the panel us ing 8 standard screws size M6 ac cording to the drawing Mount the device to the set squares using standard sqrews size M4 If the device is mounted in switch gear cabinets the set squares can be omitted provided the cabinet po sesses adequate solid mounting rails If no...

Page 497: ... C73165 A63 C203 1 are necessary for panel surface mounting Fix the set squares to the mounting rails of the device using 8 standard screws size M4 Fit threaded holes sleeves or bolts size M6 into the panel according to the above draw ing Fasten the device with the fixed set sqares to the panel and ensure correct distance by means of the distance pieces When using fixed bolts Fit the distance piec...

Page 498: ...IL2S2 Q5 Q6 IL3S2 R13 R14 UE R15 R17 UL1 R18 UL2 R16 UL3 F5 F6 BI1 F8 F9 F10 F7 BI2 BI4 BI5 BI3 K9 K10 BI6 K11 K12 BI7 R3 R4 BO3 R6 BO4 R5 BO5 R2 BO2 R1 BO1 R8 R7 1 2 3 2 BO6 R9 R10 BO7 R11 R12 BO8 K6 K5 1 2 3 2 BO11 Q7 Q8 IEE2 System interface or analog output B A Front oper interface Time Synchronization Service Port C Analog output D For the pin assignment of Interfaces refer to Table 3 20 to 3...

Page 499: ... BI12 BI10 N7 N8 BI13 N9 N10 BI14 N11 N12 BI15 R3 R4 BO3 R6 BO4 R5 BO5 R2 BO2 R1 BO1 R8 R7 1 2 3 2 BO6 R9 R10 BO7 R11 R12 BO8 K6 K5 1 2 3 2 BO11 P17 P18 BI8 N1 N2 BI9 P6 P7 BO14 P8 BO15 P5 BO16 P9 P10 BO17 P11 P12 BO18 P13 P14 BO19 P15 P16 BO20 Q7 Q8 IEE2 P4 P3 1 2 3 2 BO13 System interface or analog output B A Front oper interface Time synchronization Service port C Analog output D For the pin as...

Page 500: ... BI5 BI3 88 63 BI6 87 62 BI7 73 98 BO3 72 BO4 97 BO5 99 BO2 74 BO1 71 96 1 2 3 2 BO6 95 70 BO7 94 69 BO8 65 90 1 2 3 2 BO11 22 47 IEE2 System interface or analog output B Front oper interface Service port C Analog output D For the pin assignment of the interfaces see tables 3 20 and 3 21 in subsection 3 2 1 14 39 IL1S1 13 38 IL2S1 12 37 IL3S1 11 36 IEE1 92 67 BO9 91 66 BO10 64 89 1 2 3 2 BO12 86 6...

Page 501: ...2 3 2 BO11 90 40 BI8 89 39 BI9 139 188 BO14 138 BO15 189 BO16 187 137 BO17 186 136 BO18 185 135 BO19 184 134 BO20 47 97 IEE2 1 2 3 2 BO13 System interface or analog output B Front oper interface Service interface C Analog output D For the assignment of the interfaces see tables 3 20 and 3 21 in subsection 3 2 1 170 120 TD1 169 119 TD2 168 118 TD3 25 75 IL1S1 24 74 IL2S1 23 73 IL3S1 22 72 IEE1 176 ...

Page 502: ...6 R 13 R 14 F 5 F 6 F 7 F 8 F 9 F 10 K 9 K 10 Surface mounting housing 25 50 24 49 23 48 22 47 20 19 44 45 21 46 58 57 56 55 54 83 88 63 95 70 71 96 97 72 98 73 99 74 94 69 51 52 15 16 BI 7 K 11 K 12 87 62 NC or NO with Jumper Live status contact IA S1 IB S1 IC S1 IG sens EE1 J 1 J 2 J 3 J 4 J 5 J 6 J 7 J 8 14 39 13 38 12 37 11 36 R 10 R 11 K 3 K 4 K 2 K 1 K 5 K 6 91 66 67 92 90 65 R 12 K 7 K 8 89...

Page 503: ... 148 199 149 194 144 101 102 37 38 BI 7 K 11 K 12 171 121 Live status contact NC or NO with jumper IA S1 IB S1 IC S1 IG sens EE1 J 1 J 2 J 3 J 4 J 5 J 6 J 7 J 8 25 75 24 74 23 73 22 72 R 9 R10 R11 K 3 K 4 K 2 K 1 K 5 K 6 175 125 126 176 174 124 R12 K 7 K 8 173 123 TD 1 Start up K 13 K 14 170 120 TD 2 Temp K 15 K 16 169 119 TD 3 EXC K 17 K 18 168 118 Serial Thermal or 2 x 20 mA A D B Service interf...

Page 504: ...and broken delta voltage transformers e n VE VA L1 VB L2 VC L3 IA L1 S2 IB L2 S2 IC L3 S2 A L1 B L2 C L3 IA L1 S1 IB L2 S1 IC L3 S1 IEE2 R18 R16 R17 R15 Q8 Q7 R13 R14 Q1 Q2 Q3 Q4 Q5 Q6 7UM62 RL IEE1 J8 J7 Rotor earth current injection k l J2 J3 J4 J5 J6 J1 TD3 K18 K17 Excitation voltage injection TD1 K14 K13 TD2 K16 K15 Measuring transducer Temperature injection or DC voltage injection n e ANSI 52...

Page 505: ...nt measuring by two CT sets detection of displacement volt age at broken delta winding e n IA L1 S2 IB L2 S2 IC L3 S2 VE VA L1 VB L2 VC L3 IA L1 S1 IB L2 S1 IC L3 S1 A L1 B L2 C L3 IEE2 R18 R16 R17 R15 Q8 Q7 R13 R14 Q1 Q2 Q3 Q4 Q5 Q6 7UM62 low resistance if necessary for protection of resistor do not earth here RE J1 J2 J3 J4 J5 J6 IEE1 J8 J7 TD3 K18 K17 TD1 K14 K13 TD2 K16 K15 Measuring transduce...

Page 506: ...lacement voltage at a broken delta winding e n R18 R16 R17 R15 J8 J7 R13 R14 Q1 Q2 Q3 Q4 Q5 Q6 7UM62 Earthing transformer with measuring winding Yd5 RL J1 J2 J3 J4 J5 J6 Q8 Q7 TD3 K18 K17 TD1 K14 K13 TD2 K16 K15 Divider 3PP1326 VExc For 100 stator earth fault protection IEE2 IEE1 A L1 B L2 C L3 VA L1 VB L2 VC L3 VE IA L1 S1 IB L2 S1 IC L3 S1 IA L1 S2 IB L2 S2 IC L3 S2 Measuring transducer Temperat...

Page 507: ...er Loading resistor connected either directly to starpoint circuit or via matching transformers VE R18 R16 R17 R15 R13 R14 Q1 Q2 Q3 Q4 Q5 Q6 7UM62 Yd11 RL max 10A Neutral transformer RE J1 J2 J3 J4 J5 J6 J8 J7 TD3 K18 K17 VExc Q8 Q7 IEE2 TD1 K14 K13 TD2 K16 K15 IEE1 Measuring transducer 1 3Hz Rotor earth fault protection or Temperature injection or DC voltage injection For 100 stator earth fault p...

Page 508: ...th additional source 7XR61 for injecting a nominal frequency test voltage between the rotor circuit and the earth with series connected resistor 3PP1336 7UM62 TD3 K18 K17 UExc Exc TD1 K14 K13 TD2 K16 K15 7KG6 31 32 12 11 Amplifier max 10 cm connections shall be twisted and screened Shunt 10 A 150 mV Connection to the phase to phase VT voltage IEE1 R14 R13 J8 J7 1B1 1B3 1A1 1A3 4A1 4B1 3PP1336 Exc ...

Page 509: ...h Fault Protection with series device 7XR61for injection of a rated frequency voltage into the rotor circuit if the sensitive earth current input is used Connection to the phase to phase VT voltage IEE1 J7 J8 1B1 1B3 1A1 1A3 4A1 4B1 3PP1336 Exc 2B1 7UM6 7XR61 100 V 125 V AC 105Ω 105Ω ...

Page 510: ...h side Earth fault direction detection by toroidal CTs VA L1 VB L2 VC L3 IA L1 S2 IB L2 S2 IC L3 S2 A L1 B L2 C L3 IA L1 S1 IB L2 S1 IC L3 S1 VE R18 R16 R17 R15 R13 R14 Q1 Q2 Q3 Q4 Q5 Q6 7UM62 J1 J2 J3 J4 J5 J6 IEE1 J8 J7 IEE2 Q7 Q8 k l TD3 K18 K17 TD1 K14 K13 TD2 K16 K15 Measuring transducer for injection of any analog signal e g speed vibration pressure e n ANSI 52 FromRTD module Port C oder D R...

Page 511: ...condary Side Figure A 36 Rotor Earth Fault Connection 1 to 3 Hz with 1 3 Hz generator 7XT71 and resistor device 7XR6004 UL1 UL2 UL3 R18 R16 R17 R15 7UM61 L1 L2 L3 7UM62 VA L1 VB L2 VC L3 UA L1 UB L2 UC L3 R18 R16 R17 R15 7UM6 L1 L2 L3 A B C VA L1 VB L2 VC L3 7UM62 Exc Connection to the phase to phase VT voltage Control input Measuring input 15 17 11 25 27 7XR6004 21 19 7UM62 7XT71 TD1 K14 K13 TD2 ...

Page 512: ...ormer J7 J8 TD3 K18 K17 VExc Excitation TD1 K14 K13 IEE1 TD2 K16 K15 7XT33 20 Hz Generator 20 Hz Bandpass 4A3 4A1 1A1 1A2 1A3 3A2 3A1 3A3 At gas turbines Injection of cold gas temperature 400A 5A max 200 V S2 S1 7KG6 31 32 12 11 Amplifier max 10 cm Shunt 10 A 150 mV 2A1 2A3 BE VH VH VA L1 UB L2 UC L3 Device operative Auxiliary voltage DC AC External block Wiring shielded P2 P1 7XT34 1B4 1B1 1A4 1A...

Page 513: ...enerator Figure A 39 Earth current differential protection transformer IA L1 S2 IB L2 S2 IC L3 S2 Q1 Q2 Q3 Q4 Q5 Q6 IA L1 S1 IB L2 S1 IC L3 S1 IEE2 Q7 Q8 J2 J3 J4 J5 J6 J1 7UM62 A L1 B L2 C L3 IA L1 S1 IB L2 S1 IC L3 S1 J2 J3 J4 J5 J6 J1 IA L1 S2 IB L2 S2 IC L3 S2 Q1 Q2 Q3 Q4 Q5 Q6 IEE2 Q7 Q8 7UM62 A L1 B L2 C L3 ...

Page 514: ...mber 00 A and B jumpers for the terminating resis tors Bus number 00 A and B jumpers for the terminating resis tors 7UM62 7XV5650 FO RS485 Converter A B T1 Port D A A B B 7XV566 RTD Box 7UM62 Port C or D A B R1 A A B B 7XV566 RTD Box Bus number 01 A and B jumpers for the terminating resis tors Bus number 01 A and B jumpers for the terminating resis tors 7UM62 A B 7XV566 RTD Box Bus number 01 A B T...

Page 515: ...to a Primary Load Resistor Voltage Transformer Specification An unearthed voltage transformer with a low primary secondary impedance must be used for the 20 Hz frequency Primary voltage UN Generator 3 non saturated up to UN Generator Secondary voltage 500 V Power for 20 s 3 kVA 50 Hz or 60 Hz Primary secondary impedance Zps RL at 20 Hz but at least 1000 Ω Can be obtained e g from Ritz Messwandlerb...

Page 516: ... resistor 0 to 10 kΩ is required for the tests Generator at Standstill 1 After checking the connections a supply voltage is applied to the 20 Hz generator and the protection device The following parameters must be set as follows deliv ery settings address 5309 PHI I SEF 0 and address 5310A SEF Rps 0 Ω In fault free condition RE infinite read out the angle j SEF from the oper ational measured value...

Page 517: ...nal measured values This value is set at address 5302 as R SEF ALARM 4 Finally a series of measurements is performed starting with 0 kΩ and proceeding in steps of 1 kΩ If changes are made to the correction angle PHI I SEF or to the contact resistance SEF Rps the settings for the trip stage R SEF TRIP and the alarm stage R SEF ALARM must be matched as required Running Generator With the generator r...

Page 518: ...ed on the protective device that the power is negative Table A 2 Operating Ranges for Synchronous and Asynchronous Machines Synchronous Generator Synchronous Motor Asynchronous Generator Asynchronous Motor I U G ϕ P Q I U Stability limit underexcited overexcited Reactive power Q is controlled by the ex citation Normal condition P and Q P Q I U Stability limit underexcited overexcited Reactive powe...

Page 519: ... definition is mul tiplied with 1 This means that the power diagram is mirrored around the reactive power axis and that the interpretation of the active power changes This effect must be considered when evaluating the metered energy values If for instance positive power values are to be obtained in an asynchronous motor the current direction parameter 0201 STARPNT SIDE 1 must be reversed Param ete...

Page 520: ...ing are given in Tables A 3 and A 4 on the basis of the IEC 60044 1 and 60044 6 standards Table A 5 shows the necessary equations for converting the requirements into the knee point voltages The primary nominal CT current is defined according to the rules of good engineering practice It must be chosen higher than or equal to the nominal current of the protected object with Ktd Rated transient dime...

Page 521: ...metrical short circuit cur rent IpSC Example uSC 0 1 n 40 xd 0 12 n 34 to 42 Note Always use identical trans formers Power 10 or15 VA Example of network transformer 10P10 10 or15 VA IsN 1 A or 5 A Note the internal burden Example IN G approx 1000 to 2000 A 5P15 15 VA IsN 1 A or 5 A IN G 5000 A 5P20 30 VA IsN 1 A or 5 A Table A 4 Transformer Requirements Transformer Generator 1 uSC IpN Tr 1 xd IpN ...

Page 522: ...tput Slow OUT Output Indication ON OFF X X X X X1 X X X2 OUT Output Indication Open Close X X X X X1 X X X2 Output Fast OUT Protection ON OFF X X X X X X X2 OUT Protection Open Close X X X X X X X2 Tagging IntSP Internal Single Point Indication ON OFF X X X X X X1 X X X2 IntSP Internal Single Point Indication Open Close X X X X X X1 X X X2 IntDP Internal Double Point Indication Breaker indication ...

Page 523: ...2 Trip 2 Close C_D4 ON OFF X X X X X X C_D4 Open Close X X X X X X C_D4 Transformer Tap Changer X X X X X X Double Controls 1 Trip 2 Close C_D12 ON OFF X X X X X X C_D12 Open Close X X X X X X C_D12 Transformer Tap Changer X X X X X X Double Controls negated C_D2N ON OFF X X X X X X C_D2N Open Close X X X X X X C_D2N Transformer Tap Changer X X X X X X Type of Information Source Destination CFC Ta...

Page 524: ... X X X X X X CF_D2 Double Point Indication Breaker indication 00 not valid transmitted as 3 Control X X X X X X DP Feedback X X X X X X CF_D2 Double Point Indication Breaker indication 00 intermediate transmitted as 0 Control X X X X X X DP_I Feedback X X X X X X CF_D2 Transformer Tap Changer Control X X X X X X TxTap Feedback Double Controls 1 Trip 1 Close 1 Common CF_D3 Single Point Indication O...

Page 525: ...transmitted as 0 Control X X X X X X DP_I Feedback X X X X X X CF_D12 Transformer Tap Changer Control X X X X X X TxTap Feedback Double Controls 1 Trip 1 Close negated CF_D2N Single Point Indication ON OFF Control X X X X X X SP Feedback X X X X X X X X CF_D2N Single Point Indication Open Close Control X X X X X X SP Feedback X X X X X X X X CF_D2N Double Point Indication Breaker indication 00 not...

Page 526: ...ted systems via the SCADA interface Table A 6 Overview of Indication Buffers Information type Message buffer E T Single Point Indications SP X X Double Point Indications DP X Output Indications OUT X X Internal Single Point Indications IntSP X X Internal Double Point Indications DP X Transformer Tap Change Indications TxTap X Table A 7 Overview of SCADA Interfaces SCADA Interface Information Type ...

Page 527: ...ave Cap 0004 SP Trigger Waveform Capture Binary input 8 152 List Empty No functions configured reserve Binary output Abbreviation FNo Type Description Output relay 1 Error PwrSupply Fail Battery 0147 0177 OUT O O OUT O O General indication Internal monitoring Output relay 2 Relay TRIP 0511 OUT O O Relay trip Output relay 3 I TRIP Diff TRIP Imp Z1 TRIP Imp Z1B TRIP Imp Z2 TRIP Imp T3 TRIP I TRIP O ...

Page 528: ... U TRIP Pr SV TRIP I2 Θ TRIP Diff TRIP 1815 5193 6573 5237 5343 5346 5098 5161 5671 OUT O O OUT O O OUT O O OUT O O OUT O O OUT O O OUT O O OUT O O OUT O O Marshalled via the tripping matrix De excitation Generator Output relay 10 I TRIP S E F TRIP f2 TRIP I2 Θ TRIP Diff TRIP 1815 5193 5237 5161 5671 OUT O O OUT O O OUT O O OUT O O OUT O O Marshalled via the tripping matrix Stop valve Output relay...

Page 529: ...t breaker De excitation Stop valve I2 TRIP I2 Θ TRIP U0 TRIP S E F TRIP f1 TRIP f2 TRIP f3 TRIP f4 TRIP DC Prot TRIP Exc 3 TRIP Exc 1 TRIP Exc 2 TRP Exc U TRP U f TRP U f th TRIP R E F TRIP I En TRIP Relay 8 Relay 9 Relay 10 SEF 3H TRIP Diff TRIP Diff Trip Diff Trip Up TRIP U TRIP U TRIP U TRIP U TRIP START SUP TRIP Relay 8 Relay 9 Relay 10 Generator circuit breaker De excitation Stop valve FNo 48...

Page 530: ...UT O O Trip by differential protection LED 9 Pr TRIP Pr SV TRIP 5097 5098 OUT O O OUT O O Trip by reverse power protection LED 10 Exc 3 TRIP Exc 1 TRIP Exc 2 TRIP Exc U TRIP 5343 5344 5345 5346 OUT O O OUT O O OUT O O OUT O O Trip by underexcitation protection LED 11 I2 TRIP I2 Θ TRIP 5160 5161 OUT O O OUT O O Trip by unbalanced protection LED 12 f1 TRIP f2 TRIP f3 TRIP 5236 5237 5238 OUT O O OUT ...

Page 531: ...hown in Figure A 47 Figure A 47 Display of spontaneous messages in the display example Pri Side 1 Side 2 L1 122A 1222A L1 124A 1243A L3 123A 1231A I1 0 50kA cosϕ U 10 93kV f 50 00Hz P 4 64MW Q 2 86MVAR DIFF STAB L1 0 00A 0 00A L1 0 00A 0 00A L3 0 00A 0 00A 1 0 50kA 12 6 31kV 2 0 50kA 23 6 30kV 3 0 50kA 31 6 29kV E 0 0A E 2V Protective Function that picked up first Protective Function that dropped ...

Page 532: ...his would not be possible directly i e without the additional block Figure A 48 Logical Link between Input and Output Set points Using modules on the running sequence measured value processing a low current monitor for the three phase currents is implemented The output message is set high as soon as one of the three phase currents falls below the set threshold FigureA 49 Undercurrent Monitoring Ge...

Page 533: ... 2 3 3 3 3 3 4 see separate table in the device manual Information List in the following section 3 3 5 3 3 6 3 3 7 Measurands in monitor direction 144 Measurand I 145 Measurands I V 146 Measurand I V P Q 147 Measurands IN VEN 148 Measurands IL1 2 3 VL1 2 3 P Q f 3 3 8 Generic functions in monitor direction 240 Read headings of all defined groups 241 Read values of all entries of one group 243 Read...

Page 534: ...neral interrogation of generic data 248 Write entry 249 Write entry with confirmation 250 Write entry with execution 251 Write entry abort 3 5 Basic application functions Test mode Blocking of monitor direction Disturbance data Generic services Private data 3 6 Miscellaneous Measurand max value rated value x 1 2 2 4 Current L1 Current L2 Current L3 Voltage L1 E Voltage L2 E Voltage L3 E Voltage L1...

Page 535: ...n I 114 O C PROT Ip Disabled with IEC characteristic on side 1 with ANSI characteristic on side 1 with IEC characteristic on side 2 with ANSI characteristic on side 2 Disabled Inverse O C Time Protection 116 Therm Overload Disabled Enabled Enabled Thermal Overload Protection 117 UNBALANCELOAD Disabled Enabled Enabled Unbalance Load Negative Sequence 118 O C STARTUP Disabled Enabled Enabled Startup...

Page 536: ...bled non directional only U0 non directional with U0 I0 directional non directional with U0 I0 Stator Earth Fault Protection 151 O C PROT Iee Disabled with Iee1 with Iee2 with Iee2 Sensitive Earth Current Protec tion 152 SEF 3rd HARM Disabled Enabled Enabled Stator Earth Fault Prot 3rd Har monic 153 100 SEF PROT Disabled Enabled Enabled 100 Stator Earth Fault Protec tion 160 ROTOR E F Disabled Ena...

Page 537: ...d Positive Sequence Current I1 Negative Sequence Current I2 Positive Sequence Voltage U1 Active Power P Reactive Power Q Frequency f Power Factor p u Temperature of Rotor p u Temperature of Stator Disabled Analog Output B2 Port B 175 ANALOGOUTPUT D1 Disabled Positive Sequence Current I1 Negative Sequence Current I2 Positive Sequence Voltage U1 Active Power P Reactive Power Q Frequency f Power Fact...

Page 538: ...s with 1 Binary Input Disabled Trip Circuit Supervision 185 THRESHOLD Disabled Enabled Enabled Threshold Supervision 186 EXT TRIP 1 Disabled Enabled Enabled External Trip Function 1 187 EXT TRIP 2 Disabled Enabled Enabled External Trip Function 2 188 EXT TRIP 3 Disabled Enabled Enabled External Trip Function 3 189 EXT TRIP 4 Disabled Enabled Enabled External Trip Function 4 190 RTD BOX INPUT Disab...

Page 539: ...bject 211 IN PRI I SIDE2 Power System Data 1 1 100000 A 500 A CT Rated Primary Current Side 2 212 IN SEC I SIDE2 Power System Data 1 1A 5A 1A CT Rated Secondary Cur rent Side 2 213 FACTOR IEE2 Power System Data 1 1 0 100000 0 60 0 CT Ratio Prim Sec IEE2 214 GRD TERM IEE2 Power System Data 1 Terminal Q7 Terminal Q8 Terminal Q7 Grounded Terminal CT IEE2 221 Unom PRIMARY Power System Data 1 0 10 400 ...

Page 540: ...ct connected to busbar Unit transformer connected Direct connected to busbar Scheme Configuration 274A ATEX100 Power System Data 1 YES NO NO Storage of th Replicas w o Power Supply 275 FACTOR R SEF Power System Data 1 1 0 200 0 37 0 Ratio Prim Sec R SEF 276 TEMP UNIT Power System Data 1 Degree Celsius Degree Fahrenheit Degree Celsius Unit of temparature measu rement 280 TMin TRIP CMD Power System ...

Page 541: ...t Time Protec tion I 1202 I O C I with undervoltage seal in 0 05 20 00 A 1 35 A I Pickup 1203 T I O C I with undervoltage seal in 0 00 60 00 sec 3 00 sec T I Time Delay 1204 U SEAL IN O C I with undervoltage seal in ON OFF OFF State of Undervoltage Seal in 1205 U O C I with undervoltage seal in 10 0 125 0 V 80 0 V Undervoltage Seal in Pik kup 1206 T SEAL IN O C I with undervoltage seal in 0 10 60 ...

Page 542: ...eshold for Release Ip 1601 Ther OVER LOAD Thermal Over load Protection OFF ON Block relay for trip commands Alarm Only OFF Thermal Overload Protec tion 1602 K FACTOR Thermal Over load Protection 0 10 4 00 1 11 K Factor 1603 TIME CONSTANT Thermal Over load Protection 30 32000 sec 600 sec Thermal Time Constant 1604 Θ ALARM Thermal Over load Protection 70 100 90 Thermal Alarm Stage 1605 TEMP RISE I T...

Page 543: ...T COOL DOWN Unbalance Load Negative Sequence 0 50000 sec 1650 sec Time for Cooling Down 1706 I2 Unbalance Load Negative Sequence 10 100 60 I2 Pickup 1707 T I2 Unbalance Load Negative Sequence 0 00 60 00 sec 3 00 sec T I2 Time Delay 1801 O C STARTUP Startup O C protection OFF ON Block relay for trip commands OFF Startup O C protection 1802 STARTUP I Startup O C protection 0 10 20 00 A 1 30 A I Pick...

Page 544: ... Start 2053 T START MAX Differential Pro tection 0 0 180 0 sec 5 0 sec Maximum Permissible Star ting Time 2056A I ADD ON STAB Differential Pro tection 2 00 15 00 I InO 4 00 I InO Pickup for Add on Stabiliza tion 2057A T ADD ON STAB Differential Pro tection 2 250 Cycle 15 Cycle Duration of Add on Stabili zation 2061 2 HARMONIC Differential Pro tection 10 80 15 2nd Harmonic Content in I DIFF 2062A C...

Page 545: ...on Protection 50 120 90 Inclination Angle of Charac teristic 2 3007 T CHAR 2 Underexcitation Protection 0 00 60 00 sec 10 00 sec Characteristic 2 Time Delay 3008 1 xd CHAR 3 Underexcitation Protection 0 25 3 00 1 10 Conductance Intersect Characteristic 3 3009 ANGLE 3 Underexcitation Protection 50 120 90 Inclination Angle of Charac teristic 3 3010 T CHAR 3 Underexcitation Protection 0 00 60 00 sec ...

Page 546: ...e Protection 3302 IMP I Impedance Pro tection 0 10 20 00 A 1 35 A Fault Detection I Pickup 3303 U SEAL IN Impedance Pro tection ON OFF OFF State of Undervoltage Seal in 3304 U Impedance Pro tection 10 0 125 0 V 80 0 V Undervoltage Seal in Pik kup 3305 T SEAL IN Impedance Pro tection 0 10 60 00 sec 4 00 sec Duration of Undervoltage Seal in 3306 ZONE Z1 Impedance Pro tection 0 05 130 00 Ohm 2 91 Ohm...

Page 547: ...ly gon reverse 3506 Zc Out of Step Protection 0 10 130 00 Ohm 3 60 Ohm Reactance Zc of Polygon forward char 1 3507 Zd Zc Out of Step Protection 0 00 130 00 Ohm 6 40 Ohm Reactance Dif Char 1 Char 2 forward 3508 PHI POLYGON Out of Step Protection 60 0 90 0 90 0 Angle of Inclination of the Polygon 3509 REP CHAR 1 Out of Step Protection 1 4 1 Number of Power Swing Characteristic 1 3510 REP CHAR 2 Out ...

Page 548: ...NCY Frequency Pro tection OFF ON Block relay for trip commands OFF Over Under Frequency Protection 4202 f1 PICKUP Frequency Pro tection 40 00 65 00 Hz 48 00 Hz f1 Pickup 4203 f1 PICKUP Frequency Pro tection 40 00 65 00 Hz 58 00 Hz f1 Pickup 4204 T f1 Frequency Pro tection 0 00 600 00 sec 1 00 sec T f1 Time Delay 4205 f2 PICKUP Frequency Pro tection 40 00 65 00 Hz 47 00 Hz f2 Pickup 4206 f2 PICKUP ...

Page 549: ...rexcitation Protection U f 0 20000 sec 20000 sec U f 1 05 Time Delay 4307 t U f 1 10 Overexcitation Protection U f 0 20000 sec 6000 sec U f 1 10 Time Delay 4308 t U f 1 15 Overexcitation Protection U f 0 20000 sec 240 sec U f 1 15 Time Delay 4309 t U f 1 20 Overexcitation Protection U f 0 20000 sec 60 sec U f 1 20 Time Delay 4310 t U f 1 25 Overexcitation Protection U f 0 20000 sec 30 sec U f 1 25...

Page 550: ... stage f1 4506 df2 dt Rate of fre quency change protection df dt negative rate of freq change df dt positive rate of freq change df dt negative rate of freq change Mode of Threshold df2 dt 4507 STAGE df2 dt Rate of fre quency change protection 0 1 10 0 Hz s 1 0 Hz s Pickup Value of df2 dt Stage 4508 T df2 dt Rate of fre quency change protection 0 00 60 00 sec 0 50 sec Time Delay of df2 dt Stage 45...

Page 551: ...Window for df1 dt df2 dt 4521A df3 4 HYSTERES Rate of fre quency change protection 0 02 0 99 Hz s 0 40 Hz s Reset Hysteresis for df3 dt df4 dt 4522A df3 4 M WINDOW Rate of fre quency change protection 1 25 Cycle 5 Cycle Measuring Window for df3 dt df4 dt 4601 VECTOR JUMP Jump of Voltage Vector OFF ON Block relay for trip commands OFF Jump of Voltage Vector 4602 DELTA PHI Jump of Voltage Vector 2 3...

Page 552: ...000 mA 23 mA Iee Pickup 5105 T IEE Sensitive Earth Current Protec tion 0 00 60 00 sec 1 00 sec T Iee Time Delay 5106 IEE Sensitive Earth Current Protec tion 1 5 50 0 mA 0 0 0 mA Iee Pickup Interrupted Circuit 5201 SEF 3rd HARM Stator Earth Fault Protec tion 3rdHarm OFF ON Block relay for trip commands OFF Stator Earth Fault Protec tion 3rdHarm 5202 U0 3 HARM Stator Earth Fault Protec tion 3rdHarm ...

Page 553: ...Stator Earth Fault Pro tection 5 40 mA 10 mA Supervision Threshold of 20Hz Current 5309 PHI I SEF 100 Stator Earth Fault Pro tection 60 60 0 Correction Angle for I SEF 100 5310A SEF Rps 100 Stator Earth Fault Pro tection 0 0 700 0 Ohm 0 0 Ohm Resistance Rps 5311A Rl PARALLEL 100 Stator Earth Fault Pro tection 20 700 Ohm Ohm Parallel Load Resistance 6001 ROTOR E F Rotor Earth Fault Protection OFF O...

Page 554: ...ult Protec tion 1 3Hz 0 00 60 00 sec 1 00 sec Time Delay of Tripping Stage Re 6106 Qc Rotor Earth Fault Protec tion 1 3Hz 0 00 1 00 mAs 0 02 mAs Pickup Value of open Rotor Circuit Qc 6107A TEST RESISTOR Rotor Earth Fault Protec tion 1 3Hz 1 0 10 0 kOhm 3 3 kOhm Testing Resistor 6501 STARTUP MOTOR Motor Starting Time Supervi sion OFF ON Block relay for trip commands OFF Motor Starting Time Super vi...

Page 555: ...Block relay for trip commands OFF Breaker Failure Protection 7002 TRIP INTERN Breaker Failure Protection OFF Start Breaker Failure with Bin Outp 12 Start Breaker Failure with CFC OFF Start with Internal TRIP Command 7003 CIRC BR I Breaker Failure Protection 0 04 2 00 A 0 20 A Supervision Current Pickup 7004 TRIP Timer Breaker Failure Protection 0 06 60 00 sec 0 25 sec TRIP Timer 7101 INADVERT EN I...

Page 556: ... 0 20 mA B2 correspond to 7304 MIN VALUE B2 Analog Outputs 0 0 5 0 mA 1 0 mA Output value B2 valid from 7305 20 mA D1 Analog Outputs 10 0 1000 0 200 0 20 mA D1 correspond to 7306 MIN VALUE D1 Analog Outputs 0 0 5 0 mA 1 0 mA Output value D1 valid from 7307 20 mA D2 Analog Outputs 10 0 1000 0 200 0 20 mA D2 correspond to 7308 MIN VALUE D2 Analog Outputs 0 0 5 0 mA 1 0 mA Output value D2 valid from ...

Page 557: ...SUP Trip Circuit Supervision OFF ON OFF TRIP Circuit Supervision 8501 MEAS VALUE 1 Threshold supervision Disabled Active Power P Reactive Power Q Change of Active Power Delta P Positive Sequence Voltage U1 Negative Sequence Voltage U2 Zero Sequence Cur rent I0 Positive Sequence Current I1 Negative Sequence Current I2 Power Angle PHI Disabled Measured Value for Thres hold MV1 8502 THRESHOLD MV1 Thr...

Page 558: ...P Positive Sequence Voltage U1 Negative Sequence Voltage U2 Zero Sequence Cur rent I0 Positive Sequence Current I1 Negative Sequence Current I2 Power Angle PHI Disabled Measured Value for Thres hold MV4 8508 THRESHOLD MV4 Threshold supervision 200 200 100 Pickup Value of Measured Value MV4 8509 MEAS VALUE 5 Threshold supervision Disabled Active Power P Reactive Power Q Change of Active Power Delta...

Page 559: ...Time Delay 8701 EXTERN TRIP 2 External Trip Functions OFF ON Block relay for trip commands OFF External Trip Function 2 8702 T DELAY External Trip Functions 0 00 60 00 sec 1 00 sec Ext Trip 2 Time Delay 8801 EXTERN TRIP 3 External Trip Functions OFF ON Block relay for trip commands OFF External Trip Function 3 8802 T DELAY External Trip Functions 0 00 60 00 sec 1 00 sec Ext Trip 3 Time Delay 8901 ...

Page 560: ... F 212 F RTD 2 Temperature Stage 1 Pickup 9025 RTD 2 STAGE 2 RTD Box 50 250 C 120 C RTD 2 Temperature Stage 2 Pickup 9026 RTD 2 STAGE 2 RTD Box 58 482 F 248 F RTD 2 Temperature Stage 2 Pickup 9031A RTD 3 TYPE RTD Box not connected Pt 100 Ohm Ni 120 Ohm Ni 100 Ohm not connected RTD 3 Type 9032A RTD 3 LOCATION RTD Box Oil Ambient Winding Bearing Other Other RTD 3 Location 9033 RTD 3 STAGE 1 RTD Box ...

Page 561: ... 1 RTD Box 50 250 C 100 C RTD 5 Temperature Stage 1 Pickup 9054 RTD 5 STAGE 1 RTD Box 58 482 F 212 F RTD 5 Temperature Stage 1 Pickup 9055 RTD 5 STAGE 2 RTD Box 50 250 C 120 C RTD 5 Temperature Stage 2 Pickup 9056 RTD 5 STAGE 2 RTD Box 58 482 F 248 F RTD 5 Temperature Stage 2 Pickup 9061A RTD 6 TYPE RTD Box not connected Pt 100 Ohm Ni 120 Ohm Ni 100 Ohm not connected RTD 6 Type 9062A RTD 6 LOCATIO...

Page 562: ... connected RTD 8 Type 9082A RTD 8 LOCATION RTD Box Oil Ambient Winding Bearing Other Other RTD 8 Location 9083 RTD 8 STAGE 1 RTD Box 50 250 C 100 C RTD 8 Temperature Stage 1 Pickup 9084 RTD 8 STAGE 1 RTD Box 58 482 F 212 F RTD 8 Temperature Stage 1 Pickup 9085 RTD 8 STAGE 2 RTD Box 50 250 C 120 C RTD 8 Temperature Stage 2 Pickup 9086 RTD 8 STAGE 2 RTD Box 58 482 F 248 F RTD 8 Temperature Stage 2 P...

Page 563: ...p 9106 RTD10 STAGE 2 RTD Box 58 482 F 248 F RTD10 Temperature Stage 2 Pickup 9111A RTD11 TYPE RTD Box not connected Pt 100 Ohm Ni 120 Ohm Ni 100 Ohm not connected RTD11 Type 9112A RTD11 LOCATION RTD Box Oil Ambient Winding Bearing Other Other RTD11 Location 9113 RTD11 STAGE 1 RTD Box 50 250 C 100 C RTD11 Temperature Stage 1 Pickup 9114 RTD11 STAGE 1 RTD Box 58 482 F 212 F RTD11 Temperature Stage 1...

Page 564: ... Stage 1 Pickup 9124 RTD12 STAGE 1 RTD Box 58 482 F 212 F RTD12 Temperature Stage 1 Pickup 9125 RTD12 STAGE 2 RTD Box 50 250 C 120 C RTD12 Temperature Stage 2 Pickup 9126 RTD12 STAGE 2 RTD Box 58 482 F 248 F RTD12 Temperature Stage 2 Pickup Addr Setting Title Function Setting Options Default Setting Comments ...

Page 565: ...ED Device SP LED BI BO 135 50 1 GI 00007 Setting Group Select Bit 0 Set Group Bit0 Change Group SP LED BI BO 135 51 1 GI 00015 Test mode Test mode Device SP LED BI BO 135 53 1 GI 00016 Stop data transmission DataStop Device SP LED BI BO 135 54 1 GI 00051 Device is Operational and Protecting Device OK Device OUT ON OF F LED BO 135 81 1 GI 00052 At Least 1 Protection Funct is Active ProtActive Devic...

Page 566: ... Ph Seq Measurement Supervision OUT ON OF F LED BO 70 35 1 GI 00176 Failure Phase Sequence Voltage Fail Ph Seq U Measurement Supervision OUT ON OF F LED BO 135 192 1 GI 00177 Failure Battery empty Fail Battery Supervision OUT ON OF F LED BO 00181 Error A D converter Error A D conv Supervision OUT ON OF F LED BO 00191 Error Offset Error Offset Supervision OUT ON OF F LED BO 00193 Alarm NO calibrati...

Page 567: ...5 156 1 GI 00266 Failure Phase Sequence I side 2 FailPh Seq I S2 Measurement Supervision OUT ON OF F LED BO 135 157 1 GI 00267 Failure RTD Box 2 Fail RTD Box 2 Supervision OUT ON OF F LED BO 135 209 1 GI 00272 Set Point Operating Hours SP Op Hours Set Points Stati stic OUT ON OF F LED BO 135 229 1 GI 00284 Set Point I alarm SP I Set Points Measu red Values OUT LED BO 135 244 1 GI 00361 Failure Fee...

Page 568: ...2 Power System Data 2 OUT ON OFF 150 192 4 01020 Counter of operating hours Op Hours Statistics OUT 01202 BLOCK IEE BLOCK IEE Sensitive Earth Current Protection SP ON OF F LED BI BO 151 102 1 GI 01203 BLOCK IEE BLOCK IEE Sensitive Earth Current Protection SP ON OF F LED BI BO 151 103 1 GI 01221 IEE picked up IEE picked up Sensitive Earth Current Protection OUT ON OFF LED BO 151 121 2 GI 01223 IEE ...

Page 569: ...n OUT ON OF F LED BO 166 191 1 GI 01451 Breaker failure is switched OFF BkrFail OFF Breaker Failure Protection OUT ON OF F LED BO 166 151 1 GI 01452 Breaker failure is BLOCKED BkrFail BLOCK Breaker Failure Protection OUT ON OF F ON OFF LED BO 166 152 1 GI 01453 Breaker failure is ACTIVE BkrFail ACTIVE Breaker Failure Protection OUT ON OF F LED BO 166 153 1 GI 01455 Breaker failure protection picke...

Page 570: ...67 19 1 GI 01521 Thermal Overload TRIP ThOverload TRIP Thermal Overload Protection OUT ON LED BO 167 21 2 GI 01720 BLOCK direction I stage BLOCK dir O C I with direc tion SP ON OF F LED BI BO 60 18 1 GI 01721 BLOCK I BLOCK I O C I with direc tion SP LED BI BO 01722 BLOCK I BLOCK I O C I with under voltage seal in SP LED BI BO 01801 O C fault detection stage I phase L1 I Fault L1 O C I with direc t...

Page 571: ...ction OUT ON OFF LED BO 60 184 2 GI 01897 O C fault detection Ip phase L2 O C Ip Fault L2 Inverse O C Time Protection OUT ON OFF LED BO 60 185 2 GI 01898 O C fault detection Ip phase L3 O C Ip Fault L3 Inverse O C Time Protection OUT ON OFF LED BO 60 186 2 GI 01899 O C Ip picked up O C Ip pick up Inverse O C Time Protection OUT ON OFF LED BO 60 183 2 GI 01900 O C Ip TRIP O C Ip TRIP Inverse O C Ti...

Page 572: ... up Impedance Protec tion OUT ON OFF LED BO 28 229 2 GI 03967 Imp Fault detection phase L1 Imp Fault L1 Impedance Protec tion OUT ON OFF LED BO 28 230 2 GI 03968 Imp Fault detection phase L2 Imp Fault L2 Impedance Protec tion OUT ON OFF LED BO 28 231 2 GI 03969 Imp Fault detection phase L3 Imp Fault L3 Impedance Protec tion OUT ON OFF LED BO 28 232 2 GI 03970 Imp O C with undervoltage seal in Imp ...

Page 573: ... BLOCKED Ext 2 BLOCKED External Trip Functions OUT ON OF F ON OFF LED BO 51 152 1 GI 04553 External trip 2 is ACTIVE Ext 2 ACTIVE External Trip Functions OUT ON OF F LED BO 51 153 1 GI 04556 External trip 2 General picked up Ext 2 picked up External Trip Functions OUT ON OFF LED BO 51 156 2 GI 04557 External trip 2 General TRIP Ext 2 Gen TRP External Trip Functions OUT ON LED BO 51 157 2 GI 04563 ...

Page 574: ...LK Re Inhib Restart Inhibit for Motors SP LED BI BO 04823 Emergency start rotor Emer Start ΘR Restart Inhibit for Motors SP ON OF F LED BI BO 168 51 1 GI 04824 Restart inhibit motor is switched OFF Re Inhibit OFF Restart Inhibit for Motors OUT ON OF F LED BO 168 52 1 GI 04825 Restart inhibit motor is BLOCKED Re Inhibit BLK Restart Inhibit for Motors OUT ON OF F LED BO 168 53 1 GI 04826 Restart inh...

Page 575: ...ut of Step Protec tion OUT ON OF F ON OFF LED BO 70 57 1 GI 05063 Out of step protection is ACTIVE O S ACTIVE Out of Step Protec tion OUT ON OF F LED BO 70 58 1 GI 05067 Out of step pulse of characteristic 1 O S char 1 Out of Step Protec tion OUT ON OFF LED BO 70 60 2 GI 05068 Out of step pulse of characteristic 2 O S char 2 Out of Step Protec tion OUT ON OFF LED BO 70 61 2 GI 05069 Out of step ch...

Page 576: ... Forward Power Supervision SP ON OF F LED BI BO 70 103 1 GI 05121 Forward power supervis is switched OFF Pf OFF Forward Power Supervision OUT ON OF F LED BO 70 106 1 GI 05122 Forward power supervision is BLOK KED Pf BLOCKED Forward Power Supervision OUT ON OF F ON OFF LED BO 70 107 1 GI 05123 Forward power supervision is ACTIVE Pf ACTIVE Forward Power Supervision OUT ON OF F LED BO 70 108 1 GI 051...

Page 577: ...05159 I2 picked up I2 picked up Unbalance Load Negative Sequence OUT ON OFF LED BO 70 138 2 GI 05160 Unbalanced load TRIP of current stage I2 TRIP Unbalance Load Negative Sequence OUT ON M LED BO 70 139 2 GI 05161 Unbalanced load TRIP of thermal stage I2 Θ TRIP Unbalance Load Negative Sequence OUT ON LED BO 70 140 2 GI 05165 I2 picked up I2 picked up Unbalance Load Negative Sequence OUT ON OFF LED...

Page 578: ...3 BLOCK frequency protection BLOCK Freq Frequency Protec tion SP LED BI BO 05206 BLOCK stage f1 BLOCK f1 Frequency Protec tion SP ON OF F LED BI BO 70 177 1 GI 05207 BLOCK stage f2 BLOCK f2 Frequency Protec tion SP ON OF F LED BI BO 70 178 1 GI 05208 BLOCK stage f3 BLOCK f3 Frequency Protec tion SP ON OF F LED BI BO 70 179 1 GI 05209 BLOCK stage f4 BLOCK f4 Frequency Protec tion SP ON OF F LED BI ...

Page 579: ...e Cur rent Protection OUT ON OF F LED BO 71 183 1 GI 05306 DC protection picked up DC Prot pick up DC Voltage Cur rent Protection OUT ON OFF LED BO 71 186 2 GI 05307 DC protection TRIP DC Prot TRIP DC Voltage Cur rent Protection OUT ON LED BO 71 187 2 GI 05308 Failure DC protection Failure DC Prot DC Voltage Cur rent Protection OUT ON OF F LED BO 71 184 1 GI 05323 BLOCK underexcitation protection ...

Page 580: ...53 BLOCK overexcitation protection U f BLOCK Overexcitation Pro tection U f SP LED BI BO 05357 Reset memory of thermal replica U f RM th rep U f Overexcitation Pro tection U f SP ON OF F LED BI BO 05361 Overexcitation prot is swiched OFF U f OFF Overexcitation Pro tection U f OUT ON OF F LED BO 71 83 1 GI 05362 Overexcitation prot is BLOCKED U f BLOCKED Overexcitation Pro tection U f OUT ON OF F O...

Page 581: ...ED R E F BLOCKED Rotor Earth Fault Protection OUT ON OF F ON OFF LED BO 71 122 1 GI 05393 Rotor earth fault prot R fn is ACTIVE R E F AKTIVE Rotor Earth Fault Protection OUT ON OF F LED BO 71 123 1 GI 05394 Rot earth flt prot R fn block by U R E F U block Rotor Earth Fault Protection OUT ON OF F LED BO 71 124 1 GI 05395 REF protection 1 3Hz open circuit REF 1 3Hz open Rotor Earth Fault Protection ...

Page 582: ...tator Earth Fault Protection SP ON OF F LED BI BO 71 227 1 GI 05481 S E F 100 protection is switched OFF SEF100 OFF 100 Stator Earth Fault Protection OUT ON OF F LED BO 71 228 1 GI 05482 Stator earth flt prot 100 is BLOK KED SEF100 BLOCKED 100 Stator Earth Fault Protection OUT ON OF F ON OFF LED BO 71 229 1 GI 05483 Stator earth flt prot 100 is ACTIVE SEF100 ACTIVE 100 Stator Earth Fault Protectio...

Page 583: ...e of frequency change protection OUT ON OFF LED BO 72 10 2 GI 05518 Stage df3 dt picked up df3 dt pickup Rate of frequency change protection OUT ON OFF LED BO 72 11 2 GI 05519 Stage df4 dt picked up df4 dt pickup Rate of frequency change protection OUT ON OFF LED BO 72 12 2 GI 05520 Stage df1 dt TRIP df1 dt TRIP Rate of frequency change protection OUT ON LED BO 72 13 2 GI 05521 Stage df2 dt TRIP d...

Page 584: ...th 3 Harm TRIP SEF 3H TRIP Stator Earth Fault Protection 3rdHarm OUT ON M LED BO 72 55 2 GI 05571 BLOCK startup O C protection BLOCK O C St Startup O C protec tion SP LED BI BO 05572 Startup O C protection is switched OFF O C Start OFF Startup O C protec tion OUT ON OF F LED BO 72 62 1 GI 05573 Startup O C protection is BLOCKED O C Start BLK Startup O C protec tion OUT ON OF F ON OFF LED BO 72 63 ...

Page 585: ...IVE Differential Protec tion OUT ON OF F LED BO 75 17 1 GI 05620 Diff adverse Adaption factor CT Diff Adap fact Differential Protec tion OUT ON LED BO 05631 Differential protection picked up Diff picked up Differential Protec tion OUT ON OFF M LED BO 75 31 2 GI 05644 Diff Blocked by 2 Harmon L1 Diff 2 Harm L1 Differential Protec tion OUT ON OFF LED BO 75 44 2 GI 05645 Diff Blocked by 2 Harmon L2 D...

Page 586: ...UT LED BO 75 73 1 GI 05674 Differential protection TRIP L3 Diff TRIP L3 Differential Protec tion OUT LED BO 75 74 1 GI 05681 Diff prot IDIFF L1 without Tdelay Diff L1 Differential Protec tion OUT ON OFF LED BO 75 81 2 GI 05682 Diff prot IDIFF L2 without Tdelay Diff L2 Differential Protec tion OUT ON OFF LED BO 75 82 2 GI 05683 Diff prot IDIFF L3 without Tdelay Diff L3 Differential Protec tion OUT ...

Page 587: ... OFF LED BO 76 12 1 GI 05813 Restricted earth fault is ACTIVE REF ACTIVE Restricted Earth Fault Protection OUT ON OF F LED BO 76 13 1 GI 05817 REF protection picked up REF picked up Restricted Earth Fault Protection OUT ON OFF LED BO 76 17 2 GI 05821 REF protection TRIP REF TRIP Restricted Earth Fault Protection OUT ON LED BO 76 21 2 GI 05836 REF adverse Adaption factor CT REF Adap fact Restricted...

Page 588: ...e Protection OUT ON OFF LED BO 74 98 2 GI 06526 Inv Undervoltage Up char picked up Up ch pick up Inverse Undervol tage Protection OUT ON OFF LED BO 74 99 2 GI 06527 Inverse Undervoltage Up TRIP Up AUS Inverse Undervol tage Protection OUT ON LED BO 74 100 2 GI 06530 Undervoltage protection switched OFF Undervolt OFF Undervoltage Pro tection OUT ON OF F LED BO 74 30 1 GI 06531 Undervoltage protectio...

Page 589: ...BI BO 06811 Starting time supervision switched OFF START SUP OFF Motor Starting Time Supervision OUT ON OF F LED BO 169 51 1 GI 06812 Starting time supervision is BLOCKED START SUP BLK Motor Starting Time Supervision OUT ON OF F ON OFF LED BO 169 52 1 GI 06813 Starting time supervision is ACTIVE START SUP ACT Motor Starting Time Supervision OUT ON OF F LED BO 169 53 1 GI 06821 Starting time superv...

Page 590: ...d Value MV3 picked up Meas Value3 Threshold supervi sion OUT LED BO 07963 Measured Value MV4 picked up Meas Value4 Threshold supervi sion OUT LED BO 07964 Measured Value MV5 picked up Meas Value5 Threshold supervi sion OUT LED BO 07965 Measured Value MV6 picked up Meas Value6 Threshold supervi sion OUT LED BO 14101 Fail RTD broken wire shorted Fail RTD RTD Box OUT ON OF F LED BO 14111 Fail RTD 1 b...

Page 591: ...tage 1 picked up RTD 5 St 1 p up RTD Box OUT ON OF F LED BO 14153 RTD 5 Temperature stage 2 picked up RTD 5 St 2 p up RTD Box OUT ON OF F LED BO 14161 Fail RTD 6 broken wire shorted Fail RTD 6 RTD Box OUT ON OF F LED BO 14162 RTD 6 Temperature stage 1 picked up RTD 6 St 1 p up RTD Box OUT ON OF F LED BO 14163 RTD 6 Temperature stage 2 picked up RTD 6 St 2 p up RTD Box OUT ON OF F LED BO 14171 Fail...

Page 592: ... RTD Box OUT ON OF F LED BO 14211 Fail RTD11 broken wire shorted Fail RTD11 RTD Box OUT ON OF F LED BO 14212 RTD11 Temperature stage 1 picked up RTD11 St 1 p up RTD Box OUT ON OF F LED BO 14213 RTD11 Temperature stage 2 picked up RTD11 St 2 p up RTD Box OUT ON OF F LED BO 14221 Fail RTD12 broken wire shorted Fail RTD12 RTD Box OUT ON OF F LED BO 14222 RTD12 Temperature stage 1 picked up RTD12 St 1...

Page 593: ... Authoriza tion IntSP ON OF F LED Error Systeminterface SysIntErr Protocol IntSP ON OF F LED BO Fault Recording Start FltRecSta Oscillographic Fault Records IntSP ON OF F LED BO Group A Group A Change Group IntSP ON OF F LED BO 70 23 1 GI Group B Group B Change Group IntSP ON OF F LED BO 70 24 1 GI Hardware Test Mode HWTestMod Device IntSP ON OF F LED BO Stop data transmission DataStop Device IntS...

Page 594: ...00626 U L31 UL31 Measure ment CFC CD DD 00627 Displacement voltage UE UE Measure ment 134 147 priv 9 10 CFC CD DD 00629 U1 positive sequence U1 Measure ment 134 147 priv 9 11 CFC CD DD 00630 U2 negative sequence U2 Measure ment CFC CD DD 00639 UE 3rd Harmonic Voltage Minimum UE3h min Min Max Measure ment Setup CFC CD DD 00640 UE 3rd Harmonic Voltage Maximum UE3h max Min Max Measure ment Setup CFC ...

Page 595: ...e ment 134 147 priv 9 3 CFC CD DD 00755 REF 1 3Hz Freq of square wave gen fgen Measure ment CFC CD DD 00757 REF 1 3Hz Volt of square wave gen Ugen Measure ment CFC CD DD 00758 REF 1 3Hz Curr of rotor meas circuit Imeas Measure ment CFC CD DD 00759 REF 1 3 Hz Charge at polarity rev Qc Qc Measure ment CFC CD DD 00760 SEF100 Prim stator earth resistance RSEFp Measure ment CFC CD DD 00761 REF 1 3Hz Fa...

Page 596: ...nce Minimum I1 Min Min Max Measure ment Setup CFC CD DD 00858 Positive Sequence Maximum I1 Max Min Max Measure ment Setup CFC CD DD 00874 U1 positive sequence Voltage Minimum U1 Min Min Max Measure ment Setup CFC CD DD 00875 U1 positive sequence Voltage Maximum U1 Max Min Max Measure ment Setup CFC CD DD 00876 Active Power Minimum PMin Min Max Measure ment Setup CFC CD DD 00877 Active Power Maximu...

Page 597: ...mp unbal load Therm Rep Thermal Measure ment CFC CD DD 00911 Cooling medium temperature AMB TEMP Thermal Measure ment CFC CD DD 00924 Wp Forward Wp Energy CD DD 00925 Wq Forward Wq Energy CD DD 00928 Wp Reverse Wp Energy CD DD 00929 Wq Reverse Wq Energy CD DD 00995 SEF100 Phase angle in stator circuit ϕ SEF Measure ment CFC CD DD 00996 Transducer 1 Td1 Measure ment CFC CD DD 00997 Transducer 2 Td2...

Page 598: ...ment 134 146 priv 9 11 CFC CD DD 01079 Temperature of RTD12 Θ RTD12 Thermal Measure ment 134 146 priv 9 12 CFC CD DD 07740 Phase angle in phase IL1 side 1 ϕIL1S1 Measure ment CFC CD DD 07741 Phase angle in phase IL2 side 1 ϕIL2S1 Measure ment CFC CD DD 07742 IDiffL1 I Inominal object IDiffL1 Diff and Rest Measure ment CFC CD DD 07743 IDiffL2 I Inominal object IDiffL2 Diff and Rest Measure ment CFC...

Page 599: ...0 Diff Diff and Rest Measure ment CFC DD 30655 I0 Rest REF I Inominal object I0 Rest Diff and Rest Measure ment CFC DD 30659 3I0 1 REF I Inominal object 3I0 1 Diff and Rest Measure ment CFC DD 30660 3I0 2 REF I Inominal object 3I0 2 Diff and Rest Measure ment CFC DD IL under current IL Set Points Measu red Values CFC CD DD Number of TRIPs of TRIPs Statistics CD DD Operating hours greater than OpHo...

Page 600: ... User defined messages and switching objects Yes Yes Yes Yes Yes Time synchronization Via protocol DCF77 IRIG B Interface Binary input Via DCF77 IRIG B Interface Binary input protocol Via protocol DCF77 IRIG B Interface Binary input Via DCF77 IRIG B Interface Binary input protocol Messages with time stamp Yes No Yes No Yes Commissioning aids Measured value indica tion blocking Yes No No No Yes Cre...

Page 601: ...ear reader printing errors can never be entirely eliminated therefore should you come across any when read ing this manual kindly enter them in this form to gether with any comments or suggestions for im provement that you may have From Name Company Dept Address Phone no Fax no Corrections Suggestions ...

Page 602: ...bidden with out express authority Offenders are liable to the payment of damages All rights are reserved in the event of the grant of a patent or the registration of a utility model or design Order no C53000 G1176 C149 3 Available from LZF Fürth Bislohe Printed in Germany Imprimé en Allemagne AG 0702 0 1 FO 600 En Siemens Aktiengesellschaft ...

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