siemens siprotec 5 catalog ed3.0

SIPROTEC 5 for every application and requirement

www.siemens.com/siprotec

SIPROTEC 5 DevicesProtection, Automation and MonitoringCatalog SIPROTEC 5.01 Edition 3

2 SIPROTEC 5 Devices Protection, Automation and Monitoring Siemens SIPROTEC 5.01 Edition 3

SIPROTEC 5 catalog

The catalog describes the system features and the devices of SIPROTEC 5.

Selection guide for SIPROTEC and Reyrolle

The selection guide offers an overview of the device series of the Siemens protection devies, and a device selection table.

Device manuals

The device manuals describe the functions and applications of a speci c SIPROTEC 5 device. The printed manual and the online help for the device have the same informational structure.

Hardware manual

The hardware manual describes the hardware components and device combinations of the SIPROTEC 5 device family.

Operating manual

The operating manual describes the basic principles and procedures for operating and assembling the devices of the SIPROTEC 5 device family.

Communication protocol manuals

The communication protocol manuals include a description of speci c protocols for communication within the SIPROTEC 5device family and with higher-level control centers.

Product information

The product information includes general information about device installation, technical data, limit values for input and output modules, and conditions when preparing for operation. This document is provided with each SIPROTEC 5 device.

Engineering Guide

The Engineering Guide describes the important steps of Engi-neering with DIGIS 5. The Engineering Guide offers information on how to load a con guration to a SIPROTEC 5 device and how to update the device functionality of a SIPROTEC 5 device.

DIGSI 5 online help

The DIGSI 5 online help contains a help package for DIGSI 5 and CFC. The help package for DIGSI 5 includes a description of the basic operation of software, the DIGSI principles and editors. The help package for CFC includes an introduction to CFC programming, basic examples of working with CFC, and a reference chapter with all the CFC blocks available for the SIPROTEC 5 range.

Online help devices

The online help for devices has the same information structure as the device manual.

SIPROTEC 5 / DIGSI 5 Tutorial

The tutorial on the DVD contains brief information about important product features, more detailed information about the individual technical areas, as well as operating sequences with tasks based on practical operation and a brief explanation of SIPROTEC 5 and DIGSI 5.

Overview of documentation

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3SIPROTEC 5 Devices Protection, Automation and Monitoring Siemens SIPROTEC 5.01 Edition 3

Contents

SIPROTEC 5 DevicesProtection, Automation and MonitoringCatalog SIP 5.01 Edition 3

Invalid: Edition 2

SIPROTEC 5 System 1

Editorial / SIPROTEC 5 System 1.1

Innovation Highlights 1.2

Functional Integration 1.3

Hardware 1.4

Engineering 1.5

Communication 1.6

IEC 61850 Simply Usable 1.7

Test and Diagnostics 1.8

Safety Concept 1.9

Devices 2

Device Types 2.1

Relay Selection Guide 2.2

Application Examples 2.3

Overcurrent Protection SIPROTEC 7SJ82, 7SJ85 2.4

Line Protection

Distance protection SIPROTEC 7SA82, 7SA86, 7SA87

Line differential protection SIPROTEC 7SD82, 7SD86, 7SD87

Combined line differential and distance protection SIPROTEC 7SL82, 7SL86, 7SL87

Breaker management SIPROTEC 7VK87

Overcurrent protection SIPROTEC 7SJ86

2.5

Transformator Protection SIPROTEC 7UT82, 7UT85, 7UT86, 7UT87 2.6

Motor Protection SIPROTEC 7SK82, 7SK85 2.7

Busbar Protection SIPROTEC 7SS85 2.8

Bay Controller SIPROTEC 6MD85, 6MD86 2.9

Fault Recorder SIPROTEC 7KE85 2.10

Appendix 3

DIGSI 5 Variants and System Requirements 3.1

Connection Variants 3.2

Connection Diagrams 3.3

Grouping Measured Values 3.4

Technical Data 3.5

Spare Parts /Accessories 3.6

Legal Notice 3.7

The products and systems described in this catalogare manufactured and sold according to a certi edmanagement system (acc. to ISO 9001, ISO 14001and BS OHSAS 18001).

1.1 /4 SIPROTEC 5 Devices Protection, Automation and Monitoring Siemens SIPROTEC 5.01 Edition 3

The SIPROTEC 5 System

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Editorial

SIPROTEC has been a recognized brand leader in digital protec-tion and eld devices on the energy market for decades. The Siemens high-performance SIPROTEC devices cover the entire power spectrum and can be implemented in a wide range of elds from power generation to very high voltage transmis-sion and distribution network applications.

Smart automation for transmission grids is the Siemens response to the present and future challenges to achieve a reliable and ef cient energy supply. SIPROTEC 5 is an active component of the energy-ef cient smart grid and an important building block in the complex distributed energy supply systems and networks solutions.

The next generation of SIPROTEC devices, SIPROTEC 5, is based on the proven features of SIPROTEC 4 to provide you with a new, modern platform including both hardware and software. This platform offers an excellent solution to the challenges associated with evolving grid structures and work ows. The quality, reliability and proven functions of the former system have been preserved. Innovative approaches including holistic work ow, safety and security, and network stability monitoring (PMU functionality) have been added.

The pioneering system architecture places you in full control of switchgear communications. A powerful, reliable communica-tion infrastructure, combined with the exible engineering capabilities serves as the basis for monitoring and controlling of distributed, decentralized systems. Seamless communications is the central component of the SIPROTEC 5 system architecture to provide exibility, safety and security in the automated distributed network solutions.

With SIPROTEC 5, you are at the beginning of a new generation of intelligent, digital multifunction eld devices. The new operating tool DIGSI 5 offers individual support for you handles your speci c work ow requirements, from system design to device selection and testing, covering the entire device lifecycle. The new tool offers cost savings over the entire lifecycle without compromising safety and system availability.

With the new SIPROTEC 5 generation, you are well equipped to meet the growing economic and reliability demands imposed on your networks. The philosophy of SIPROTEC 5 is re ected in the modularity and exibility of its hardware and software components. Perfectly tailored t the custom t for your switchgear and speci cations for the application and standard-ization of energy automation.

Ingo Erkens

General ManagerEnergy ManagementEnergy Automation Products

Introduction

1.1/5SIPROTEC 5 Devices Protection, Automation and Monitoring Siemens SIPROTEC 5.01 Edition 3


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Solutions for todays and future power supply systems for more than 100 years

SIPROTEC has established itself on the energy market for decades as a powerful and complete system family of numerical protection relays and bay controllers from Siemens.

SIPROTEC protection relays from Siemens can be consistent-ly used throughout all applications in medium and high voltage. With SIPROTEC, operators have their systems rmly and safely under control, and have the basis to implement cost-ef cient solutions for all duties in modern, intelligent and smart grids. Users can combine the units of the different SIPROTEC device series at will for solving manifold duties because SIPROTEC stands for continuity, openness and future-proof design.

As the innovation driver and trendsetter in the eld of protection systems for 100 years, Siemens helps system operators to design their grids in an intelligent, ecological, reliable and ef cient way, and to operate them economic-ally. As a pioneer, Siemens has decisively in uenced the de-velopment of numerical protection systems (Fig. 1.1 /2). The rst application went into operation in Wrzburg, Germany, in 1977. Consistent integration of protection and control functions for all SIPROTEC devices was the innovation step in the 90ies. After release of the communication standard IEC 61850 in the year 2004, Siemens was the rst manufac-turer worldwide to put a system with this communication standard into operation. In the meantime we have delivered more than 400,000 devices with IEC 61850 included.

SIPROTEC protection relays have approvals from many users for use in their power systems. The devices have also been certi ed by independent test institutes and universities (KEMA, EPRI, LOYD, UR Laboratories).

How can system operators bene t from this experience?

Proven and complete applications

Easy integration into your system

Highest quality of hardware and software

Excellent operator friendliness of devices and tools

Easy data exchange between applications

Extraordinary consistency between product and system-engineering

Reduced complexity by easy operation

Siemens as a reliable, worldwide operating partner.

Youll nd the information of the SIPROTEC 4 devices and the devices of SIPROTEC Compact in the subcatalogsor under: www.siemens.com/siprotec

Fig. 1.1 /2 SIPROTEC Pioneer over generations

Fig. 1.1/1 SIPROTEC family

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SIPROTEC 5 the new benchmark for protection, automation and monitoring of grids

The SIPROTEC 5 series is based on the long eld experience of the SIPROTEC device series, and has been especially designed for the new requirements of modern systems. For this purpose, SIPROTEC 5 is equipped with extensive functionalities and device types. With the holistic and consistent engineering tool DIGSI 5, a solution has also been provided for the increasingly complex processes, from the design via the engineering phase up to the test and operation phase.

Thanks to the high modularity of hardware and software, the functionality and hardware of the devices can be tailored to the requested application and adjusted to the continuously chang-ing requirements throughout the entire life cycle.

Besides the reliable and selective protection and the complete automation function, SIPROTEC 5 offers an extensive database for operation and monitoring of modern power supply systems. Synchrophasors (PMU), power quality data and extensive operational equipment data are part of the scope of supply.

Powerful protection functions guarantee the safety of the system operators equipment and employees

Individually con gurable devices save money on initial investment as well as storage of spare parts, maintenance, expansion and adjustment of your equipment

Arc protection, detection of transient ground fault and process bus simply integrable and retro ttable

Clear and easy-to-use of devices and software thanks to user- friendly design

Increase of reliability and quality of the engineering process

High safety by consistent implementation of Safety and Security

Powerful communication components guarantee safe and effective solutions

Full compatibility between IEC 61850 Editions 1 and 2

Integrated switch for low-cost and redundant optical and electrical Ethernet rings

Ethernet redundancy protocols RSTP, PRP and HSR for highest availability

Ef cient operating concepts by exible engineering of IEC 61850 Edition 2

Comprehensive database for monitoring of modern power grids

Optimal smart automation platform for grids based on integrated synchrophasor measurement units (PMU) and power quality functions.

Fig. 1.1 /3 SIPROTEC 5 modular hardware

Fig. 1.1 /4 SIPROTEC 5 modular process connectionLS

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Innovation Highlights

With SIPROTEC 5, Siemens is writing yet another chapter in the successful history of protection technology, representing the 5th digital generation and over 100 years of experience in protection. SIPROTEC 5 represents the next logical step in this development. With SIPROTEC 5, we have combined a function-ality that has been proven and re ned over years with a high-performance and exible new platform, extended with trendsetting innovations for present and future demands.

Holistic work ow

The tools for end-to-end engineering from system design to operation will make your work easier throughout the entire process.

The highlight of SIPROTEC 5 is the greater-than-ever emphasis on daily ease of operation. SIPROTEC 5 provides support along all the steps in the engineering work ow, allowing for system view management and con guration down to the details of individual devices, saving time and cost without compromising quality (Fig. 1.2 /1).

Holistic work ow in SIPROTEC 5 means: Integrated, consistent system and device engineering from

the single line diagram of the unit all the way to device parameterization

Simple, intuitive graphical linking of primary and secondary equipment

Easily adaptable library of application templates for the most frequently used applications

Manufacturer-independent tool for easy system engineering

Open interfaces for seamless integration into your process environment

Integrated tools for testing during engineering, commissioning, and for simulating operational scenarios,e.g., grid disruptions or switching operations.

For you, Holistic work ow in SIPROTEC 5 means:An end-to-end tool from system design to operation even allowing crossing of functional and departmental boundaries saves time, assures data security and transparency throughout the entire lifecycle of your system.

Perfectly tailored t

Individually con gurable devices provide you with cost-effec-tive solutions that match your needs precisely throughout the entire lifecycle.

SIPROTEC 5 sets new standards in cost savings and availability with its innovative modular and exible hardware, functionality and communication. SIPROTEC 5 provides a perfectly tailored t for your switchgear and applications unparalleled by any other system.

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Fig. 1.2 /2 SIPROTEC 5 innovation highlights



Perfectly tailored t with SIPROTEC 5 means:

Modular system design in hardware, software and communication ensures the perfect t for your needs

Functional integration of a wide range of applications, such as protection, control, measurement, power quality or fault recording

The same expansion and communication modules for all devices in the family

Innovative terminal technology ensures easy assembly and interchangeability with the highest possible degree of safety

Identical functions and consistent interfaces throughout the entire system family mean less training requirement and increased safety, e.g., an identical automatic reclosing (AR) for line protection devices 7SD8, 7SA8, 7SL8

Functions can be individually customized by editing for your speci c requirements

Innovations are made available to all devices at the same time and can easily be retro tted as needed via libraries.

For you, perfectly tailored t with SIPROTEC 5 means:

Individually con gurable devices save you money in the initial investment, spare parts storage, maintenance, extending and adapting your system.

Designed to communicate

The trendsetting system architecture places communication rmly under your control. Powerful, exible, and above all reliable communication is the most important prerequisite for distributed and decentralized systems such as smart grids. In the system architecture of SIPROTEC 5 we have placed immense importance on communication, and we have gone to excep-tional lengths to ensure that you are ideally equipped for the communication demands of today and the future.

Designed to communicate with SIPROTEC 5 means:

Adaptation to the topology of your communication structure using settings (ring, star, network, )

Scalable redundancy in hardware and software (protocols) to match your requirements

Multiple communication channels with various higher-level systems

Pluggable, upgradable communication modules

Hardware modules decoupled from communication protocols

2 independent protocols on one module

Extensive routines for testing connections, functions and operating work ows

Expansion module for process bus communication.

For you, designed to communicate in SIPROTEC 5 means:

Communication as an integral component of the system architecture provides you with the exibility and safeguards you need to design and implement highly operable and reliable networked systems.

Safety and security inside

Multilayer safety mechanisms in all links of the system safety chain provide you with the highest possible level of safety and availability.

Safety for personnel and equipment, and also ultimate availabil-ity, are all the top priorities. As the plant landscape systems become more open and complex, the conventional security mechanisms are no longer adequate. For this reason, a security concept has been integrated in the SIPROTEC 5 device architec-ture that is designed to address these multidimensional aspects in a holistic approach.

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3.7 Fig. 1.2 /3 SIPROTEC 5 device with extensive communication interfaces



Smart automation is a major real-time component designed to preserve the stability of these grids and at the same time conserve energy and reduce costs.

With SIPROTEC 5, you have the optimum smart automation platform for your smart grids.

Smart automation for transmission grids with SIPROTEC 5 means: Open, scalable architecture for IT integration and new functions The latest standards in the area of communication and

Cyber Security Smart functions, e.g., for network operation, analysis of

faults or power quality (power systems monitoring, power control unit, fault location)

Integrated automation with optimized logic modules based on the IEC 61131-3 standard

Highly precise acquisition and processing of process values and transmission to other components in the smart grid

Protection, automation and monitoring in the smart grid.

For you, smart automation for transmission grids with SIPROTEC 5 means:

This is the rst device that has been designed speci cally to meet the requirements of the modern grid and offers the automation platform and future compatibility for smart grid projects.

The common features of all ve innovation highlights described are IEC 61850 Edition 2 and its thoroughly designed, user-oriented implementation in SIPROTEC 5.

Safety and security inside with SIPROTEC 5 means: Proven functions for protecting systems and personnel,

continuously developed over ve generations Long-lasting, rugged hardware (housings, assemblies, plugs)

and sophisticated layout of the entire electronics for highest resilience against voltage, EMC, climate and mechanical stress

Sophisticated self-monitoring routines identify and report device malfunctions immediately and reliably

Conformance with the stringent Cyber Security requirements according to the user guidelines and standards such as the BDEW Whitepaper and NERC CIP

Encryption along the entire communication segment between DIGSI 5 and the device, conforming to the recommendations of IEC 62351

Automatic recording of access attempts and security-critical operations on the devices and systems.

For you, safety and security inside with SIPROTEC 5 means:

With the multilayer safety mechanisms integrated in SIPROTEC 5, your equipment and systems will have the highest possible degree of security and reliability, conforming to the most recent requirements of international standards and technologies.

Smart automation for transmission grids

The extraordinary range of integrated functionalities for all the demands of your smart grid.

Climate change and dwindling fossil fuels are forcing a total re-evaluation of the energy supply industry, from generation to distribution and consumption. This is having fundamental effects on the structure and operation of the power grids.

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3.7Fig. 1.2 /4 SIPROTEC 5 as a system component of the smart grid



IEC 61850 Simply usable

Siemens, the pioneer of IEC 61850 makes the full potential of this global standard simply usable for you.

The IEC 61850 standard is more than just a substation automa-tion protocol. It comprehensively de nes data types, functions and communication in station networks. In Edition 2, the in uence of the standard is extended to more domains and applications of the energy supply industry.

Siemens was actively involved in the process of standardization from Edition 1 to Edition 2, and with the largest number of completed installations in the world, our experience as a manufacturer in the eld is unsurpassed. Jointly with key customers, we designed its implementation in SIPROTEC 5, paying close attention to interoperability, exibility and compatibility between Editions 1 and 2.

Besides IEC 61850, SIPROTEC 5 also supports other standards such as IEC 60870-5-103, IEC 60870-5-104, DNP 3 (seriell or TCP) or Modbus TCP.

IEC 61850 Simply usable with SIPROTEC 5 means:

A stand alone IEC 61850 sytem con guration tool allow IEC 61850 con guration of SIPROTEC 5, SIPROTEC 4 amd multi-vendor IEDs, also including process bus engineering

Full compatibility with Edition 1 and 2

Open interfaces in accordance with IEC 61850 guarantee manufacturer-independent system con guration and interoperability

Highly usable presentation of the complex IEC 61850 data model

Consistent system and device engineering from the single line diagram of the unit all the way to device parameterization

Flexible object modeling freedom in addressing objects and exible communication services assure the highest possible degree of customization and effective exchange and expansion concepts

Optimization of handling based on many projects and close cooperation with customers from all application areas

Protection settings over IEC 61850

Handling of multiple communication modules in Edition 2.

For you, IEC 61850 simply usable with SIPROTEC 5 means:

The implementation of IEC 61850 Edition 2 unleashes the full potential of this standard by optimally supporting your operational needs and simplifying handling.

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Functional Integration

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SIPROTEC 5 Devices Protection, Automation and Monitoring Siemens SIPROTEC 5.01 Edition 3

Perfectly tailored t

Optimizing the application templatefor your speci c application

You can adapt the application templates to your application and create your own in-house standards. The required number of protection stages or zones can be increased without dif culty. Additional functions can be loaded into the device directly from an extensive function library.

Functional integration

Due to the modular design of its hardware and software and the powerful engineering tool DIGSI 5, SIPROTEC 5 is ideally suited for protection, automation, measurement and monitoring tasks in the electrical power systems.

The devices are not only pure protection and control equipment, their performance enables them to assure functional integration of desired depth and scope. For example, they can also serve to perform monitoring, phasor measurement, fault recording, a wide range of measurement functions and much more, concurrently, and they have been designed to facilitate future functionality expansion.

SIPROTEC 5 provides an extensive, precise data acquisition and bay level recording for these functions. By combining device functionality with communication exibility, SIPROTEC 5 has the ability to meet a wide range of todays applications and speci c project speci cations as well as the functional expansion capability to adapt to changing needs in the future.

With SIPROTEC 5 you can improve the safety and reliability of your application. Fig. 1.3 / 1 shows the possible functional expansion of a SIPROTEC 5 device.

Faster results with application templates

Application templates allow you to fast track your solution. A library of application templates is available that can be tailored to the speci c functional scope for typical applications.

Fig. 1.3 /2 shows an example of a system con guration. Note that the functions in the application template are combined in functional groups (FG). The functional groups (FG) correspond to the primary components (protection object: line; switching device: circuit breaker), thereby simplifying the direct reference to the actual system. For example, if your switchgear includes 2 circuit breakers, this is also represented by 2 circuit breaker functional groups a schematic map of your actual system.

Due to the modular construction of their hardware and software, and their functional integration, SIPROTEC 5 devices are well suited for all tasks in the electricity trans-mission and distribution grid.

The SIPROTEC 5 devices can be used for the following applications:

Protection

Control and automation

Monitoring

Data acquisition and recording

Communication and Cyber Security

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Instrument and protection-class current transformer

The exibility of the SIPROTEC 5 family enables even greater functional integration and parallel processing of an extremely wide range of functions. The modular hardware enables an application-speci c device con guration. If you also want to use the phasor measurement function, i.e., the highly precise acqui-sition of current and voltage phasors and the variables derived from them such as power and frequency, this function can be assigned to the measuring input. Another additional application is monitoring power quality characteristics.

Fig. 1.3 /3 shows the connection to a protection-class and instrument current transformer for a feeder. The necessary protection functions are assigned to the protection-class current transformer and the measurement functions are assigned to the instrument transformer according to the application.

The highly precise measured values and status information provided by the SIPROTEC 5 devices can be transmitted over the high-performance communication system to automation systems such as a substation and power systems control or central analysis systems (e.g., SIGUARD PDP). In particular, the control and monitoring of smart grids require information from power generators (conventional or renewable energies) and from consumers (line branches). This essential information may be measured values, switching statuses, or messages from protection and monitoring functions. In addition to performing local protection, control and monitoring tasks, the SIPROTEC 5 devices are an excellent data source.

The exible communication among the devices enables them to be combined in various communication topologies. In this con-text, the widely used Ethernet-based communications standard IEC 61850 offers many advantages.

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Protection

SIPROTEC 5 provides all the necessary protection functions to address reliability and security of power transmission systems. System con gurations with multiple busbars and breaker-and-a-half schemes are both supported. The functions are based on decades of experience in putting systems into operation, including feedback and suggestions from our customers.

The modular, functional structure of SIPROTEC 5 allows exceptional exibility and enables the creation of a protection functionality that is speci c to the conditions of the system while also being capable of further changes in the future.

In the following segment available device functions of SIPROTEC 5 will be described.

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1.3 /4

Functional IntegrationDescription of the device functions

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Distance protection (ANSI 21, 21N) - classic method

SIPROTEC 5 provides 6-system distance protection featuring all well-proven algorithms of previously supplied SIPROTEC protec-tion devices.

By parallel calculation and monitoring of all six impedance loops, a high degree of sensitivity and selectivity is achieved for all types of faults. All methods of neutral-point treatment (com-pensated, isolated, solid or low-resistive grounded) are reliably dealt with. 1-pole and 3-pole tripping is possible depending on the speci c device type. The distance protection is suitable for cables and overhead lines with or without series capacitor compensation.

The device provides quadrilateral as well as MHO. The characte-ristics can be used separately for phase and ground faults.

Resistance ground faults can, for instance, be covered with the quadrilateral characteristic and phase faults with the MHO characteristic.

The evaluation of healthy voltages and the use of a voltage memory make optimal direction determination possible.

Zone characteristic quadrilateral

The quadrilateral characteristic permits separate setting of the reactance X and the resistance R. The resistance section R can be set separately for faults with and without earth involvement. This characteristic has therefore an optimal performance for detecting high-resistive faults.

Applications with ground fault dependent reactance reach per zone can be covered as well by simply using additional distance zones. Each distance zone can be set separately to operate for ground faults only, for phase faults only or for all fault types.

The distance zones can be set forward, backward or non-directional.

Zone-characteristic MHO

With the MHO characteristic, the MHO circle expansion gua-rantees safe and selective operation for all types of faults, even for faults close to the zone boundary. The circle expands to the source impedance but never more than the selected impedance reach. The example in the gure (Fig. 1.3 /5) shows the charac-teristic for a forward fault.

Appropriate number of distance zones

The number of distance zones can be freely adapted according to the application requirements. For functions using a dependent zone, such as signal comparison, all parameterized zones from the distance protection are available (application of the zone in distance protection itself is not affected by this). Each distance zone has its own timer, separately dedicated to 1-phase and 3-phase short circuits. Thus, the new exibility of the SIPROTEC 5 device family provides optimal adaptation to each application. The distance protection will always provide the exact number of required distance zones.

Four pickup methods

The following pickup methods can be employed alternatively:

Overcurrent pickup I >>

Voltage-dependent overcurrent pickup V / I

Voltage-dependent and phase angle dependent overcurrent

pickup V / I / Impedance pickup Z evaluates the r.m.s. value, referred to one systems period.

Transformer inrush current detection

If the device is used in a transformer feeder, high inrush currents can be expected when the transformer is switched on. These can reach many times the rated current and ow for several tens of milliseconds to several seconds, depending on the size and design of the transformer. The inrush current detection function detects the transformer energizing and generates a blocking signal for protection functions that would spuriously respond to the transformer inrush current. This enables these protection functions to be sensitive.

To detect transformer energizing reliably, the function uses the "harmonic analysis" and "CWA methods" (current waveform analysis) measuring methods. The two methods work in parallel and combine the results with a logical OR. The result is a "1-out-of-2 decision," which increases the availability of the electrical installation.

Inverse-time overcurrent protection (ANSI 51V)

This function also comprises short-circuit and backup protection and is used for power system protection with current-dependent protection devices. IEC and ANSI characteristics can be selected (Table 1.3 /1). The current function can be controlled by evaluating the gene-rator terminal voltage. The controlled version releases the sen-sitive set current stage. With the restraint version, the pickup value of the current is lowered linearly with decreasing voltage. The fuse failure monitor prevents unwanted operation.

Available inverse-time characterictics

Characteristics acc. to ANSI / IEEE IEEE IEC 60255-3

Inverse

Moderately inverse

Very inverse

Extremely inverse

De nite inverse

Table 1.3 /1 Available inverse-time characteristics

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Directional overcurrent protection, phases and ground (ANSI 67, 67N)

The functions directional time-overcurrent protection for phases and ground sense short circuits in electrical equipment. With directional time-overcurrent protection, the units can also be used in power systems in which not only the overcurrent crite-rion but also the direction of power ow to the fault location is a selectivity criterion, e.g. in single-feed parallel lines, in double-feed lines, or in looped lines.

Two de nite time-overcurrent protection stages (DTL stages) and one inverse time-overcurrent protection stage (IDMTL stage) are precon gured. Further de nite time-overcurrent protection stages and one stage with a user-de ned characteristic can be con gured within the function.

For the inverse time-overcurrent protection stages, all common characteristics according to IEC and ANSI/IEEE are available.

The following gure shows how the direction characteristic of the ground function can be freely con gured. The characteristic can be rotated for the phase function.

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Blocking functions of the stage: on measuring voltage failure, via binary input signal, or by other functions (automatic reclosure, cold load pickup)

Every stage can be restrained against over-response caused by transformer inrush currents

The direction can be set for each stage

The stage can optionally be used for directional comparison protection. Both a release and a blocking method can be implemented

Each stage can be used as an alarm stage (no trip signal)

For the measuring method, measurement of the fundamental or the rms value can be selected.

The ground function evaluates the calculated zero-sequence current (3I0) or the measured ground current

Logarithmically inverse characteristics are also available for the ground stages.

lance, which also results in unbalance currents. The function permits both static and dynamic compensation. The latter must be used if dynamic environmental in uences such as tempe-rature uctuations are already causing relevant operational unbalances.

Moreover, the measured unbalance can optionally be normalized with the current of the capacitor bank to ensure constant sensitivity even at different powers.

Measuring-voltage failure detection (ANSI 60FL)

This function monitors the voltage transformer secondary circuits:

Non-connnected transformers

Pickup of the voltage transformer circuit-breaker (in the event of short circuits in the secondary circuit)

Series faults in one or more measuring loops.

All these events cause a voltage of 0 in the voltage-transformer secondary circuits, which can lead to failures of the protection functions.

The following protection functions are automatically blocked in the case of a measuring-voltage failure:

Distance protection

Directional negative-sequence protection

Ground-fault protection for high-resistance faults in grounded-neutral systems.

Restart inhibit (ANSI 66)

The restart inhibit prevents the motor from restarting if the permitted temperature limit would thus be exceeded.

The rotor temperature of a motor is far below the permissible temperature limit during normal operation and also under increased load conditions. High starting currents required when starting the motor increase the risk of the rotor being thermally damaged rather the stator due to overheating. This is related to the short thermal constant of the rotor. To avoid tripping of the circuit breaker due to multiple motor start-up attempts, the restart of the motor has to be inhibited if it is obvious that the temperature limit of the rotor has been exceeded during a start-up attempt (see Fig. 1.3 /11).

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1.3 /14


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Directional sensitive ground-fault detection for isolated and resonant-grounded systems (ANSI 67Ns, ANSI 51Ns, 59N)

The directional sensitive ground-fault detection function detects ground faults in isolated and resonant-grounded systems. It provides different function elements which can also be used par-allelly. This allows adapting the function optimally to the system conditions, user philosophy and different fault characteristics:

Overvoltage elements with zero sequence system /displacement voltage

The zero-sequence system voltage (displacement voltage) is assessed as to exceeding a threshold. In addition, the faulted phase can be determined when the phase-ground voltages are connected.

Directional ground-current elements withdirection determination using cos and sin measurementThis is the classical wattmetric (cos , in the resonant-grounded system) or varmetric (sin , in the isolated system) measurement procedure for the directional detection of static ground faults. For determining the direction the part of the ground current which is perpendicular to the set directional characteristic (= axis of symmetry) is decisive (3I0dir.), see Fig. 1.3 /13. The element can be adapted to the system condi-tions with the corresponding setting (position of the directional characteristic). Very sensitive and exact measurements can be made in this way.

Fig. 1.3 /13 Direction determination cos -measurement

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Directional ground-current element withdirection determination using (V,I) measurement

This procedure can be used as an alternative to the cos or sin procedure if desired by the user philosophy. The direction is found by determining the phase angle between the angle-error compensated ground current and the rotated zero voltage V0. In order to satisfy different network conditions and applications, the reference voltage can be rotated by an adjustable angle. This allows taking the vector of the rotated reference voltage close to the vector of the 3I0com ground current. The result of the direction determination is highly reliable in this way (see Fig. 1.3/12).

Ground-fault transient procedure

This transient procedure works only during the rst 1 to 2 periods after the fault ignition. It determines the direction by evaluating the active energy of the transient process. It is particularly suitable if direction information is required for faults

Directional ground-fault protection with phase selector for high-resistance ground faults (ANSI 51G, 67G, 50G)

In grounded systems, it may happen that the main protection sensitivity is not suf cient to detect high-resistance ground faults. The SIPROTEC 5 device therefore has protection functions for faults of this nature.

Multiple stages

The ground fault overcurrent protection can be used with 6 de nite-time stages (DT) and one inverse-time stage (IDMTL).

The following inverse-time characteristics are provided:

Inverse acc. to IEC 60255-3

ANSI/IEEE inverse

Logarithmic inverse

V0-inverse

S0-inverse.

Appropriate direction decision modes

The direction decision can be determined by the residual current I0 and the zero sequence voltage V0 or by the negative sequence components V2 and I2. Using negative-sequence components can be advantageous in cases where the zero sequence voltage tends to be very low due to unfavorable zero sequence impedan-ces.

In addition or as an alternative to the directional determination with zero sequence voltage, the ground current of a grounded power transformer may also be used for polarization. Dual polarization applications can therefore be ful lled. Alternatively, the direction can be determined by evaluation of zero sequence power. Each stage can be set in forward or reverse direction or both directions (non-directional).

High sensitivity and stability

The SIPROTEC 5 devices can be provided with a sensitive neutral (residual) current transformer input. This feature provides a measuring range for the ground current (fault current) from 5 mA to 100 A with a rated current of 1 A and from 5 mA to 500 A with a nominal current of 5 A. Thus the ground-fault overcurrent protection can be applied with extreme sensitivity.

The function is equipped with special digital lter algorithms, providing the elimination of higher harmonics. This feature is particularly important for low zero sequence fault currents which usually have a high content of 3rd and 5th harmonics.

Dynamic setting change

Dynamic setting change of pickup values and delay time settings can be activated depending on the status of an auto-reclosure function. An instantaneous switch-on to fault is applicable for each stage.

Phase selector

The ground-fault protection is suitable for 3-phase and, optio-nally, for 1-phase tripping by means of a sophisticated phase selector. It may be blocked during the dead time of 1-pole auto-reclose cycles or during pickup of a main protection function.

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Power-swing blocking (ANSI 68)

Dynamic transient incidents, for instance short-circuits, load uctuations, auto-reclosures or switching operations can cause power swings in the transmission network. During power swings, large currents along with small voltages can cause unwanted tripping of distance protection devices. The power-swing blocking function avoids uncontrolled tripping of the distance protection.

Power swings can be detected under symmetrical load conditions as well as during 1-pole auto-reclose cycles (see Fig. 1.3/14).

No settings required

The function requires no settings. The optimal computation is always obtained by automatic adaptation. During a power-swing blocking situation all swing properties are constantly supervised. A subsequent network fault is reliably detected and results in phase-selective reset of the distance protection blocking by the power-swing detection.

Trip circuit supervision (ANSI 74TC)

The circuit breaker coil including its feed lines is monitored with two binary inputs. An alarm will be generated if there is an interruption in the trip circuit.

which extinguish very fast (after 0.5 to few periods). This makes it suitable for use in parallel to the element with cos measurement.

This procedure can also be used in meshed networks. It is also optimal for use at closed rings since circulating zero sequence are eliminated. With an additional logic the function can optio-nally switch off static faults.

Non-directional ground-current element

If required, a simple non-directional ground-current element can be con gured.

General

High phase-angle accuracy is particularly important in resonant-grounded systems. The measured ground current is corrected for this purpose via the stored phase-angle fault characteristic of the cable-type current transformer (phase-angle fault as a function of the current).

A special algorithm can detect the extinction of the fault fast. This detection allows blocking the directional ground-current stages whose direction determination is based on the phase-angle reference between zero-sequence current and zero-sequence voltage. The stability is increased in this way during the decaying process of the zero-sequence system in the resonant-grounded system. Pickup and trip signals can be stored in the separate ground fault buffer.

Fig. 1.3 /14 Power-swing detection during 1-pole open condition

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Cooperation with external devices via binary inputs andoutputs or via communication with GOOSE message in IEC 61850 systems

Control of the integrated AR function by an external protection

Cooperation with the internal or an external synchrocheck

Monitoring of the circuit-breaker auxiliary contact

Dynamic setting change of overcurrent protection elements, depending on the AR status.

Two auto-reclosure (AR) functions

For applications with two circuit breakers per feeder, e.g. breaker-and-a-half, ring bus or double circuit-breaker appli-cations the devices can be con gured to operate with two independent auto-reclosure functions.

1-pole auto-reclosure

In electrical power systems with grounded system neutral-point and if the circuit-breaker pole can be operated individually, a 1-pole auto-reclosure is usually initiated for 1-phase short circuits.

1-pole auto-reclosure functionality is available in SIPROTEC 5 devices with 1-pole tripping capability. The following operating modes are provided in addition to the above mentioned features:

1-pole auto-reclosure for 1-phase short circuits, no reclosing for multi-phase faults

1-pole auto-reclosure for 1-phase faults and for 2-phase faults without ground, no reclosing for multi-phase short circuit

1-pole auto-reclosure for 1-phase fault and 3-pole auto-reclosing for multi-phase faults

1-pole auto-reclosure for 1-phase faults and for 2-phase faults without ground and 3-pole auto-reclosure for other faults

Appropriate evolving fault response

3-pole coupling (positive 3-pole tripping) in case of circuit-breaker pole discrepancy.

Voltage-dependent supplementary functions

The integration of auto-reclosure in the feeder protection allows evaluation of the line-side voltages. A number of voltage-dependent supplementary functions are thus available:

DLCBy means of a dead-line check, reclosure is effected only when the line is de-energized (prevention of asynchronous circuit-breaker closure), if no synchrocheck can be used.

ADT The adaptive dead time is employed only if auto-reclosure at the opposite end was successful (reduction of stress onequipment).

RDTReduced dead time is employed in conjunction with autoreclosure where no teleprotection is used: When faultswithin the overreach zone, but external to the protected line, are switched off for short-time interruption, the RDT function decides on the basis of measurement of the reverse polarity voltage from the opposite end, which has not tripped, whether or not to reduce the dead time.

Out-of-step protection (ANSI 78)

In electric power transmission systems electrical stability must be maintained at all times. If system conditions arise that threa-ten the stability measures must be taken to avoid an escalation. One such system is the out-of-step protection. The function can be applied as out-of-step protection or can be integrated into more complex systems for supervision and load control, i.e. system integrity protection systems (SIPS).

The out-of-step function constantly evaluates the impedance trajectory of the positive sequence impedance. The response characteristic is de ned by impedance zones in the R /X plane. Accumulators are incremented depending on the point at which the impedance trajectory enters or exits the associated impedance zone. Tripping or signaling occurs when the set accu-mulator limits are reached. The out-of-step protection provides up to four independent impedance zones which can be adjusted and tilted according to the requirements of stability in the power network. (see Fig. 1.3 / 15).

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Automatic reclosing (ANSI 79)

About 85% of the arc faults on overhead lines are extinguished automatically after being tripped by the protection. The over-head line can therefore be re-energized. Reclosure is performed by an automatic-reclosing function (AR). Each protection function can be con gured to start or block the auto-reclosure function.

Basic features and operating modes

Tripping controlled start with action time or without action time

Pickup controlled start with action time or without action time

3-pole auto-reclosing for all types of faults; different dead times are available depending on the type of fault

Multiple-shot auto-reclosure

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Frequency protection (ANSI 81O, 81U)

Frequency deviations are caused by an unbalance between generated and consumed the active power. Causes are, for example, load shedding, network disconnections, increased need for active power, generator failures or faulty functioning of the power and frequency regulation.

The frequency protection detects frequency deviations in the network or in electric machines. It monitors the frequency band and outputs failure indications. In case of critical power frequency entire generation blocks can be isolated or networks can be decoupled. To ensure network stability, load shedding can be initiated.

Different frequency measuring elements with high accuracy and short pickup times are available. Tripping by frequency measuring elements can be effected either at the local circuit breaker or at the opposite end by remote tripping.

The following measuring elements are available:

Overfrequency protection (ANSI 81O)

Two precon gured stages, can be increased up to three stages. All stages are of identical design.

Underfrequency protection (ANSI 81U)

Three precon gured stages, can be increased up to ve stages. All stages are of identical design.

The following frequency measurement procedures are available for selection:

Angle difference method: Angle change of the voltage phasor over a time interval

Filter method of measurement: Evaluation of immediate voltage values with special lters.

For all measuring methods the speci c protection functions are provided in the DIGSI 5-library.

Rate-of-frequency-change protection (ANSI 81R)

Frequency changes can be detected quickly with the rate-of-frequency-change protection. The function is able to prevent unsafe states of the system caused by unbalance between generated and consumed active power. It is therefore used in power system disconnection and load shedding measures.

The function provides two types of stages:

df/dt rising

df/dt falling

Of each type of stage, up to ve stages can be set up in the function.

By de ning the measurement window length, either the measuring accuracy or the starting time can be optimized for the speci c application.

On undervoltages, the function is automatically blocked to exclude imprecise or incorrect measurements.

Tele (pilot) protection for distance protection (ANSI 85/21)

A teleprotection function is available for fast clearance of faults up to 100% of the line length.

For conventional signal transmission the required send and receive signals can be freely assigned to binary inputs and outputs. The signals can certainly be transferred via the serial protection interface, a SIPROTEC 5-wide system feature. The transmission via GOOSE messages with IEC 61850 system interfaces is provided as well, if the available communication structures in the substations ful ll the intra-substation require-ments acc. to IEC 61850-90-1.

The following teleprotection schemes are provided for distance protection:

Permissive underreach schemes PUTT

Pickup with expansion of measuring range

Acceleration with pickup

Direct underreaching trip

Permissive overreach schemes POTT

With overreach zone

Directional comparison pickup

Unblocking

Each permissive scheme can be extended with an unblocking logic

Blocking

Reverse interlocking

Transmission link protection

The send and receive signals are available as general signals or as phase-selective signals. The phase-selective signals are particularly advantageous as they guarantee reliable 1-pole tripping, if 1-phase short circuits occur on different lines. The teleprotection schemes are suitable also for power lines with more than two line-ends, e.g. teed feeder. Up to six line-ends are possible.

Transient blocking (current reversal guard) is provided for all per-missive and blocking schemes in order to suppress interference signals during tripping of parallel lines.

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Weak or no infeed: Echo and tripping (ANSI 85/27)

To prevent delayed tripping of distance protection permissive schemes and ground-fault directional comparison scheme during weak or zero infeed situations, an echo function is provided. If no fault detector is picked up at the weak-infeed end of the line, the signal received here is returned as echo to allow accelerated tripping at the strong infeed end of the line. It is also possible to initiate phase-selective tripping at the weak-infeed end. A phase-selective 1-pole or 3-pole trip is issued if a send signal is received and if the measured voltage drops correspon-dingly. This feature is available for all permissive underreach and overreach schemes. As an option, the weak infeed logic can be equipped according to a French speci cation.

Teleprotection for directional ground-fault protection (ANSI 85/67N)

For fast clearance of faults up to 100% of the line length the directional ground-fault protection can be expanded with a teleprotection scheme.

The following schemes are available:

Directional comparison

Blocking

Unblocking

The send and receive signals are available as general signals or as phase-selective signals in combination with the phase selector of the directional ground-fault protection. For conven-tional signal transmission the send and receive signals can be freely assigned to binary inputs and outputs. The signals can certainly be transferred via the serial protection data interface, a SIPROTEC 5-wide system feature. The transmission via GOOSE messages with IEC 61850-system interfaces is provided as well, if the available communication structures in the substations ful ll the intra-substation requirements according to IEC 61850-90-1.

The transient blocking (current reversal guard) function can be enabled in order to suppress the interference signals during tripping of parallel lines. Communication of the teleprotection functions for distance protection and ground-fault protection can use the same signaling channel or separate and redundant channels.

Line differential protection (ANSI 87L, 87T)

Line differential protection is a selective short-circuit protection for overhead lines, cables, and busbars with single-side and multi-side infeed in radial, looped, or meshed systems. It can be used at all voltage levels. Line differential protection works strictly phase-selectively and allows instantaneous tripping of 1- or 3-phase short circuits at up to six line ends. Depending on the device variation 1-/3-pole (7SD87/7SL87) or only 3-pole tripping (7SD84/7SD86/7SL86) is possible. The devices in a differential protection topology communicate with each other via protection interfaces (protection-data communication). The exible use of available communication media saves investment in communication infrastructure and guarantees the protection of lines of all lengths.

Adaptive measurement

An adaptive measurement method ensures a maximum of sensitivity to detect internal faults under all conditions. To gua-rantee highest stability any measurement and communication errors are taken into account (see Fig. 1.3 / 16). Simple settings and supervision features shorten time of engineering and commissioning.

A sensitive measurement stage (IDiff >) offers the detection ofhigh resistive faults. Special algorithms guarantee highstability even with high-level DC components in the short-circuit current.

A high-set differential stage (IDiff >>) offers high-speed fault clearance with very short tripping times.

Different CT ratios at the line ends are handled inside the relay.

No external matching transformers are needed.

With the setting of CT-error data the differential protectiondevice automatically calculates the restraint current andadapts its permissible sensitivity according to the CTs data.Thus no protection characteristic has to be parameterized.Only IDiff > (sensitive stage) and IDiff >> (high-set current differential stage) must be set according to the charging current of the line/cable.

Enhanced communication features guarantee stability andaccuracy even under disturbed or interrupted communication on all kinds of media like optical bers, pilot wires or communication networks.

Differential and restraint currents are monitored continuouslyduring normal operation and are displayed as operational measurements.

High stability during external faults even with different current transformer saturation levels.

When long lines or cables get switched on, transient charging currents load the line. To avoid higher settings and less sensitivity of the IDiff >> stage, the set point may be increased IDiff > for a settable time. This offers higher sensitivity under normalload conditions.

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1.3 /19


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Charging current compensation

Particularly long cables and very high-voltage lines can cause considerable, permanently owing capacitive load currents. These must be considered via the trip threshold of the sensitive differential protection stages because they produce a differential current.

The charging current compensation serves to improve the sensitivity so that maximum sensitivity can be protected even at high charging currents.

Charging current compensation requires that local voltage transformers are connected.

The principle of distributed compensation guarantees maximum availability, since with local failure of measuringvoltages of a device, the remaining devices continue to guarantee their part of the compensation.

Transformer in the protection range

Apart from normal lines, line differential protection can also protect lines with a transformer in block connection. The current transformers selectively delimit the protection range.

A separate transformer protection device can therefore be omitted, since line differential protection acts as a transformer protection with measuring points that may lie far away from one another.

With few additional transformer parameters such as rated apparent power, primary voltages, vector groups and any neutral-point groundings of the respective windings, there isno need for external matching transformers.

The sensitivity of differential protection can be further increased by capturing the earth currents of grounded neutralpoint windings.

The inrush current detectionstabilizes the differential protection against tripping due to transformer inrush currents. This can occur phase-selectively or in 3-phase bymeans of the crossblock function.

Breaker-and-a-half schemes

Differential protection can be integrated easily into breaker-and-a-half schemes. With corresponding hardware extension (see standard variants), two 3-phase current inputs per device are con gurable. Thus ultimately topologies of up to 12 measure-ment points with 6 devices can be con gured. The protection of a STUB-BUS can be assumed by the separate STUB differential protection.

Improved communication features

The line differential protection uses the protection interfaces in the Differential protection con guration (Type 1, see Protection-data communication). Different communication modules and external converters allow the interfacing and use of all available communication media.

Direct ber-optic data transmission is immune toelectromagnetic interference and offers highest performance.

Using the external communication converters via existing pilot wires or communication networks is possible.

The data required for the differential calculations is cyclically exchanged in full-duplex mode in the form of synchronous, serial telegrams between the protection units. Enhanced supervision features ensure stability in operation in any commu-nication environment:

Telegrams are secured with CRC check sums to detect transmission errors. Only valid telegrams get operated by thedifferential protection.

Supervision of all communication paths between the unitswithout additional equipment.

Unambiguous identi cation of each unit is ensured by the assignment of settable communication addresses for each unit within a differential protection topology.

Detection of re ected telegrams in the communication networks.

Detection of time delay changes in the communication networks.

Dynamic compensation of delay time in the differential measurement and supervision of the maximum permissible signal-transit time.

Generation of alarms on disturbed communication connection. Faulty telegram counters are available as operational measurement.

Switched communication networks can lead to unsymmetrical delay times in receive and transmit directions. The resultingdifferential current is compensated by the adaptive measuring techniques of the differential protection.

With a high-precision 1 s pulse from a GPS receiver the relayscan be synchronized with an absolute, exact time at each lineend. In this way, delay times in receive and transmit path canbe measured exactly. Thus the differential protection can beused in communication networks with a maximum of sensiti-vity even under massive unsymmetrical delay conditions.

1.3 /20


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Phase-selective circuit-breaker intertripping andremote trip / indications

Normally the differential fault current is calculated for each line end nearly at the same time. This leads to fast and uniform tripping times. Under weak infeed conditions, especially when the differential protection function iscombined with an overcurrent pickup a phase-selective breaker intertripping offers a tripping of all line ends. Therefore high-speed transfer-trip signals get transmitted to the other line ends. They can also be initiated by an external relay via binary inputs. Therefore they can be used to indicate, for example, a directional decision of the backupdistance protection.

Additional remote signals can be freely assigned to binaryinputs and outputs and are circulating between the different devices (see Protection-data communication).

Fig. 1.3 /17 Differential protection in ring topology

Communication topologies /modes of operation

Differential protection devices may work in a ring or chain line topology. The use of a test mode offers operating conditions and maintenance.

The system tolerates the loss of one data connection in a ringtopology. The ring topology is rerouted within 20 ms into a chain topology, while the differential protection function isstill working.

When a chain topology is given by the communication infrastructure, cost effective relays with only one activeinterface are necessary at the chain ends.

For important two-end lines a hot standby transmission is possible by a redundant communication connection to ensure high availability. When the main connection is interrupted, the communication switches over from the main path to a secondary path.

For service or maintenance reasons individual differential protection devices within multi-end topologies can be logged out by a signal via binary input. Circuit-breaker positions and load currents get checked before a logoff is initiated. Theremaining devices are able to operate in this reduced topology.

The whole con guration can be set up into a test mode. All functions and indications are available except the breakers will not trip. The local relay can be tested without tripping or intertripping at the other relays.

STUB differential protection (ANSI 87 STUB)

STUB differential protection is a full- edged line differential pro-tection, but without communication between the line ends. It is used with a teed feeder or a breaker-and-a-half scheme, when a feeder of the line section can no longer be selectively protected by opening the disconnector (example distance protection).

The activation of the STUB differential protection occurs through the feedback of the disconnector position. The SIPROTEC 5 line protection device must be equipped with two 3-phase current inputs in its hardware for this. The STUB differential protection corresponds structurally and with regard to the setting parame-ters to the line differential protection (ANSI 87L) in all regards, with the exception of protection data communication. It guarantees the selective protection of the remaining line section and rapid tripping times up to 10 ms.

Transformer differential protection (ANSI 87T)

The transformer differential protection is a selective short-circuit protection for power transformers with different types of design (standard transformers and autotransformers) and different connection designs. The number of protectable windings (sides)and the number of usable measuring points depends on the device type (see above explanations).

The following properties are essential for the protection function:

Restraint tripping characteristic with freely settable characte-ristic sections in accordance with Fig. 1.3 / 19

Integrated adaptation to the transformer ratio with different rated currents of the current transformer (primary and secon-dary) taken into account

Flexible adaptation to the different transformer vector groups

Adaptive adjustment of the trip characteristics by detection of the transformer tapping

Fig. 1.3 /18 Differential protection in chain topology

1.3 /21


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Additional consideration given to neutral point currents with grounded winding and thus increase of the sensitivity by one third

Redundant stabilization procedure (2nd harmonic + curve wave analysis) to detect safely inrush procedures at the transformer

Further stabilization options through the evaluation of the 3rd or 5th harmonic in the differential current. The 5th harmonic is suitable for detecting safely a steady-state overexitation of thetransformer and thus for avoiding an overfunction

Additional stabilization procedures against external faults withcurrent transformer saturation. The rst procedure responds to high-current faults and monitors the differential current curve (differential current detected outside the add-on stabilization characteristic for a limited time, see Fig. 1.3 /19). Changeover to an internal fault is safely detected. The secondprocedure works with low-current faults. Phase-angle shifts can occur in the secondary current due to the DC component in the short-circuit current and remanence of the current transformer. If jumps occur in the stabilization current and ifDC components are detected in the differential current at the same time, the tripping characteristic is increased for a limited time.

If asynchronous motors are connected to transformers, differential currents can occur due to the distorted transmis-sion of the starting current. The start detection (jump in thestabilization current and DC component evaluation) will raise the tripping characteristic.

High-power internal faults are detected safely and quickly with the high-current stage IDiff-fast (see Fig. 1.3 /20). In order to avoid an overfunction due to q-axis currents (e.g. use in one-and-a-half layout), the instantaneous values of the dif-ferential and stabilization current are evaluated. Internal and external faults are safely detected within a few milliseconds.

The protection function was adapted to the special conditions of the autotransformer in order to ensure the protection of autotransformers. The pure node point protection can be used as an additional sensitive protection of the autotransformer winding. The node point protection works parallel to the classi-cal d ifferential protection. The autotransformer banks become highly sensitive to ground faults and interturn faults with it.Fig. 1.3 /21 shows the basic idea.

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Fig. 1.3 /21 Protection of an autotransformer through two differential protection in one device

1.3 /22


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Differential ground-fault protection (ANSI 87N T)

Ground faults close to the neutral of a grounded neutral winding can be detected by the longitudinal differential pro-tection only to a limited extent. The ground-fault differential protection will support you here.

The neutral point current and the calculated zero sequence of the phase currents are evaluated in accordance with Fig. 1.3 / 23. An overfunction in the case of external ground faults is avoided with special stabilization measures. The phase angles of the zero sequence are monitored in addition to the differential current and stabilization current based on the zero quantities. The tripping quantity is the zero sequence in the neutral point.

///

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, + n< - - - - - -

24 Overexcitation protection V/f - - - - - -

25 Synchrocheck, synchronizing function Sync 27 Undervoltage protection, 3-phase V< 27 Undervoltage protection, positive-sequence system V1< 27 Undervoltage protection, universal, Vx Vx< 27Q Undervoltage-controlled reactive power protection Q>/V< 32, 37 Power protection active/reactive power P, Q 37 Undercurrent I< 38 Temperature Supervision 46 Negative sequence overcurrent protection I2> - - - - - -

46 Unbalanced-load protection (thermal) I2 t> - - - - - -

46 Negative sequence overcurrent protection with direction I2>, (V2,I2) 47 Overvoltage protection, negative-sequence system V2> 48 Starting-time supervision for motors Istart - - - - - -

49 Thermal overload protection , It 49 Thermal overload protection for RLC lter elements of a

capacitor bank, It - - - - - -

49H Hot spot calculation h, It - - - - - -49R Thermal overload protection, rotor R - - - - - -50/51 TD Overcurrent protection, phases I> 50N/51N TD Overcurrent protection, ground IN> 50HS High speed instantaneous overcurrent protection I>>>

Instantaneous tripping at switch onto fault SOTF 50N/51N TD Overcurrent protection, 1-phase IN> 50Ns/ 51Ns Sensitive ground-current protection for systems with

resonant or isolated neutralINs>

Intermittent ground fault protection Iie> 50/51 Emergency overcurrent protection, phases I> - - - - - -

50N/51N Emergency overcurrent protection, ground faults IE> - - - - - -

50/51 TD Overcurrent protection for RLC lter elements of a capacitor bank

I> - - - - - -

50BF Circuit-breaker failure protection, 3-pole CBFP - -50BF Circuit-breaker failure protection, 1-/3-pole CBFP - - - - 50RS Circuit-breaker restrike protection CBRS - -

Further functions continued on the next pages


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Relay Selection GuideFunction overview SIPROTEC 5

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