7UM62_iec

(1)

SIPROTEC

Multifunction Generator,

Motor and Transformer

Protection Relay

7UM62

V4.1

Manual

C53000-G1176-C149-3

Preface

Introduction

1 Functions

2 Installation and Commissioning

3 Technical Data

4 Appendix

A

(2)

lack of total agreement.

The information in this manual is checked periodically, and necessary corrections will be included in future editions. We appreciate any suggested improvements.

We reserve the right to make technical improvements without notice.

Release V4.10.01

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.

Registered trademarks

SIPROTEC, SIMATIC®, SIMATIC NET®, SINAUT®, SI-CAM®, and DIGSI®are registered trademarks of Siemens AG. Other designations in this manual may be trademarks that if used by third parties for their own purposes may vi-olate the rights of the owner.

(3)

Preface

Purpose of This Manual

This manual describes the functions, operation, installation, and placing into service of the device. In particular, one will find:

• Information regarding customizing of the device and descriptions of device functions and settings→Chapter 2;

• Instructions for mounting and commissioning→Chapter 3; • Instructions for mounting and commissioning→Chapter 4;

• As well as a compilation of the most significant data for experienced users in the Appendix A.

For general information on the operation and configuration of SIPROTEC®4 devices, please refer to theSIPROTEC®4 System Manual (Order No.: E50417–H1176–C151).

Target Audience Protection engineers, commissioning engineers, personnel concerned with

adjustment, checking, and service of selective protective equipment, automatic and control facilities, and personnel of 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 of the member states relating to electromagnetic compatibility (EMC Council Directive 89/336/EEC) and concerning electrical equipment for use within certain voltage limits (Low-voltage Directive 73/23/EEC). This conformity is proved by tests conducted by Siemens AG in accordance with Article 10 of the Council Directive in agreement with the generic standards EN 50081 and EN 50082 for EMC directive, and with the standard EN 60255–6 for the low-voltage directive.

The product conforms with the international standard of the series IEC 60255 and the German standard DIN 57435 /Part 303 (corresponds to VDE 0435/Part 303).

IND. CONT. EQ. TYPE 1

69CA

IND. CONT. EQ. TYPE 1

(4)

Additional Support For questions regarding SIPROTEC®4 devices, please contact your Siemens representative.

Training Courses Individual course offerings may be found in our Training Catalog, or questions can be directed to our training center. Please contact your Siemens representative.

Instructions and Warnings

The following indicators and standard definitions are used:

DANGER

means that death, severe personal injury, or considerable equipment damage will occur if safety precautions are disregarded.

WARNING

means that death, severe personal injury, or considerable equipment damage will occur if safety precautions are disregarded.

Caution

means that death, severe personal injury, or considerable equipment damage will occur if safety precautions are disregarded. This manual describes the functions, operation, installation, and placing into service of the device.

Instruction

is an important piece of information regarding the product or the part of the manual that deserves special attention.

QUALIFIED PERSONNEL

Prerequisites to proper and safe operation of this product are proper transport, proper storage, setup, installation, 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 First aid training.

WARNING

During operation of electrical equipment, certain parts of these devices are under high voltage. Severe personal injury or significant equipment damage could result from improper behavior.

Only qualified personnel should work on this equipment or in the vicinity of this equipment. These personnel must be familiar with all warnings and service procedures described in this manual, as well as with safety regulations.

Prerequisites to proper and safe operation of this product are proper transport, proper storage, setup, installation, 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.

In particular, the general facility and safety regulations for work with high-voltage equipment (e.g. ANSI, IEC, EN, or other national or international regulations) must be observed. Noncompliance may result in death, injury, or significant equipment damage.

(5)

Preface

Typographic and Graphical

Conventions

The following text formats are used to identify concepts giving device information described by the text flow:

Parameter names, or identifiers for configuration or function parameters that appear in the device display or on the screen of a PC (with DIGSI®4) are shown in mono-script (same point size) bold text. This also applies to header bars for selection menus.

Parameter conditions, or possible settings of parameters that appear in the

device display or on the screen of a PC (with DIGSI®4), are additionally shown in italic style. This also applies to header bars for selection menus.

“Annunciations”, or identifiers for information 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 conditionsOnandOff I_L1

GND Fault device-internal (logical) input signal

internal input signal of an analog quantity

>Release

Dev. Trip external binary input signal with function number F# (binary input,

On Off 1234 FUNCTION Parameter address Parameter name Parameter Conditions

example of a parameter switchFUNCTIONwith address1234and

F# F#

external binary input signal with function number F# (binary input,

from device)

respective annunciation to the device)

Input signal of an analog quantity

≥1 & OR gate AND gate Signal inversion OR

(6)

n I2> 1706 I2>> 0 T S R Q

Input signals of dynamic quantity

Formation of one output signal from a number of analog inputs

Timer (dropout delayed)

Limit stage 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 bothinputs 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

(7)

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

(18)

1.1 Overall Operation

The SIPROTEC®4 7UM62 is a numerical, multi-functional, protective and control device equipped with a powerful microprocessor. All tasks, such as the acquisition of the measured quantities, issuing of commands to circuit breakers and other primary power system equipment, are processed in a completely digital way. Figure 1-1 illustrates the basic structure of the 7UM62.

Analog Inputs The measuring inputs (MI) section consists of current and voltage transformers. They convert the signals from the primary transformers to 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 U_aux. up to 15 Binary Inputs, Power Supply

MI

IA

AD

µC

AV

Figure 1-1 Hardware Structure of the Numerical Device 7UM62 (Maximum Configuration)

Status PC/ Modem Programmable

µC

∩

#

Error Run Output Relays, User-Programmable LEDs on the Front Panel, User-Programmable Display on Front Operator Interface System Serial Interface I_{L1, S1} I_{L2, S1} I_{L3, S1} I_EE1 U_L1 U_L2 U_L3 7 8 9 4 5 6 1 2 3 . 0 +/-ESC ENTER Rear Service Interface U_N I_EE2 I_{L1, S2} I_{L2, S2} I_{L3, S2} 3 Measuring Transducers Analog Outputs the Front Panel

Analog pro-cessing

~

(19)

1.1 Overall Operation

equipped with sensitive input transformers (I_EE) and can measure secondary currents in the mA range.

A voltage measuring input is provided for each phase-earth voltage (connection to phase-to-phase voltages and voltage transformers in V connection is possible as well). A further voltage input (U_N) may optionally be used to measure either the displacement voltage or any other voltage U_X(for injected voltage of rotor protection). The analog-to-digital (AD) stage consists of memory components, a multiplexer, and an multichannel analog-to-digital converter. The A/D converter processes the analog signals from the IA stage. The digital signals from the converter are input to the microcomputer system where they are processed as numerical values in the residing algorithms.

Microcomputer System

The actual protection and control functions of the 7UM62 are processed in the microcomputer system (µC). Specifically, the µC performs:

− Filtering and preparation of the measured quantities − Permanent supervision of the measured quantities

− Monitoring of the pickup conditions for the individual protection functions − Evaluation of limit values and sequences in time

− Control of signals for the logic functions − Decision for trip commands

− Signalling of protection behaviour via LED, LCD, relay or serial interface

− Recording of messages and data for events, alarms, faults, 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 are always processed with algorithms matched to the actual frequency. Thus, a wide frequency range from 11 Hz to 69 Hz is specified with small frequency influence.

The sampling frequency adaptation can, however, operate only when at least one a.c. measured quantity is present at one of the analog inputs, with an amplitude of at least 5 % of rated value (“operational condition 1”).

If no suitable a.c. measured values are present, or if the frequency is below 11 Hz or above 70 Hz, the relay operates in mode “operational condition 0” (refer to Section 4.34).

Binary Inputs and Outputs

The µC obtains external information through the binary inputs such as blocking commands for protective functions or position indications of circuit breakers. The µC issues commands to external equipment via the output contacts. These output commands are generally used to operate circuit breakers or other switching devices. They can also be connected to other protective devices, annunciators, or external carrier equipment for use in Pilot-Relaying schemes.

Front Elements Light-emitting diodes (LEDs) and a display screen (LCD) on the front panel provide information such as messages related to events and functional status of the 7UM62.

(20)

Integrated control and numeric keys in conjunction with the LCD facilitate local interaction with the 7UM62. All information of the device can be accessed using the integrated control and numeric keys. The information includes protective and control settings, operating and fault messages, and metering values (see also SIPROTEC® 4–System Manual). The settings can be modified; the procedures are discussed in Chapter 2.

Serial Interfaces A serial operator interface (PC port) on the front panel is provided for local

communications with the 7UM62 through a personal computer. Convenient operation of all functions of the device is possible using the SIPROTEC®4 operating program DIGSI®4.

A separate serial service interface is provided for remote communications via a modem, or local communications via a substation master computer that is permanently connected to the 7UM62. DIGSI®4 is required.

All 7UM62 data 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.

Analog Outputs/ Temperature Input

Depending on the ordering variant and configuration, Port B and D can be equipped with analog output modules for the output of selected measured values (0 to 20 mA). If these ports are equipped with input modules (RS485 or optical) instead, tempera-tures can be fed in from an external temperature detection unit.

Power Supply The 7UM62 can be supplied with any of the common power supply voltages from 24 VDC to 250 VDC. The device can also be supplied with 115 VAC. Momentary dips of the supply voltage up to 50 ms are bridged by a capacitor (see Technical Data, Sub-section 4.1.2). Voltage dips can occur, for example, if the voltage supply system (substation battery) becomes short-circuited or experiences a severe variation in load.

(21)

1.2 Applications

1.2 Applications

SIPROTEC®7UM62 is a numerical machine protection unit from the “7UM6 Numerical Protection series”. It provides all functions that are necessary for the protection of generators, motors and transformers. As the scope of functions of the 7UM62 can be customized, it is suited for small, medium-sized and large generators. It provides the scope of protection functions for the two typical basic applications: • Bus-bar connection

• Unit connection

Figure 1-2 Typical Basic Connections

The integrated differential protection function can be used for longitudinal or

transverse generator differential protection, for protection of the unit transformer or for overall differential protection.

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 (further device of the 7UM6 protection series), all protection requirements encountered for the smallest to the largest machines can be met. This permits to implement a consistent concept for backup protection.

Further applications are

• Transformer protection, as the 7UM62 has in addition to differential and overcurrent protection a large variety of protection functions that allow, for instance, monitoring of the voltage and frequency load.

• Protection of large synchronous and asynchronous motors.

7UM62

G

Busbar connection Unit connection

7UM62

G

(22)

Messages and Measured Values; Storage of Data for Fault Recordings

A series of operating messages provides information about conditions in the power system and the 7UM62 itself. Measurement quantities and values that are calculated can be displayed locally and communicated via the serial interfaces.

Messages of the 7UM62 can be indicated by a number of programmable LEDs on the front panel, externally processed through programmable output contacts, and communicated via the serial interfaces (see “Communication” below). With the help of the CFC graphic tool (Continous Function Chart), user-defined annunciations and logical combinations of internal or external signals can also be generated.

During a network fault (fault in the power system), important events and state changes are stored in a fault annunciation buffer. The instantaneous measured values during the fault are also stored in the device and are subsequently available for fault analysis.

Communication Serial interfaces are available for communications with external operating, control, and storage systems.

Operator Interface on Front Panel

A serial operator interface on the front panel is provided for local communications with the through a personal computer. All of the operating and evaluation processes can be done via this operator interface using 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 Further interfaces are located on the back of the 7UM62 — dependent on the version of the device. Comprehensive communications are possible between these interfaces and other digital equipment used for operating, control, and data storage.

The service interface can be operated through data lines. Also, a modem can be connected to this port. Servicing of the substation or plant is possible from a remote computer with DIGSI®4.

The system interface is for central communications between the 7UM62 and a control station. The service interface can be operated through data lines or optical fibres. Several standard protocols are available:

− IEC 60870–5–103

Integration of the devices into the automation systems SINAUT®LSA and SICAM® also take place with this profile.

− Profibus DP

This protocol of automation technology allows to transmit annunciations and measured values.

− Modbus ASCII/RTU

− DNP 3.0

− It is also possible to provide an analog output (2 x 20 mA) for the output of measured values.

(23)

1.3 Features

1.3 Features

General Features • Powerful 32-bit microprocessor system.

• Complete digital processing of measured values and control, from the sampling of the analog input quantities to the initiation of outputs for, as an example, tripping circuit breakers or other switch-gear devices.

• Complete galvanic and reliable separation between the internal processing circuits of the 7UM62 and the external measurement, control, and DC supply circuits because of the design of the analog input transformers, binary inputs and outputs, and the DC converters.

• Simple device operation using the integrated operator panel or by means of a connected personal computer running DIGSI®4.

• Continuous calculation and display of measured quantities.

• Constant monitoring of the measurement quantities, as well as continuous self-diagnostics covering the hardware and software.

• Storage of operational data, fault data, and oscillographic fault records with information to be used for analysis and troubleshooting.

• Communication with central control and data storage equipment via serial

interfaces through the choice of data cable, modem, or optical fibers, as an option. • Battery-buffered real time clock that can be synchronized with an IRIG-B (or

DCF77) signal, binary input 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 record.

Definite-Time-Overcurrent Protection (I>) with Undervoltage Seal-In

• Two instantaneous (Definite-Time) overcurrent elements for phase protection; • Undervoltage seal-in for synchronous machines, the excitation voltage of which is

derived from the machine terminals;

• Optionally additional directional determination with theI>>–stage; • Blocking capability for reverse-interlocking bus-bar protection.

Inverse-Time-Overcurrent Protection

• Common ANSI and IEC time overcurrent curves are available;

• Optionally voltage controlled or voltage restraint alteration of pick-up value during undervoltage;

• Undervoltage influence can be blocked by fuse failure monitor or via binary input, e.g. by a voltage transformer m.c.b.

Thermal Overload Protection

• Temperature rise of the protected equipment is calculated using a thermal homogeneous model that takes into account energy entering the equipment and energy losses. Thermal overload protection has full memory capability;

• Adjustable warning levels based on temperature rise and current magnitude; • input of cooling medium or ambient temperature possible.

(24)

Unbalanced Load Protection

• Evaluation of negative sequence component of the three phase currents; • Alarm stage when a set unbalanced load is exceeded;

• Thermal replica for rotor temperature rise with adjustable negative sequence factor K and adjustable time for cool down;

• High-speed trip stage for large unbalanced loads (can be used for short-circuit protection).

Startup Overcurrent Protection

• I> stage for lower speed ranges (e.g. startup of generators with frequency starting converter).

Differential Protection

Used for generator, motor or transformer differential protection • Tripping characteristic with current restraint;

• High degree of sensitivity;

• Insensitivity to DC components and current transformer saturation; • High degree of stability even with different degrees of CT saturation; • Restraint feature against high inrush currents with 2nd harmonics;

• Restraint feature against transient and steady-state fault currents with 3rd or 5th harmonics;

• 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 measures against overfunction at external faults.

Underexcitation Protection

• Conductance measurement from positive sequence components; • Multi-step characteristic for steady-state and dynamic stability limits; • Detection of the excitation voltage.

Reverse Power Protection

• Calculation of power from positive sequence components;

• Highly sensitive active power measurement (detection of small motoring powers even with small power factor cosϕ, angle error correction);

• Insensitive to power swings;

• Independent long-time stage and short-time stage with stop valve tripped.

Forward Power Supervision

• Calculation of power from positive sequence components;

• Supervision of over-power (P>) and/or under-power (P<) with individually adjustable power limits;

(25)

1.3 Features

Impedance Protection

• Phase selective overcurrent fault detection with undervoltage seal-in (for synchronous machines which take their excitation voltage from the terminal voltage);

• 2 impedance zones, 1 overreach zone for zone extension (controlled via binary input), 4 time stages;

• Polygonal tripping characteristics; • Additional power swing blocking.

Out-of-Step Protection

• Based on the well-proven impedance measurement method;

• Measurement release by the positive sequence current, and measurement blocking by the negative sequence current;

• Evaluation of the rate of change of the complex impedance vector; • Optimum matching to the system conditions by selectable slope of the

characteristic;

• Reliable distinction between the power swing centre being in the system or in the generator unit area.

Undervoltage Protection

• Two undervoltage elements, measuring positive sequence voltage. • Additional stage with 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 phase angle changes; • Adjustable undervoltage blocking.

Overexcitation Protection

• Calculation of the ratio U/f;

• Adjustable warning and tripping stage;

• Standard characteristic or either optional characteristic selectable for calculation of the thermal stress.

Rate-of-Frequency-Change Protection

• Monitors whether the frequency exceeds (df/dt>) and/or falls below (df/dt<) a set limit value, with 4 individually settable limit values or delay times;

• Variable measuring windows;

• Coupling to frequency protection pickup; • Settable undervoltage threshold.

Jump of Voltage Vector

• Sensitive phase jump detection to be used for network disconnection.

90–%–Stator Earth Fault Protection

(26)

• Measurement of displacement voltage at the machine via the neutral transformers or earthing transformer or by calculation from phase-to-earth voltages;

• Highly sensitive earth current detection, optional with or without directional determination with zero sequence components (I₀, U₀);

• With adjustable slope of directional characteristic; • Discrimination of the earth-faulted phase.

Sensitive Earth Current Protection

• Two sensitive earth fault instantaneous overcurrent elements: I_EE>> and I_EE>; • Pickup currents are adjustable and can be set very sensitive (as low as 2 mA); • Can be used for stator earth fault or rotor earth fault detection;

• Measured circuit monitoring when used for rotor earth fault protection.

100–%–Stator Earth Fault Protection with 3rd Harmonics

• Detection of the 3rd harmonic of the voltage at the starpoint or open delta winding of an earthing transformer;

• In addition to the 90-%-stator earth fault protection there is a protection of the entire stator winding (protective range 100 %).

100–%–Stator Earth Fault Protection with 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 earth impedances and brush resistances; • Calculation of the fault resistance from the total impedance;

• Alarm stage and tripping stage directly adjustable in Ohms (rotor-earth resistance); • Measurement circuit supervision with alarm output.

Sensitive Rotor Earth Fault Protection with 1 to 3 Hz Square Wave Voltage Injection

• Evaluation of the 1 to 3 Hz square-wave voltage injected into the rotor circuit (7XT71);

• Warning and trip stage R< and R<<; • High sensitivity (max. 80 KΩ); • Integrated test function.

Motor Starting Time Supervision

• Current dependent tripping based on an evaluation of the motor starting current; • Blocked rotor protection.

Restart Inhibit for Motors

• Rotor temperature is calculated based on the stator currents;

• Start-up is permitted only if the rotor has sufficient thermal reserves for a complete start-up;

(27)

1.3 Features

• Different prolongation of cool-down time constants for rest/operation period is taken into consideration;

• Disabling of the start inhibit is possible if an emergency start-up is required.

Breaker Failure Protection

• Breaker failure condition determined by current flow after a trip signal has been issued, or the breaker position indication (binary input) can be evaluated; • Breaker failure protection initiated by the tripping of any integrated protective

element that trips the circuit breaker (internal start);

• Initiation possible through a binary input from an external protective device (external start).

Inadvertent Energization

• The inadvertent accidental energizing protection serves to limit damages by accidental connection of the standing generator by a fast actuation of the generator breaker;

• Evaluation of negative sequence component of the three phase currents; • Released by operational condition check, undervoltage supervision, and fuse

failure monitor.

DC 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 (depending on the variant ordered).

Threshold Supervision

• 6 freely assignable indications for threshold supervision; • Realization of fast supervision tasks with CFC.

Temperature Detection Using Thermoboxes

• Detection of any ambient or coolant temperature using external thermoboxes and external temperature detectors (RTDs).

Phase Rotation Changing

• Selectable L1, L2, L3 or L1, L3, L2 with a setting (static) or binary input (dynamic).

User-Defined Functions

• Internal and external signals can be logically combined to establish user-defined logic functions;

• All common logic functions are available for programming (AND, OR, NOT, Exclusive OR, etc.);

• Time delays and limit value inquiries are available;

• Processing of measured values, including zero suppression, adding a knee characteristic for a transducer input, and live-zero monitoring.

(28)

Breaker Control • Circuit breakers can be opened and closed via the programmable function keys on the front panel, through the SCADA, or through the front operator interface using a personal computer with DIGSI®4);

• Circuit breakers are monitored via the breaker auxiliary contacts;

• Plausibility monitoring of the circuit breaker position and check of interlocking 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 circuits, power supply, hardware, and software;

• Current transformer and voltage transformer secondary circuits are monitored using summation and symmetry check techniques;

• Trip circuit monitoring; • Phase Rotation.

(29)

Functions

2

This chapter describes the numerous functions available on the SIPROTEC®7UM62 relay. The setting options for each function are explained, including instructions to determine setting values and formulae where required.

2.1 Introduction, Reference Power System 16

2.2 Functional Scope 18

2.3 Power System Data 1 27

2.4 Setting Groups 35

2.5 Power System Data 2 36

2.6 Definite-Time Overcurrent Protection (I>, ANSI 50/51) with Undervoltage

Seal-In 38

2.7 Definite-Time Overcurrent Protection (I>>, ANSI 50, 51, 67) with Direction

Detection 42

2.8 Inverse-Time Overcurrent Protection (ANSI 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 Supervision (ANSI 32F) 119

2.17 Impedance Protection (ANSI 21) 122

2.18 Out-of-Step Protection (ANSI 78) 137

2.19 Undervoltage Protection (ANSI 27) 148

2.20 Overvoltage Protection (ANSI 59) 151

2.21 Frequency Protection (ANSI 81) 154

2.22 Overexcitation (Volt/Hertz) Protection (ANSI 24) 159 2.23 Inverse-Time Undervoltage Protection (ANSI 27) 164 2.24 Rate-of-Frequency-Change Protection df/dt (ANSI 81R) 167

(30)

2.26 90–%–Stator Earth Fault Protection (ANSI 59N, 64G, 67G) 177 2.27 Sensitive Earth Fault Protection (ANSI 51GN, 64R) 185 2.28 100–%–Stator Earth Fault Protection with 3rd Harmonics (ANSI 27/59TN

3rd Harm.) 189

2.29 100–% Stator Earth Fault Protection with 20 Hz Voltage Injection (ANSI 64G

- 100%) 194

2.30 Rotor Earth Fault Protection R, fn (ANSI 64R) 201 2.31 Sensitive Rotor Earth Fault Protection with 1 to 3 Hz Square Wave 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 Threshold Supervision 261

2.41 External Trip Coupling 267

2.42 Temperature Detection by Thermoboxes 270 2.43 Inversion of Phase Sequence (Phase Sequence Reversal) 279

2.44 Protection Function Logic 281

2.45 Auxiliary Functions 286

(31)

Regionalization The SIPROTEC®7UM62 protective relays are offered in regional versions. The user should purchase only the functional scope that is needed. The prepared functions are adapted to the technical requirements of the regions.

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 characteristic curves X – X

(32)

2.1 Introduction, Reference Power System

The following chapters explain the individual protective and additional functions and provide information about on the setting values.

Generator The calculation examples are based on two reference power systems with the two typical basic connections, i.e. the busbar connection and the unit connection (see Figure 2-1). 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 U_E I_{L, S2} I_EE1 U_L 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 I_{L, S2} IEE U_LU_E 500 A/1 A 5.27 MVA 6.3 kV _{6.3 kV} √3 100 V √3 3∼ 100 V 3 60/1 A R_L Earthing trans-G 3∼ I_{L, S1} I_{L, S1} Side 2 Side 1 Side 2 Side 1 former

(33)

Introduction, Reference Power System Technical Data of the Reference Power Systems Generator: S_{N, G} = 5.27 MVA U_{N, G} = 6.3 kV I_{N, G} = 483 A cosϕ = 0.8

Current transformer: I_N,prim = 500 A; I_{N, sec}= 1 A Toroidal current transformer I_N,prim = 60 A; I_{N, sec}= 1 A

Voltage transformer: U_{N, prim} = (6.3/√3) kV U_{N, sec}= (100/√3) V U_en/3= (100/3) V

Transformer Transformer: S_{N, T} = 5.3 MVA

U_prim = 20 kV U_sec = 6.3 kV u_sc = 7 % Neutral transformer Resistor divider: 5 : 1 Motor Motor: U_{N, M} = 6600 V I_{N, M} = 126 A

I_START = 624 A (Startup current)

I_max = 135 A (Admissible continuous stator current) T_START = 8,5 s (Duration of startup with I_START) Current transformer: I_N,prim = 200 A; I_{N, sec}= 1 A

Further technical data is provided within the framework of the functional setting specifications 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 the specification of primary values is performed as a setting related to the nominal quantities of the object to be protected (I_{N, G}; U_{N, G}; S_{N, G}). This procedure has the advantage that system-independent, typical settings of the protective functions can be pre-specified. The data of the individual power system are updated in the power system data (see sections 2.3 and 2.5) and the conversion to secondary values is executed via a mouse click. All necessary conversion formula of the individual functions are stored in the operating program.

6.3 kV

(34)

2.2 Functional Scope

2.2.1 Description

General The 7UM62 has numerous protective and additional functions. The hardware and firmware provided is designed for this scope of functions. Nevertheless a few restrictions apply to the use of the earth fault current and earth fault voltage inputs U_E and I_EErespectively. It is not possible to feed different measured quantities to one and the same input, i.e. to use the input, for example, for both rotor and stator earth fault protection. Table 2-2 gives an overview of the protective functions and the inputs they use.

The command functions can be matched to the plant conditions. In addition, individual functions can be activated or deactivated during the configuration procedure, so that functions that are not needed can be disabled.

The available protective and additional functions can be configured asEnabledor

Disabled. For individual functions, the choice between several alternatives may be presented, as described below.

Functions that are configured asDisabledare not processed by the 7UM62: There are no messages, and corresponding settings (functions, limit values) are not displayed during detailed settings.

Determination 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 read, but cannot be modified and transmitted to the device.

The functional scope with the available options is set in theDevice Configuration dialog box to match plant requirements.

2.2.2 Setting Hints

Special Cases Most settings are self-explanatory. The special cases are described below.

If the setting group change-over function is to be used, the setting in address0103 Grp Chge OPTIONmust be set toenabled. In this case, it is possible to apply two groups of settings for the function parameters (refer also to Section 2.4) so that a convenient and fast switch-over between these setting groups is possible. The setting

Disabledimplies that only one function parameter setting group can be applied and used.

Note:

The functions and default settings depend of the variant ordered (for details refer to Table 2-1 and Appendix A.1). Also, not all combinations of protective functions are possible because of certain restrictions imposed by the hardware (see Table 2-2, “Allocation of Device Inputs to Protection Functions”).

(35)

Functional Scope

Parameter0104 FAULT VALUEis used to specify whether the oscillographic fault recording should recordInstantaneous valuesorRMS values. IfRMS values are recorded, the available recording time increases by the factor 16.

For some protective functions you can also choose the measuring inputs of the relay to which they will be allocated (side 1 or side 2); for other functions the allocation is fixed (see Table 2-2).

For example, address0112 O/C PROT. I>allows such a choice for the I> stage of the overcurrent protection (=Side 1,Side 2orDisabled).

For the high-current stage I>> of the overcurrent protection, address0113 O/C PROT. I>>allows non-directional operation for side 1/side 2 or directional operation for side 1/side2. By settingDisabled, this overcurrent stage can be excluded altogether. For the inverse time overcurrent protection set in address0114 O/C PROT. Ip, different sets of inverse characteristics are available, depending on the version ordered; they are either according to IEC or according to ANSI. This function, too, can be allocated to either side 1 or side 2 (=with IEC-characteristic on

side 1,with ANSI-characteristic on side 1,with

IEC-characteristic on side 2,with ANSI-characteristic on side 2).

Inverse time overcurrent protection can be excluded altogether by settingDisabled. 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 available for rotor earth fault protection (R, fn) (see also Table 2-3). The same restrictions are true for measuring transducer inputs, which can only be used by one protection function at a time. Where the TDs are not used by any protection function, they are available for general processing by the measured value blocks in CFC.

Table 2-2 Allocation of Device Inputs to Protection Functions

Protection Function ANSI

Side 1 Side 2 U_L1; U_L2; U_L3 I_L1S1; I_L2S1; I_L3S1 I_EE1 U_E I_L1S2; I_L2S2; I_L3S2 I_EE2 TD

Definite-time I>; I>>

/non-directional ANSI 50

Fixed Selectable - - Selectable -

-Definite-Time I>>/directional Fixed Selectable - - Selectable -

-Inverse-Time Overcurrent Protection

ANSI 51, 67

Fixed Selectable - - Selectable -

-Thermal Overload Protection ANSI 49 - - - - Fixed - TD2

Negative Sequence Protection ANSI 46 - - - - Fixed -

-Startup Overcurrent Protection ANSI 51 - - - - Fixed -

-Differential Protection ANSI 87 - Fixed - - Fixed -

-Earth Fault Differential Protection

ANSI 87GN/TN

U0 calcu-lated

Selectable - - Selectable Fixed

-Underexcitation (Loss-of-Field) Protection

ANSI 40 Fixed - - - Fixed - TD3

Reverse Power Protection ANSI 32R Fixed - - - Fixed -

-Forward Active Power Supervision

(36)

-Impedance Protection ANSI 21 Fixed - - - Fixed -

-Out-of-Step Protection ANSI 78 Fixed - - - Fixed -

-Undervoltage Protection ANSI 27 Fixed - - -

-Overvoltage Protection ANSI 59 Fixed - - -

-Frequency Protection ANSI 81 Fixed - - Fixed -

-Overexcitation (Volt/Hertz) Protection ANSI 24 Fixed - - - -Inverse-Time Undervoltage Protection ANSI 27 Fixed - - - -Rate-of-Frequency-Change Protection ANSI 81R Fixed - - -

-Jump of Voltage Vector Fixed - - -

-90–%–Stator Earth Fault Protection ANSI 59N, 64G, 67G U0 calculated if REFP is used - - - - Fixed

-Sensitive Earth Fault Protection ANSI

51GN, 64R

- - Sele

ct.

- - Select.

-100–%–Stator Earth Fault Prot. with 3rd Harmonics

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,

49_Rotor

- - - - Fixed -

-Breaker Failure Protection ANSI 50BF - Selectable - - Selectable -

-Inadvertent Energization ANSI 50/27 Fixed - - - Fixed -

-DC Voltage/-DC Current Protection ANSI 59N DC/51N DC - - - TD1

Fuse Failure Monitor Fixed - - - Fixed -

-Trip Circuit Monitoring ANSI 74TC - - -

-Threshold Supervision Fixed - - - Fixed -

-External Trip Commands - - -

-Table 2-2 Allocation of Device Inputs to Protection Functions

Protection Function ANSI

Side 1 Side 2 U_L1; U_L2; U_L3 I_L1S1; I_L2S1; I_L3S1 I_EE1 U_E I_L1S2; I_L2S2; I_L3S2 I_EE2 TD

(37)

Functional Scope

For the differential protection, address0120 DIFF. PROT.allows to specify the type of protected object (Generator/Motoror3-phase Transformer); the function can be excluded altogether by settingDisabled.

Figure 2-2 Use as Generator 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

Address0120 DIFF. PROT. =

Generator/Motor

7UM62 G 3∼

Side 2 Side 1

Address0120 DIFF. PROT. =

3-phase Transformer

7UM62 G

3∼

Side 1

Address0120 DIFF. PROT. = 3-phase Transformer

7UM62_iec

SIPROTEC

Multifunction 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

Preface

DANGER

WARNING

Caution

WARNING

Table of Contents

Introduction

1

1.1

Overall Operation

MI

IA

AD

µC

AV

µC

∩

#

~

1.2

Applications

7UM62

G

7UM62

G

1.3

Features

Functions

2

2.1

Introduction, Reference Power System

2.2

Functional Scope

2.2.1

Description

2.2.2

Setting Hints