Siemens Power Engineering Guide

Power Engineering Guide Transmission and Distribution

4th Edition

Power Engineering Guide Transmission and Distribution

Your local representative:

Sales locations worldwide (EV): http://www.ev.siemens.de/en/pages/salesloc.htm

Distributed by: Siemens Aktiengesellschaft Power Transmission and Distribution Group International Business Development, Dept. EV IBD P.O. Box 3220 D-91050 Erlangen Phone: ++ 49 - 9131-73 45 40 Fax: ++ 49-9131-73 45 42 Power Transmission and Distribution group online: http://www.ev.siemens.de

Siemens Power Engineering Guide · Transmission and Distribution · 4th Edition

Foreword

This Power Engineering Guide is devised as an aid to electrical engineers who are engaged in the planning and specifying of electrical power generation, transmission, distribution, control, and utilization systems. Care has been taken to include the most important application, performance, physical and shipping data of the equipment listed in the guide which is needed to perform preliminary layout and engineering tasks for industrial and utility-type installations. The equipment listed in this guide is designed, rated, manufactured and tested in accordance with the International Electrotechnical Commission (IEC) recommendations. However, a number of standardized equipment items in this guide are designed to take other national standards into account besides the above codes, and can be rated and tested to ANSI/ NEMA, BS, CSA, etc. On top of that, we manufacture a comprehensive range of transmission and distribution equipment specifically to ANSI/NEMA codes and regulations. Two thirds of our product range is less than five years old. For our customers this means energy efficiency, environmental compatibility, reliability and reduced life cycle cost. For details, please see the individual product listings or inquire. Whenever you need additional information to select suitable products from this guide, or when questions about their application arise, simply call your local Siemens office.

Siemens AG is one of the world’s leading international electrical and electronics companies. With 416 000 employees in more than 190 countries worldwide, the company is divided into various Groups. One of them is Power Transmission and Distribution. The Power Transmission and Distribution Group of Siemens with 24 700 employees around the world plans, develops, designs, manufactures and markets products, systems and complete turn-key electrical infrastructure installations. The group owns a growing number of engineering and manufacturing facilities in more than 100 countries throughout the world. All plants are, or are in the process of being certified to ISO 9000/9001 practices. This is of significant benefit for our customers. Our local manufacturing capability makes us strong in global sourcing, since we manufacture products to IEC as well as ANSI/NEMA standards in plants at various locations around the world. Siemens Power Transmission and Distribution Group (EV) is capable of providing everything you would expect from an electrical engineering company with a global reach. The Power Transmission and Distribution Group is prepared and competent, to perform all tasks and activities involving transmission and distribution of electrical energy.

Sales locations worldwide: http://www.ev.siemens.de/en/pages/ salesloc.htm

Siemens Power Transmission and Distribution Group offers intelligent solutions for the transmission and distribution of power from generating plants to customers. The Group is a product supplier, systems integrator and service provider, and specializes in the following systems and services: ■ High-voltage systems ■ Medium-voltage systems ■ Metering ■ Secondary systems ■ Power systems control and energy management ■ Power transformers ■ Distribution transformers ■ System planning ■ Decentralized power supply systems. Siemens’ service includes the setting up of complete turnkey installations, offers advice, planning, operation and training and provides expertise and commitment as the complexity of this task requires. Backed by the experience of worldwide projects, Siemens can always offer its customers the optimum cost-effective concept individually tailored to their needs. We are there – wherever and whenever you need us – to help you build plants better, cheaper and faster.

Dr. Hans-Jürgen Schloß Vice President Siemens Aktiengesellschaft Power Transmission and Distribution


Quality and Environmental Policy

Quality and Environmental – Our first priority Transmission and distribution equipment from Siemens means worldwide activities in engineering, design, development, manufacturing and service. The Power Transmission and Distribution Group of Siemens AG, with all of its divisions and relevant locations, has been awarded and maintains certification to DIN EN ISO 9001 and DIN EN ISO 14001. Certified quality Siemens Quality Management and Environmental Management System gives our customers confidence in the quality of Siemens products and services. Certified to be in compliance with DIN EN ISO 9001 and DIN EN ISO 1400, it is the registered proof of our reliabilty.


Contents General Introduction Energy Needs Intelligent Solutions

Power Transmission Systems

1

High Voltage

2

Medium Voltage

3

Low Voltage

4

Transformers

5

Protection and Substation Control

6

Power Systems Control and Energy Management

7

Metering

8

Services

9

System Planning

10

Conversion Factors and Tables Contacts and Internet Addresses Conditions of Sales and Delivery


General Introduction

Energy management systems are also important, to ensure safe and reliable operation of the transmission network. Distribution In order to feed local medium-voltage distribution systems of urban, industrial or rural distribution areas, HV/MV main substations are connected to the subtransmission systems. Main substations have to be located next to the MV load center for reasons of economy. Thus, the subtransmission systems of voltage levels up to 145 kV have to penetrate even further into the populated load centers. The far-reaching power distribution system in the load center areas is tailored exclusively to the needs of users with large numbers of appliances, lamps, motor drives, heating, chemical processes, etc. Most of these are connected to the low-voltage level. The structure of the low-voltage distribution system is determined by load and reliability requirements of the consumers, as well as by nature and dimensions of the area to be served. Different consumer characteristics in public, industrial and commercial supply will need different LV network configurations and adequate switchgear and transformer layout. Especially for industrial supply systems with their high number of motors and high costs for supply interruptions, LV switchgear design is of great importance for flexible and reliable operation. Independent from individual supply characteristics in order to avoid uneconomical high losses, however, the substations with the MV/LV transformers should be located as close as possible to the LV load centers. The compact load center substations should be installed right in the industrial production area near to the LV consumers. The superposed medium-voltage system has to be configured to the needs of these substations and the available sources (main substation, generation) and leads again to different solutions for urban or rural public supply, industry and large building centers. In addition distribution management systems can be tailored to the needs, from small to large systems and for specific requirements.

Main substation with transformers up to 63 MVA HV switchgear

MV switchgear

Local medium-voltage distribution system

Feeder cable

Spot system

Connection of large consumer

Industrial supply and large buildings

Ring type Public supply

Medium voltage substations MV/LV substation looped in MV cable by load-break switchgear in different combinations for individual substation design, transformers up to 1000 kVA LV fuses

Circuitbreaker Loadbreak switch Consumer-connection substation looped in or connected to feeder cable with circuitbreaker and load-break switches for connection of spot system in different layout

MV/LV transformer level

Low-voltage supply system Public supply with pillars and house connections internal installation

Large buildings with distributed transformers vertical LV risers and internal installation per floor

Consumers

Fig. 2: Distribution: Principle configuration of distribution systems


Industrial supply with distributed transformers with subdistribution board and motor control center


Despite the individual layout of networks, common philosophy should be an utmost simple and clear network design to obtain ■ flexible system operation ■ clear protection coordination ■ short fault clearing time and ■ efficient system automation. The wide range of power requirements for individual consumers from a few kW to some MW, together with the high number of similar network elements, are the main characteristics of the distribution system and the reason for the comparatively high specific costs. Therefore, utmost standardization of equipment and use of maintenance-free components are of decisive importance for economical system layout. Siemens components and systems cater to these requirements based on worldwide experience in transmission and distribution networks. Protection, operation, control and metering Safe, reliable and economical energy supply is also a matter of fast, efficient and reliable system protection, data transmission and processing for system operation. The components required for protection and operation benefit from the rapid development of information and communication technology. Modern digital relays provide extensive possibilities for selective relay setting and protection coordination for fast fault clearing and minimized interruption times. Remote Terminal Units (RTUs) or Substation Automation Systems (SAS) provide the data for the centralized monitoring and control of the power plants and substations by the energy management system. Siemens energy management systems ensure a high supply quality, minimize generation and transmission costs and optimally manage the energy transactions. Modularity and open architecture offer the flexibility needed to cope with changed or new requirements originating e.g. from deregulation or changes in the supply area size. The broad range of applications includes generation control and scheduling, management of transmission and distribution networks, as well as energy trading. Metering devices and systems are important tools for efficiency and economy to survive in the deregulated market. For example, Demand Side Management (DSM) allows an electricity supply utility from a control center to remotely control certain consumers on the supply network for load control purposes. Energy meters are used for measuring the consumption of electricity, gas, heat and water for purposes of billing in the fields of households, commerce, industry and grid metering.

Power system substation Power system switchgear Bay protection – Overcurrent – Distance – Differential etc. Other bays

Bay switching interlocking Control Other bays

Bay coordination level

Substation coordination level BB and BF (busbar and breaker failure) protection

Substation control

Switchgear interlocking

Data and signal input/output

Data processing Automation Metering

Power network telecommunication systems

Other substations

Power line carrier communication

Other substations

Fiber-optic communication

System coordination level SCADA functions

Power and scheduling applications

Distribution management functions Grafical information systems

Network analysis

Training simulator

Control room equipment

Fig. 3: System Automation: Principle configuration of protection, control and communication systems Siemens Power Engineering Guide · Transmission and Distribution · 4th Edition


Overall solutions – System planning Of crucial importance for the quality of power transmission and distribution is the integration of diverse components to form overall solutions. Especially in countries where the increase in power consumption is well above the average besides the installation of generating capacity, construction and extension of transmission and distribution systems must be developed simultaneously and together with equipment for protection, supervision, control and metering. Also, for the existing systems, changing load structures, changing requirements due to energy market deregulation and liberalization and/ or environmental regulations, together with the need for replacement of aged equipment will require new installations. Integral power network solutions are far more than just a combination of products and components. Peculiarities in urban development, protection of the countryside and of the environment, and the suitability for expansion and harmonious integration in existing networks are just a few of the factors which future-oriented power system planning must take into account. Outlook The electrical energy supply (generation, transmission and distribution) is like a pyramid based on the number of components and their widespread use. This pyramid rests on a foundation formed by local expansion of the distribution networks and power demand in the overall system, which is determined solely by the consumers and their use of light, power and heat. These basic applications arise in many variations and different intensities throughout the entire private, commercial and industrial sector (Fig. 4). Reliability, safety and quality (i.e. voltage and frequency stability) of the energy supply are therefore absolute essentials and must be assured by the distribution networks and transmission systems.

Generation Transmission Distribution Consumers

Applications

Light

Power

Monitoring, Control, Automation

Fig. 4: Industrial applications


Heat

Energy Needs Intelligent Solutions

The changing state of the world’s energy markets and the need to conserve resources is promoting more intelligent solutions to the distribution of man’s silent servant, electricity. Change is generally wrought by necessity, often driven by a variety of factors, not least social, political, economic, environmental and technological considerations. Currently the world’s energy supply industries – principally gas and electricity – are in the process of undergoing radical and crucial change that is driven by a mixture of all these considerations. The collective name given to the factors affecting the electricity supply industry worldwide is deregulation. This is the changing operating scenario the electricity supply industry as a whole faces as it moves inexorably into the 21st century. How can it rise to the challenge of liberalized markets and the opportunities presented by deregulation? One of the answers is the better use of information technology and “intelligent” control to affect the necessary changes born of deregulation. However, to achieve this utilities need to be very sure of the technical and commercial competence of their systems suppliers. Failure could prove to be very costly not just in financial terms, but also for a utility’s reputation with its consumers in what is becoming increasingly a buyer’s market. Forming and maintaining close partnerships with long-established systems suppliers such as Siemens is the best way of ensuring success with deregulation into the millennium. Siemens can look back on over 100 years of working in close co-operation with power utilities throughout the world. This accumulated experience allows the company’s Power Transmission and Distribution Group to address not just technical issues, but also better appreciate many of the operational and commercial aspects of electricity distribution. Experience gained over the past decade with the many-and-varied aspects of deregulation puts the Group in an almost unique position to advise utilities as to the best solutions for taking full advantage of the opportunities offered by deregulation. Innovation the issue of change Although today’s technology obviously plays a very important role in the company’s current business, innovation has always been at the vanguard of its activities; indeed it is the common thread that has run through the company since its inception 150 years ago. In future power distribution technology, computer software, power electronics and superconductivity will play increasingly prominent roles in innovative solutions. Scope for new technol-

Fig. 5: Superconducting current limiter: lightning fast response

ogies is to be found in decentralized energy supply concepts and in meeting the needs of urban conurbations. Siemens is no longer just a manufacturer of systems and equipment, it is now much more. Overall concepts are becoming ever more important. All change! Power distribution technology has not changed significantly over the past forty years… indeed, the “rules of the game” have remained the same for a much longer period of time. A new challenge Recently decentralized power supply systems have cornered a growing share of the market for a number of reasons. In developing and industrializing countries, it has become clear that the energy policies and systems solutions adopted by nations with well-established energy infrastructures are not always appropriate. Frequently it is more prudent to start with small decentralized power networks and to expand later in a progressive way as demand and economics permit. Much benefit can also be gained if generation makes use of natural or indigenous resources such as the sun, water, wind or biomass. Countries that struggle with population growth and migration to the towns and cities clearly need to pay close attention to protecting their balance of payments. In such cases, the expansion of power supplies into the countryside

is a crucial factor in the economic and social development of a particular country. In the industrialized countries the concept of the “decentralized power supply” is also gaining ground, largely because of environmental concern. This has had its consequences for the generation of electricity: wind power is experiencing a renaissance, more development work is being carried out into photovoltaic devices and combined heat and power cogeneration plants are growing in popularity in many areas for both ecological and economic reasons. These developments are resulting in some entirely new energy network structures. Additional tasks... The scope and purpose of tomorrow’s distribution systems will no longer be to simply “supply electricity”. In future they will be required to “harvest” power and redistribute it more economically and take into account, among other considerations, environmental needs. In the past it was no easy task to supply precisely the right amount of electricity according to demand because, as is well-known, electricity cannot be readily stored and the loads were continually changing. Demand scheduling was very much based on statistical forecasting – not an exact science and one that cannot by its very nature take into account realtime variations. Demand scheduling problems can become particularly acute when power stations of limited generating capacity are on line.



Nowadays these and similar problems are not insoluble because of decentralized power supplies and the use of “intelligent” control. The Power Transmission and Distribution Group has developed concepts for the economic resolution of peak energy demand. One is to use energy stores. Batteries are an obvious choice, for these can be equipped with power electronics to enhance energy quality as well as storing electricity. Intelligent energy management… One of the options for matching the amount of electricity available to the amount being demanded is, even today, the rarely used technique of load control. Energy saving can mean much more than just consuming as few kilowatt-hours as possible. It can also mean achieving the flexibility of demand that can make a valuable contribution to a country’s economy. Naturally, in places such as hospitals, textile factories and electronic chip fabrication plants it is extremely important for the power supply not to fail – not even for a second. In other areas of electricity consumption, however, there is much more room for manoeuvre. Controlled interruptions of a few minutes, and even a few hours, can often be tolerated without causing very much difficulty to those involved. There are other applications where the time constant or resilience is high, e.g. cold stores and air-conditioning plants, where energy can be stored for periods of up to several hours. Through the application of “intelligent” control and with suitable financial encouragement (usually in the form of flexible tariff rates) there is no doubt that very much more could be made of load control. Improving energy quality… Power electronics systems, for example SIPCON, can help improve energy quality – an increasingly important factor in deregulated energy markets. Energy has now become a product. It has its price and a defined quality. Consumers want a definite quality of energy, but they also produce reaction effects on the system that are detrimental to quality (e.g. harmonics or reactive power). Energy quality first has to be measured and documented, for example with the SIMEAS® family of quality recorders. These measurements are important for price setting, and can serve as the basis for remedial action, such as with active or passive filters. Power electronics development has opened up many new possibilities here, although considerable progress may still be made in this area – a breakthrough in silicon carbide technology, for example.

Fig. 6: Silicon carbide

Fig. 7: GIL

Alternatives… It should be appreciated, however, that decentralized power supplies are not a panacea. For those places where energy density requirements are high, large power stations are still the answer, and especially when they can supply district heating. Theoretically, it should still be possible to employ conventional technology to transport very large amounts of electricity to the megacities of the 21st Century. Even if the use of overhead power lines was not an option, due to say there being insufficient space or


resistance from people living nearby, it would be possible to use gas-insulated lines (GIL), an economical alternative investigated by Siemens. The development aim of reducing costs has meanwhile been attained here, and costeffective applications involving distances of serveral kilometres are therefore possible. The system costs for the gas-insulated transmission lines (GIL) developed by Siemens exceed those of overhead lines only by about a factor of 10.


Energy management via satellite

Long-distance DC transmission Wind energy Solar energy

Power plants Converter station

Pumping station

Irrigation system

Biomass power plant

Switching station

Fuel cells

Energy store GIL

Distribution station

Cooling station (liquid nitrogen)

Fig. 8: The mega-cities of the 21st century and the open countryside will need different solutions – very high values of connection density in the former and decentralised configurations in the latter

This has been achieved by laying the tubular conductor using methods similar to those employed with pipelines. Savings were also made by simplifying and standardizing the individual components and by using a gas mixture consisting of sulfur hexafluoride (SF6) and nitrogen (N2). The advantages of this new technology are low resistive and capacitive losses. The electric field outside of the enclosure is zero, and the magnetic field is negligibly small. No cooling and no phase angle compensation are required. GILs are not a fire hazard and are simple to repair.

ers are demanding a more reasonable return on their investment. Deregulation generally means privatization; profit orientation is therefore clearly going to take over from concern with cost. In addition this means that competition will inevitably produce some concessions in the price of electricity, which will increase the pressure on energy suppliers. Many power supply companies are striving to introduce additional energy services, thereby making the pure price of energy not the only yardstick their customers apply when deciding how to make their purchases.

Energy trade The new “rules of the game” that are being introduced in power supply business everywhere are demanding more capability from utility IT systems, especially in areas such as energy trading. Siemens has been in the fortunate position of being able to accumulate early practical experience in this field in markets where deregulation is being introduced very quickly – such as the United Kingdom, Scandinavia and the USA – and so is now able to offer sophisticated systems and expertise with which utilities can get to grips with the demands of the new commercial environment. In the past it was always security of supply that took the highest priority for a utility. Now, however, although it remains an important subject, more and more sharehold-

Siemens – the energy systems house Siemens is offering solutions to the problems that are governed by the new “rules of the game”. The company possesses considerable expertise, mainly because it is a global player, but also because it covers the total spectrum of products necessary for the efficient transmission and distribution of electricity. As with other Groups within the company, Power Transmission and Distribution no longer regards itself as simply a purveyor of hardware. In future Siemens will be more of a provider of services and total solutions. This will mean embracing many new disciplines and skills, not least financial control and complete project management. One of the reasons is that in future “BOT” (Build, Operate & Transfer) compa-

nies and independent operating utilities will no longer confine their activities to just energy production; they will be expected to become increasingly involved in energy distribution too. Potential for the future The ongoing development of high-temperature superconductors will doubtless enable much to be achieved. Major operational innovations will, nonetheless, come from the more pervasive use of communications and data systems – two areas of technology where innovations can be seen every 18 months. Consequently, it will be from these areas that the enabling impetus for significant advances in power engineering will come.


High Voltage

Contents

Page

Introduction ...................................... 2/2 Air-Insulated Outdoor Substations ....................... 2/4 Circuit-Breakers General ............................................. 2/10 Circuit-Breakers 72 kV up to 245 kV .......................... 2/12 Circuit-Breakers 245 kV up to 800 kV ........................ 2/14 Live-Tank Circuit-Breakers .......... 2/16 Dead-Tank Circuit-Breakers ........ 2/20 Surge Arresters .............................. 2/24 Gas-Insulated Switchgear for Substations Introduction ..................................... 2/28 Main Product Range ..................... 2/29 Special Arrangements .................. 2/33 Specification Guide ....................... 2/34 Scope of Supply ............................. 2/37 Gas-insulated Transmission Lines (GIL) .............. 2/38 Overhead Power Lines ................. 2/40 High-Voltage Direct Current Transmission .................... 2/49 Power Compensation in Transmission Systems .................. 2/52

2

High-Voltage Switchgear for Substations

Introduction 1

2

3

4

5

6

7

8

9

High-voltage substations form an important link in the power transmission chain between generation source and consumer. Two basic designs are possible: Air-insulated outdoor switchgear of open design (AIS) AIS are favorably priced high-voltage substations for rated voltages up to 800 kV which are popular wherever space restrictions and environmental circumstances do not have to be considered. The individual electrical and mechanical components of an AIS installation are assembled on site. Air-insulated outdoor substations of open design are not completely safe to touch and are directly exposed to the effects of weather and the environment (Fig. 1).

Fig. 1: Outdoor switchgear

Gas-insulated indoor or outdoor switchgear (GIS) GIS compact dimensions and design make it possible to install substations up to 550 kV right in the middle of load centers of urban or industrial areas. Each circuitbreaker bay is factory assembled and includes the full complement of isolator switches, grounding switches (regular or make-proof), instrument transformers, control and protection equipment, interlocking and monitoring facilities commonly used for this type of installation. The earthed metal enclosures of GIS assure not only insensitivity to contamination but also safety from electric shock (Fig. 2). Gas-insulated transmission lines (GIL) A special application of gas-insulated equipment are gas-insulated transmission lines (GIL). They are used where high-voltage overhead lines are not suitable for any reason. GIL have a high power transmission capability, even when laid underground, low resistive and capacitive losses and low electromagnetic fields.

10

Fig. 2: GIS substations in metropolitan areas

2/2


High-Voltage Switchgear for Substations

Turnkey Installations High-voltage switchgear is normally combined with transformers and other equipment to complete transformer substations in order to ■ Step-up from generator voltage level to high-voltage system (MV/HV) ■ Transform voltage levels within the high-voltage grid system(HV/HV) ■ Step-down to medium-voltage level of distribution system (HV/MV)

Major components, e.g. transformer Substation Control Control and monitoring, measurement, protection, etc.

Structural Steelwork Gantries and substructures

Design

AC/DC es ri auxililia

we

rc

ab les Contro l and signal c ables

Ancillary equipment

Po

rge s Su erter div g in rth e m a E st sy

2

Civil Engineering Buildings, roads, foundations

3

Fire protection Env iron pro menta tec tion l Li gh tn in g

4

ion lat n ti Ve frequ. Carrier- ent equipm

The High Voltage Division plans and constructs individual high-voltage switchgear installations or complete transformer substations, comprising high-voltage switchgear, medium-voltage switchgear, major components such as transformers, and all ancillary equipment such as auxiliaries, control systems, protective equipment, etc., on a turnkey basis or even as general contractor. The spectrum of installations supplied ranges from basic substations with single busbar to regional transformer substations with multiple busbars or 1 1/2 circuit-breaker arrangement for rated voltages up to 800 kV, rated currents up to 8000 A and short-circuit currents up to 100 kA, all over the world. The services offered range from system planning to commissioning and after-sales service, including training of customer personnel. The process of handling such an installation starts with preparation of a quotation, and proceeds through clarification of the order, design, manufacture, supply and cost-accounting until the project is finally billed. Processing such an order hinges on methodical data processing that in turn contributes to systematic project handling. All these high-voltage installations have in common their high-standard of engineering, which covers power systems, steel structures, civil engineering, fire precautions, environmental protection and control systems (Fig. 3). Every aspect of technology and each work stage is handled by experienced engineers. With the aid of high-performance computer programs, e.g. the finite element method (FEM), installations can be reliably designed even for extreme stresses, such as those encountered in earthquake zones. All planning documentation is produced on modern CAD systems; data exchange with other CAD systems is possible via standardized interfaces. By virtue of their active involvement in national and international associations and standardization bodies, our engineers are

1

5

6

Fig. 3: Engineering of high-voltage switchgear

always fully informed of the state of the art, even before a new standard or specification is published. Quality/Environmental Management Our own high-performance, internationally accredited test laboratories and a certified QM system testify to the quality of our products and services. Milestones: ■ 1983: Introduction of a quality system on the basis of Canadian standard CSA Z 299 Level 1 ■ 1989: Certification of the SWH quality system in accordance with DIN EN ISO 9001 by the German Association for Certification of Quality Systems (DQS) ■ 1992: Repetition audit and extension of the quality system to the complete EV H Division ■ 1992: Accreditation of the test laboratories in accordance with DIN EN 45001 by the German Accreditation Body for Technology (DATech) ■ 1994: Certification of the environmentalsystems in accordance with DIN EN ISO 14001 by the DQS ■ 1995: Mutual QEM Certificate


Know how, experience and worldwide presence A worldwide network of liaison and sales offices, along with the specialist departments in Germany, support and advise our customers in all matters of switchgear technology. Siemens has for many years been a leading supplier of high-voltage equipment, regardless of whether AIS, GIS or GIL has been concerned. For example, outdoor substations of longitudinal in-line design are still known in many countries under the Siemens registered tradename “Kiellinie”. Back in 1968, Siemens supplied the world’s first GIS substation using SF6 as insulating and quenching medium. Gas-insulated transmission lines have featured in the range of products since 1976.

2/3

7

8

9

10

Design of Air-Insulated Outdoor Substations

Standards 1

2

3

4

5

6

Air-insulated outdoor substations of open design must not be touched. Therefore, air-insulated switchgear (AIS) is always set up in the form of a fenced-in electrical operating area, to which only authorized persons have access. Relevant IEC 60060 specifications apply to outdoor switchgear equipment. Insulation coordination, including minimum phaseto-phase and phase-to-ground clearances, is effected in accordance with IEC 60071. Outdoor switchgear is directly exposed to the effects of the environment such as the weather. Therefore it has to be designed based on not only electrical but also environmental specifications. Currently there is no international standard covering the setup of air-insulated outdoor substations of open design. Siemens designs AIS in accordance with DIN/VDE standards, in line with national standards or customer specifications. The German standard DIN VDE 0101 (erection of power installations with rated voltages above 1 kV) demonstrates typically the protective measures and stresses that have to be taken into consideration for airinsulated switchgear. Protective measures

7

ker

8

9

10

Protective measures against direct contact, i. e. protection in the form of covering, obstruction or clearance and appropriately positioned protective devices and minimum heights. Protective measures against indirect touching by means of relevant grounding measures in accordance with DIN VDE 0141. Protective measures during work on equipment, i.e. during installation must be planned such that the specifications of DIN EN 50110 (VDE 0105) (e.g. 5 safety rules) are complied with ■ Protective measures during operation, e.g. use of switchgear interlock equipment ■ Protective measures against voltage surges and lightning strike ■ Protective measures against fire, water and, if applicable, noise insulation.

2/4

Stresses ■ Electrical stresses, e.g. rated current, short-circuit current, adequate creepage distances and clearances ■ Mechanical stresses (normal stressing), e.g. weight, static and dynamic loads, ice, wind ■ Mechanical stresses (exceptional stresses), e.g. weight and constant loads in simultaneous combination with maximum switching forces or shortcircuit forces, etc. ■ Special stresses, e.g. caused by installation altitudes of more than 1000 m above sea level, or earthquakes

Variables affecting switchgear installation Switchgear design is significantly influenced by: ■ Minimum clearances (depending on rated voltages) between various active parts and between active parts and earth ■ Arrangement of conductors ■ Rated and short-circuit currents ■ Clarity for operating staff ■ Availability during maintenance work, redundancy ■ Availability of land and topography ■ Type and arrangement of the busbar disconnectors The design of a substation determines its accessibility, availability and clarity. The design must therefore be coordinated in close cooperation with the customer. The following basic principles apply: Accessibility and availability increase with the number of busbars. At the same time, however, clarity decreases. Installations involving single busbars require minimum investment, but they offer only limited flexibility for operation management and maintenance. Designs involving 1 1/2 and 2 circuit-breaker arrangements assure a high redundancy, but they also entail the highest costs. Systems with auxiliary or bypass busbars have proved to be economical. The circuit-breaker of the coupling feeder for the auxiliary bus allows uninterrupted replacement of each feeder circuit-breaker. For busbars and feeder lines, mostly wire conductors and aluminum are used. Multiple conductors are required where currents are high. Owing to the additional shortcircuit forces between the subconductors (pinch effect), however, multiple conductors cause higher mechanical stressing at the tension points. When wire conductors, particularly multiple conductors, are used higher short-circuit currents cause a rise not only in the aforementioned pinch effect but in further force maxima in the event of swinging and dropping of the conductor bundle (cable pull). This in turn results in higher mechanical stresses on the switchgear components. These effects can be calculated in an FEM (Finite Element Method) simulation (Fig. 4).



When rated and short-circuit currents are high, aluminum tubes are increasingly used to replace wire conductors for busbars and feeder lines. They can handle rated currents up to 8000 A and short-circuit currents up to 80 kA without difficulty. Not only the availability of land, but also the lie of the land, the accessibility and location of incoming and outgoing overhead lines together with the number of transformers and voltage levels considerably influence the switchgear design as well. A one or two-line arrangement, and possibly a U arrangement, may be the proper solution. Each outdoor switchgear installation, especially for step-up substations in connection with power stations and large transformer substations in the extra-highvoltage transmission system, is therefore unique, depending on the local conditions. HV/MV transformer substations of the distribution system, with repeatedly used equipment and a scheme of one incoming and one outgoing line as well as two transformers together with medium-voltage switchgear and auxiliary equipment, are more subject to a standardized design from the individual power supply companies.

Preferred designs 1

The multitude of conceivable designs include certain preferred versions, which are dependent on the type and arrangement of the busbar disconnectors:

2

H arrangement The H arrangement (Fig. 5) is preferrably used in applications for feeding industrial consumers. Two overhead lines are connected with two transformers and interlinked by a single-bus coupler. Thus each feeder of the switchgear can be maintained without disturbance of the other feeders. This arrangement assures a high availability.

3

4 Special layouts for single busbars up to 145 kV with withdrawable circuit-breaker and modular switchbay arrangement Further to the H arrangement that is built in many variants, there are also designs with withdrawable circuit-breakers and modular switchbays for this voltage range. For detailed information see the following pages:

5

6 Vertical displacement in m

– Q8

– Q8

– Q0

– Q0

–0.6

7

–0.8

M

–1.0 –1.2

– Q1

– Q1

– T5

– T5

– T1

– T1

M

8

–1.4 – T1 –1.6 – Q1 M –1.8 Horizontal displacement in m

–2.0 –2.2 –1.4

–1.0

–0.6

–0.2

0

0.2

0.6

Fig. 4: FEM calculation of deflection of wire conductors in the event of short circuit


1.0

1.4

M

– Q10

– T1

M

– Q11

M

– Q0 – F1 = T1

– Q1

9

– Q0 – F1 = T1

Fig. 5: Module plan view

2/5

10


Withdrawable circuit-breaker

1

2

General For 123/145 kV substations with single busbar system a suitable alternative is the withdrawable circuit-breaker. In this kind of switchgear busbar- and outgoing disconnector become inapplicable (switchgear

without disconnectors). The isolating distance is reached with the moving of the circuit-breaker along the rails, similar to the well-known withdrawable-unit design technique of medium-voltage switchgear. In disconnected position busbar, circuit-breaker and outgoing circuit are separated from each other by a good visible isolating dis-

6300 17001700

2500 2500

3 7600

-Q11-Q12

4

2530 7000

3000 6400

2247 -Q11 -T1/ 1050 -Q12 -Q9 -T5 -Q0 -Q0 -T1 3100 625 7000 625 3100 2500 4500 14450 21450

=T1 -F1 2530 7000

5

6

7 Fig. 6a: H arrangement with withdrawable circuit-breaker, plan view and sections

8

9

tance. An electromechanical motive unit ensures the uninterrupted constant moving motion to both end positions. The circuitbreaker can only be operated if one of the end positions has been reached. Movement with switched-on circuit-breaker is impossible. Incorrect movement, which would be equivalent to operating a disconnector under load, is interlocked. In the event of possible malfunction of the position switch, or of interruptions to travel between disconnected position and operating position, the operation of the circuitbreaker is stopped. The space required for the switchgear is reduced considerably. Due to the arrangement of the instrument transformers on the common steel frame a reduction in the required space up to about 45% in comparison to the conventional switchgear section is achieved. Description A common steel frame forms the base for all components necessary for reliable operation. The withdrawable circuit-breaker contains: ■ Circuit-breaker type 3AP1F ■ Electromechanical motive unit ■ Measuring transformer for protection and measuring purposes ■ Local control cubicle All systems are preassembled as far as possible. Therefore the withdrawable CB can be installed quite easily and efficiently on site. The advantages at a glance ■ Complete system and therefore lower costs for coordination and adaptation. ■ A reduction in required space by about 45% compared with conventional switchbays ■ Clear wiring and cabling arrangement ■ Clear circuit state ■ Use as an indoor switchbay is also possible.

Technical data

10

Fig. 6b: H arrangement with withdrawable circuit-breaker, ISO view

2/6

Nominal voltage [kV]

123 kV (145 kV)

Nominal current [A]

1250 A (2000 A)

Nominal short time current

31.5 kA, 1s, (40 kA, 3s)

[kA]

Auxiliary supply/ motive unit [V]

230/400 V AC

Control voltage

220 V DC

[V]

Fig. 7: Technical data



Description A common steel frame forms the base for all components necessary for a reliable operation. The modul contains: ■ Circuit-breaker type 3AP1F ■ Motor-operated disconnecting device ■ Current transformer for protection and measuring purposes ■ Local control cubicle All systems are preassembled as far as possible. Therefore the module can be installed quite easily and efficiently on site.

Modular switchbay

General As an alternative to conventional substations an air-insulated modular switchbay can often be used for common layouts. In this case the functions of several HV devices are combined with each other. This makes it possible to offer a standardized module. Appropriate conventional air-insulated switchbays consist of separately mounted HV devices (for example circuit-breaker, disconnector, earthing switches, transformers), which are connected to each other by conductors/tubes. Every device needs its own foundations, steel structures, earthing connections, primary and secondary terminals (secondary cable routes etc.).

The advantages at a glance ■ Complete system and therefore lower costs for coordination and adaptation. ■ Thanks to the integrated control cubicle, upgrading of the control room is scarecely necessary. ■ A modular switchbay can be inserted very quickly in case of total breakdown or for temporary use during reconstruction. ■ A reduction in required space by about 50% compared with conventional switchbays is achieved by virtue of the compact and tested design of the module (Fig. 8). ■ The application as an indoor switchbay is possible.

1

2

3

4 Technical data

3000

2000 2000

8000

-Q8 -Q0-Q1 -T1 -Q10/-Q11 -T1 -Q1 -Q0 -F1 -T5 3000

4500

4500

7500

3000

=T1

Nominal voltage

123 kV (145 kV)

Nominal current

1250 A (2000 A)

Nominal short current

31.5 kA, 1s, (40 kA, 3s)

Auxiliary supply

230/400 V AC

Control voltage

220 V DC

5

6

Fig. 9: Technical data

4000

11500

7

8

8000 9500

19000

3000

9

A A

9500

10

8000

11500

7500 19000 Fig. 8: Plan view and side view of H arrangement with modular switchbays


2/7


1

2

3

In-line longitudinal layout, with rotary disconnectors, preferable up to 170 kV The busbar disconnectors are lined up one behind the other and parallel to the longitudinal axis of the busbar. It is preferable to have either wire-type or tubular busbars located at the top of the feeder conductors. Where tubular busbars are used, gantries are required for the outgoing overhead lines only. The system design requires only two conductor levels and is therefore clear. If, in the case of duplicate busbars, the second busbar is arranged in U form relative to the first busbar, it is possible to arrange feeders going out on both sides of the busbar without a third conductor level (Fig. 10).

Dimensions in mm 2500

Section A-A R1 S1 T1 T2 S2 R2

8000 8400 48300

20500

19400 Top view

6500 End bay

9000 4500

A

Normal 9000 bay A

4

Fig. 10: Substation with rotary disconnector, in-line design

5

6

7

Central tower layout with rotary disconnectors, normally only for 245 kV The busbar disconnectors are arranged side by side and parallel to the longitudinal axis of the feeder. Wire-type busbars located at the top are commonly used; tubular busbars are also conceivable. This arrangement enables the conductors to be easliy jumpered over the circuit-breakers and the bay width to be made smaller than that of in-line designs. With three conductor levels the system is relatively clear, but the cost of the gantries is high (Fig. 11).

Dimensions in mm 3000 12500 9000 7000

18000

17000

17000

16000

8 Fig.11: Central tower design

Diagonal layout with pantograph disconnectors, preferable up to 245 kV

9

10

The pantograph disconnectors are placed diagonally to the axis of the busbars and feeder. This results in a very clear, spacesaving arrangement. Wire and tubular conductors are customary. The busbars can be located above or below the feeder conductors (Fig. 12).

Section

Dimensions in mm Bypass bus

Bus system 13300 10000 8000

28000

48000

10000

10400 Top view 5000 18000 4000 4000 5000

Fig. 12: Busbar area with pantograph disconnector of diagonal design, rated voltage 420 kV

2/8



1 1/2 circuit-breaker layout, preferable up to 245 kV

Planning principles 1

The 1 1/2 circuit-breaker arrangement assures high supply reliability; however, expenditure for equipment is high as well. The busbar disconnectors are of the pantograph, rotary and vertical-break type. Vertical-break disconnectors are preferred for the feeders. The busbars located at the top can be of wire or tubular type. Of advantage are the equipment connections, which are very short and enable (even in the case of multiple conductors) high short-circuit currents to be mastered. Two arrangements are customary: ■ External busbar, feeders in line with three conductor levels ■ Internal busbar, feeders in H arrangement with two conductor levels (Fig. 13).

For air-insulated outdoor substations of open design, the following planning principles must be taken into account: ■ High reliability – Reliable mastering of normal and exceptional stresses – Protection against surges and lightning strikes – Protection against surges directly on the equipment concerned (e.g. transformer, HV cable)

2

3

■ Good clarity and accessibility

Dimensions in mm 4000

17500

– Clear conductor routing with few conductor levels – Free accessibility to all areas (no equipment located at inaccessible depth) – Adequate protective clearances for installation, maintenance and transportation work – Adequately dimensioned transport routes

4

5

■ Positive incorporation into surroundings

8500

48000

29000

– As few overhead conductors as possible – Tubular instead of wire-type busbars – Unobtrusive steel structures – Minimal noise and disturbance level

6

■ EMC grounding system

18000

for modern control and protection

7

■ Fire precautions and environmental

Fig.13 : 1 1/2 Circuit-breaker design

protection – Adherence to fire protection specifications and use of flame-retardant and nonflammable materials – Use of environmentally compatible technology and products

8

For further information please contact: Fax: ++ 49 - 9131- 73 18 58 e-mail: [email protected]

9

10


2/9

Circuit-Breakers for 72 kV up to 800 kV

General 1

2

3

4

5

Circuit-breaker for air-insulated switchgear Circuit-breakers are the main module of both AIS and GIS switchgear. They have to meet high requirements in terms of: ■ Reliable opening and closing ■ Consistent quenching performance with rated and short-circuit currents even after many switching operations ■ High-performance, reliable maintenancefree operating mechanisms. Technology reflecting the latest state of the art and years of operating experience are put to use in constant further development and optimization of Siemens circuitbreakers. This makes Siemens circuitbreakers able to meet all the demands placed on high-voltage switchgear. The comprehensive quality system, ISO 9001 certified, covers development, manufacture, sales, installation and aftersales service. Test laboratories are accredited to EN 45001 and PEHLA/STL.

Main construction elements 6

7

8

9

Each circuit-breaker bay for gas-insulated switchgear includes the full complement of isolator switches, grounding switches (regular or proven), instrument transformers, control and protection equipment, interlocking and monitoring facilities commonly used for this type of installation (See chapter GIS, page 2/30 and following). Circuit-breakers for air-insulated switchgear are individual components and are assembled together with all individual electrical and mechanical components of an AIS installation on site. All Siemens circuit-breaker types, whether air or gas-insulated, are made up of the same range of components, i.e.: ■ Interrupter unit ■ Operating mechanism ■ Sealing system ■ Operating rod ■ Control elements.

Control elements

Operating mechanism

Interrupter unit

10

Circuit-breaker in SF6-insulated switchgear Fig. 14: Circuit-breaker parts

2/10



Interrupter unit – two arc-quenching principles The Siemens product range includes highvoltage circuit-breakers with self-compression interrupter chambers and twin-nozzle interrupter chambers – for optimum switching performance under every operating condition for every voltage level. Self-compression breakers 3AP high-voltage circuit-breakers for the lower voltage range ensure optimum use of the thermal energy of the arc in the contact tube. This is achieved by the selfcompression switching unit. Siemens patented this arc-quenching principle in 1973. Since then, we have continued to develop the technology of the selfcompression interrupter chamber. One of the technical innovations is that the arc energy is being increasingly used to quench the arc. In short-circuit breaking operations the actuating energy required is reduced to that needed for mechanical contact movement. That means the operating energy is truly minimized. The result is that the selfcompression interrupter chamber allows the use of a compact stored-energy spring mechanism with unrestrictedly high dependability. Twin-nozzle breakers On the 3AQ and 3AT switching devices, a contact system with graphite twin-nozzles ensures consistent arc-quenching behavior and constant electric strength, irrespective of pre-stressing, i.e. the number of breaks and the switched current. The graphite twin-nozzles are resistant to burning and thus have a very long service life. As a consequence, the interrupter unit of the twin-nozzle breaker is particularly powerful. Moreover, this type of interrupter chamber offers other essential advantages. Generally, twin-nozzle interrupter chambers operate with low overpressures during arcquenching. Minimal actuating energy is adequate in this operating system as well. The resulting arc plasma has a comparatively low conductivity, and the switching capacity is additionally favourably influenced as a result.

The twin-nozzle system has also proven itself in special applications. Its specific properties support switching without restriking of small inductive and capacitive currents. By virtue of its high arc resistance, the twin-nozzle system is particularly suitable for breaking certain types of short circuit (e.g. short circuits close to generator terminals) on account of its high arc resistance.

Specific use of the electrohydraulic mechanism

Operating mechanism – two principles for all specific requirements

Advantages of the electrohydraulic mechanism at a glance:

The operating mechanism is a central module of the high-voltage circuit-breakers. Two different mechanism types are available for Siemens circuit-breakers: ■ Stored-energy spring actuated mechanism, ■ Electrohydraulic mechanism, depending on the area of application and voltage level, thus every time ensuring the best system of actuation. The advantages are trouble-free, economical and reliable circuit-breaker operation for all specific requirements. Specific use of the stored-energy spring mechanism The actuation concept of the 3AP high-voltage circuit-breaker is based on the storedenergy spring principle. The use of such an operating mechanism in the lower voltage range became appropriate as a result of development of a self-compression interrupter chamber that requires only minimal actuation energy.

The actuating energy required for the 3AQ and 3AT high-voltage circuit-breakers at higher voltage levels is provided by proven electrohydraulic mechanisms. The interrupter chambers of these switching devices are based on the graphite twin-nozzle system.

■ Electrohydraulic mechanisms provide the

high actuating energy that makes it possible to have reliable control even over very high switching capacities and to be in full command of very high loads in the shortest switching time. ■ The switch positions are held safely even in the event of an auxiliary power failure. ■ A number of autoreclosing operations are possible without the need for recharging. ■ Energy reserves can be reliably controlled at any time. ■ Electrohydraulic mechanisms are maintenance-free, economical and have a long service life. ■ They satisfy the most stringent requirements regarding environmental safety. This has been proven by electrohydraulic mechanisms in Siemens high-voltage circuit-breakers over many years of service.

1

2

3

4

5

6

7

8

Advantages of the stored-energy spring mechanism at a glance:

9

■ The stored-energy spring mechanism of-

fers the highest degree of operational safety. It is of simple and sturdy design – with few moving parts. Due to the self-compression principle of the interrupter chamber, only low actuating forces are required. ■ Stored-energy spring mechanisms are readily available and have a long service life: Minimal stressing of the latch mechanisms and rolling-contact bearings in the operating mechanism ensure reliable and wear-free transmission of forces. ■ Stored-energy spring mechanisms are maintenance-free: the spring charging gear is fitted with wear-free spur gears, enabling load-free decoupling.


10

2/11


1

2

Siemens circuit-breakers for the lower voltage levels 72 kV up to 245 kV, whether for air-insulated or gas-insulated switchgear, are equipped with self-compression switching units and spring-stored energy operating mechanisms.

The interrupter unit Self-compression system

3

4

The current path is formed by the terminal plates (1) and (8), the contact support (2), the base (7) and the moving contact cylinder (6). In closed state the operating current flows through the main contact (4). An arcing contact (5) acts parallel to this.

Closed position

6

7

1 2 3 4 5

8 6

Major features:

During the opening process, the main contact (4) opens first and the current commutates on the still closed arcing contact. If this contact is subsequently opened, an arc is drawn between the contacts (5). At the same time, the contact cylinder (6) moves into the base (7) and compresses the quenching gas there. The gas then flows in the reverse direction through the contact cylinder (6) towards the arcing contact (5) and quenches the arc there.

■ ■ ■ ■

Self-compression interrupter chamber Use of the thermal energy of the arc Minimized energy consumption High reliability for a long time

Breaking fault currents

The current path

5

Breaking operating currents

In the event of high short-circuit currents, the quenching gas on the arcing contact is heated substantially by the energy of the arc. This leads to a rise in pressure in the contact cylinder. In this case the energy for creation of the required quenching pressure does not have to be produced by the operating mechanism. Subsequently, the fixed arcing contact releases the outflow through the nozzle (3). The gas flows out of the contact cylinder back into the nozzle and quenches the arc.

Opening Main contact open

Opening Arcing contact open

Open position

1 2 3 4 5 6

Terminal plate Contact support Nozzle Main contact Arc contact Contact cylinder 7 Base 8 Terminal plate

9 7

10

8

Fig. 15: The interrupter unit

2/12



The operating mechanism 1 2 3 4 5 6 7

Spring-stored energy type Siemens circuit-breakers for voltages up to 245 kV are equipped with spring-stored energy operating mechanisms. These drives are based on the same principle that has been proving its worth in Siemens low and medium-voltage circuit-breakers for decades. The design is simple and robust with few moving parts and a vibration-isolated latch system of highest reliability. All components of the operating mechanism, the control and monitoring equipment and all terminal blocks are arranged compact and yet clear in one cabinet. Depending on the design of the operating mechanism, the energy required for switching is provided by individual compression springs (i.e. one per pole) or by springs that function jointly on a triple-pole basis. The principle of the operating mechanism with charging gear and latching is identical on all types. The differences between mechanism types are in the number, size and arrangement of the opening and closing springs.

1

2

10

8 9 10 11 12 13 14 15 16

6

11

17 18

7

12 13

3 9

4 5

Corner gears Coupling linkage Operating rod Closing release Cam plate Charging shaft Closing spring connecting rod Closing spring Hand-wound mechanism Charging mechanism Roller level Closing damper Operating shaft Opening damper Opening release Opening spring connecting rod Mechanism housing Opening spring

■ ■

3

4

5

14

■ Uncomplicated, robust construction ■ ■ ■

2

6

Major features at a glance with few moving parts Maintenance-free Vibration-isolated latches Load-free uncoupling of charging mechanism Ease of access 10,000 operating cycles

1

15 16

7

17 8 18

8 Fig. 16

9

10

Fig. 17: Combined operating mechanism and monitoring cabinet


2/13


1

Siemens circuit-breakers for the higher voltage levels 245 kV up to 800 kV, whether for air-insulated or gas-insulated switchgear, are equipped with twin-nozzle interrupter chambers and electrohydraulic operating mechanisms.

2 The interrupter unit 3

4

Twin-nozzle system Current path assembly The conducting path is made up of the terminal plates (1 and 7), the fixed tubes (2) and the spring-loaded contact fingers arranged in a ring in the moving contact tube (3).

5

6

7

Breaker in closed position

Arc-quenching assembly

Major features

The fixed tubes (2) are connected by the contact tube (3) when the breaker is closed. The contact tube (3) is rigidly coupled to the blast cylinder (4), the two together with a fixed annular piston (5) in between forming the moving part of the break chamber. The moving part is driven by an operating rod (8) to the effect that the SF6 pressure between the piston (5) and the blast cylinder (4) increases. When the contacts separate, the moving contact tube (3), which acts as a shutoff valve, releases the SF6. An arc is drawn between one nozzle (6) and the contact tube (3). It is driven in a matter of milliseconds between the nozzles (6) by the gas jet and its own electrodynamic forces and is safely extinguished. The blast cylinder (4) encloses the arcquenching arrangement like a pressure chamber. The compressed SF6 flows radially into the break by the shortest route and is discharged axially through the nozzles (6). After arc extinction, the contact tube (3) moves into the open position. In the final position, handling of test voltages in accordance with IEC 60000 and ANSI is fully assured, even after a number of short-circuit switching operations.

■ Erosion-resistant graphite nozzles ■ Consistently high dielectric strength ■ Consistent quenching capability across

Precompression

Gas flow during arc quenching

the entire performance range ■ High number of short-circuit breaking

operations ■ High levels of availability ■ Long maintenance intervals.

Breaker in open position

1 1 Upper terminal

8

plate

2 3 6

9

4 5 2

10

8

2 Fixed tubes 3 Moving contact tube Arc

4 Blast cylinder 5 Blast piston 6 Arc-quenching nozzles

7 Lower terminal plate

8 Operating rod

7

Fig. 18: The interrupter unit

2/14



The operating mechanism Electrohydraulic type All hydraulically operated Siemens circuitbreakers have a uniform operating mechanism concept. Identical operating mechanisms (modules) are used for single or triple-pole switching of outdoor circuitbreakers. The electrohydraulic operating mechanisms have proved their worth all over the world. The power reserves are ample, the switching speed is high and the storage capacity substantial. The working capacity is indicated by the permanent self-monitoring system. The force required to move the piston and piston rod is provided by differential oil pressure inside a sealed system. A hydraulic storage cylinder filled with compressed nitrogen provides the necessary energy. Electromagnetic valves control the oil flow between the high and low-pressure side in the form of a closed circuit.

■ Tripping:

The hydraulic valve is changed over electromagnetically, thus relieving the larger piston surface of pressure and causing the piston to move onto the OFF position. The breaker is ready for instant operation because the smaller piston surface is under constant pressure. Two electrically separate tripping circuits are available for changing the valve over for tripping.

1

2

3

4

5

Main features: ■ Plenty of operating energy ■ Long switching sequences ■ Reliable check of energy reserves ■

■ ■ ■ ■

at any time Switching positions are reliably maintained, even when the auxiliary supply fails Excessive strong foundations Low-noise switching No oil leakage and consequently environmentally compatible Maintenance-free.

6

Fig. 19: Operating unit of the Q range AIS circuit breakers

Monitoring unit and hydraulic pump with motor

Description of function

Fig. 20: Operating cylinder with valve block and magnetic releases

P

P

7

P

P

8

Oil tank

■ Closing:

The hydraulic valve is opened by electromagnetic means. Pressure from the hydraulic storage cylinder is thereby applied to the piston with two different surface areas. The breaker is closed via couplers and operating rods moved by the force which acts on the larger surface of the piston. The operating mechanism is designed to ensure that, in the event of a pressure loss, the breaker remains in the particular position.

Hydraulic storage cylinder

M

M

9

N2

Operating cylinder

10 Operating piston Main valve

Auxiliary switch

Pilot control Releases

On

Off

Fig. 21: Schematic diagram of a Q-range operating mechanism


2/15

Live-Tank Circuit-Breakers for 72 kV up to 800 kV

1

Circuit-breakers for air-insulated switchgear Standard live-tank breakers The construction

2

3

4

5

6

7

All live-tank circuit-breakers are of the same general design, as shown in the illustrations. They consist of the following main components: 1) Interrupter unit 2) Closing resistor (if applicable) 3) Operating mechanism 4) Insulator column (AIS) 5) Operating rod 6) Breaker base 7) Control unit The uncomplicated design of the breakers and the use of many similar components, such as interrupter units, operating rods and control cabinets, ensure high reliability because the experience of many breakers in service has been applied in improvement of the design. The twin nozzle interrupter unit for example has proven its reliability in more than 60,000 units all over the world. The control unit includes all necessary devices for circuit-breaker control and monitoring, such as: ■ Pressure/SF6 density monitors ■ Gauges for SF6 and hydraulic pressure (if applicable) ■ Relays for alarms and lockout ■ Antipumping devices ■ Operation counters (upon request) ■ Local breaker control (upon request) ■ Anticondensation heaters.

Fig. 22: 145 kV circuit-breaker 3AP1FG with triple-pole spring stored-energy operating mechanism

Fig. 23: 800 kV circuit-breaker 3AT5

8

9

Transport, installation and commissioning are performed with expertise and efficiency. The tested circuit-breaker is shipped in the form of a small number of compact units. If desired, Siemens can provide appropriately qualified personnel for installation and commissioning.

10

Fig. 24: 245 kV circuit-breaker 3AQ2

2/16



1 1

1

7

2

3

5 6

2

2 8

5

3

1 2 3 4

Interrupter unit Closing resistor Valve unit Electrohydraulic operating mechanism 5 Insulator columns 6 Breaker base 7 Control unit

9 13 12

4

10 11 4

5

3 4 7 6 Fig. 25: Type 3AT4/5

1

1 2 3 4 5 6 7 8 9 10 11 12 13

Interrupter unit Arc-quenching nozzles Moving contact Filter Blast piston Blast cylinder Bell-crank mechanism Insulator column Operating rod Hydraulic operating mechanism ON/OFF indicator Oil tank Control unit

6

7

8

Fig. 27: Type 3AQ2

9

2

10

3 5 4

1 2 3 4

Interrupter unit

Post insulator Circuit-breaker base Operating mechanism and control cubicle

5 Pillar Fig. 26: Type 3AP1FG


2/17


1

Technical data

2

3

4

5

6

7

8

9

10

Type Rated voltage Number of interrupter units per pole Rated power-frequency withstand voltage 1 min. Rated lightning impulse withstand voltage 1.2 / 50 µs Rated switching impulse withstand voltage Rated current up to Rated short-time current (3 s) up to Rated peak withstand current up to Rated short-circuit-breaking current up to Rated short-circuit making current up to Rated duty cycle Break time Frequency Operating mechanism type Control voltage Motor voltage Design data of the basic version: Clearance Phase/earth in air across the contact gap Minimum creepage Phase/earth distance across the contact gap Dimensions Height Width Depth Distance between pole centers Weight of circuit-breaker Inspection after

3AP1/3AQ1

3AP2/3AQ2

72.5

123

145

170

245/300

362

1

1

1

1

1

2

2

[kV]

140

230

275

325

460

520

610

[kV]

325

550

650

750

1050

1175

1425

[kV]

–

–

–

–

–/850

950

1050

[A] [kA] [kA] [kA]

4000

4000

4000

4000

4000

4000

4000

40

40

40

40/50

50

63

63

108

108

108

135

135

170

170

40

40

40

40/50

50

63

63

[kA]

108

108

108

135

135

170

170

3

3

3

3

3

3

3

50/60

50/60

50/60

50/60

50/60

[kV]

O - 0.3 s - CO - 3 min - CO

[cycles] [Hz]

50/60 50/60

or

420

CO - 15 s - CO

Spring-stored energy mechanism/Electrohydraulic mechanism

[V, DC] [V, DC] [V, DC]

60…250 60…250 120…240, 50/60 Hz

[mm] [mm] [mm] [mm]

700 1200

1250 1200

1250 1200

1500 1400

2200 1900/2200

2750 2700

3400 3200

2248 3625

3625 3625

3625 3625

4250 4250

6150/7626 6125/7500

7875 9050

10375 10500

[mm] [mm] [mm] [mm] [kg]

2750 3200 660 1350

3300 3900 660 1700

3300 3900 660 1700

4030 4200 660 1850

5220/5520 6600/7000 800 2800/3000

4150 8800 3500 3800

4800 9400 4100 4100

1350

1500

1500

1600

3000

4700

5000

25 years

Fig. 28a

2/18



1

2

3

3AT2/3AT3*

4

3AT4/3AT5*

245

300

362

420

550

362

420

550

2

2

2

2

2

4

4

4

800 4

460

460

520

610

800

520

610

800

1150

1050

1050

1175

1425

1550

1175

1425

1550

2100

–

850

950

1050

1175

950

1050

1175

1425

4000

4000

4000

4000

4000

4000

4000

4000

4000

6

80

63

63

63

63

80

80

63

63

216

170

170

170

170

200

200

160

160

80

63

63

63

63

80

80

63

63

216

170

170

170

170

200

200

160

160

2

2

2

O - 0.3 s - CO - 3 min - CO 50/60

50/60

50/60

2 50/60

5

or

7

CO - 15 s - CO

2

2

2

2

2

50/60

50/60

50/60

50/60

50/60

8

Electrohydraulic mechanism 48…250 48…250 or 208/120…500/289 50/60 Hz

9

2200 2000

2200 2400

2700 2700

3300 3200

3800 3800

2700 4000

3300 4000

3800 4800

5000 6400

6050 6070

6050 8568

7165 9360

9075 11390

13750 13750

7165 12140

9075 12140

10190 17136

13860 22780

4490 7340 4060 3000

4490 8010 4025 3400

6000 9300 4280 3900

6000 10100 4280 4300

6700 13690 5135 5100

4990 10600 6830 4350

6000 11400 6830 4750

6550 16600 7505 7200

8400 22200 9060 10000

5980

6430

9090

8600

12500

14400

14700

19200

23400

10

25 years Fig. 28b Siemens Power Engineering Guide · Transmission and Distribution · 4th Edition

* with closing resistor

2/19

Dead-Tank Circuit-Breakers for 72 kV up to 245 kV

1

Circuit-breakers in dead-tank design

2

For certain substation designs, dead-tank circuit-breakers might be required instead of the standard live-tank breakers. For these purposes Siemens can offer the dead-tank circuit breaker types.

Main features at a glance 3 Reliable opening and closing ■ Proven contact and arc-quenching

system

4

5

■ Consistent quenching performance

with rated and short-circuit currents even after many switching operations ■ Similar uncomplicated design for all voltages High-performance, reliable operating mechanisms ■ Easy-to-actuate spring operating

mechanisms ■ Hydraulic operating mechanisms with

6

on-line monitoring Economy

Fig. 29a: SPS-2 circuit-breaker 72.5 kV

■ Perfect finish ■ Simplified, quick installation process

7

■ Long maintenance intervals ■ High number of operating cycles ■ Long service life

Individual service

8

■ Close proximity to the customer ■ Order specific documentation ■ Solutions tailored to specific problems ■ After-sales service available promptly

worldwide

9

The right qualifications ■ Expertise in all power supply matters ■ 30 years of experience with SF6-insulat-

ed circuit breakers

10

■ A quality system certified to ISO 9001,

covering development, manufacture, sales, installation and after-sales service ■ Test laboratories accredited to EN 45001 and PEHLA/STL

Fig. 29b: SPS-2 circuit-breaker 170 kV

2/20


Dead-Tank Circuit-Breakers for 72 kV up to 245 kV

Subtransmission breaker Type SPS-2 and 3AP1-DT Type SPS-2 power circuit-breakers (Fig. 29a/b) are designed as general, definite-purpose breakers for use at maximum rated voltages of 72.5 and 245 kV. The construction The type SPS-2 breaker consists of three identical pole units mounted on a common support frame. The opening and closing force of the FA2/4 spring operating mechanism is transferred to the moving contacts of the interrupter through a system of connecting rods and a rotating seal at the side of each phase. The tanks and the porcelain bushings are charged with SF6 gas at a nominal pressure of 6.0 bar. The SF6 serves as both insulation and arc-quenching medium. A control cabinet mounted at one end of the breaker houses the spring operating mechanism and breaker control components. Interrupters are located in the aluminum housings of each pole unit. The interrupters use the latest Siemens puffer arcquenching system. The spring operating mechanism is the same design as used with the Siemens 3AP breakers. This design has been in service for years, and has a well documented reliability record. Customers can specify up to four (in some cases, up to six) bushing-type current transformers (CT) per phase. These CTs, mounted externally on the aluminum housings, can be removed without disturbing the bushings.

Operating mechanism

Included in the control cabinet are necessary auxiliary switches, cutoff switch, latch check switch, alarm switch and operation counter. The control relays and three control knife switches (one each for the control, heater and motor) are mounted on a control panel. Terminal blocks on the side and rear of the housing are available for control and transformer wiring. For non US markets the control cabinet is also available similar to the 3AP cabinet (3AP1-DT).

The type FA2/4 mechanically and electrically trip-free spring mechanism is used on type SPS-2 breakers. The type FA2/4 closing and opening springs hold a charge for storing ”open-close-open“ operations A weatherproof control cabinet has a large door, sealed with rubber gaskets, for easy access during inspection and maintenance. Condensation is prevented by units offering continuous inside/outside temperature differential and by ventilation.

1

2

3

4

Technical data

5

6

7 Type

SPS-2/3AP1-DT

Rated voltage

[kV]

38

48.3

72.5

121

145

169

242

Rated power-frequency withstand voltage

[kV]

80

105

160

260

310

365

425

Rated lighting impulse withstand voltage

[kV]

200

250

350

550

650

750

900/1050

Rated switching impulse withstand voltage

[kV]

–

–

–

–

–

–

–/850

4000

4000

4000

4000

4000

4000

40

40

63

63

63

63

Rated nominal current up to

9 [A] 4000

Rated breaking current up to [kA] Operating mechanism type

40

Spring-stored-energy mechanism

Fig. 30


8

2/21

10

Dead-Tank Circuit-Breakers for 550 kV

1

Circuit-breaker Type 3AT2/3-DT Composite insulators

2

3

4

5

6

7

8

The 3AT2/3-DT is available with bushings made from composite insulators – this has many practical advantages. The SIMOTEC® composite insulators manufactured by Siemens consist of a basic body made of epoxy resin reinforced glass fibre tubes. The external tube surface is coated with vulcanized silicon. As is the case with porcelain insulators, the external shape of the insulator has a multished profile. Field grading is implemented by means of a specially shaped screening electrode in the lower part of the composite insulator. The bushings and the metal tank of the circuit-breaker surround a common gas volume. The composite insulator used on the bushing of the 3AT2/3-DT is a onepiece insulating unit. Compared with conventional housings, composite insulators offer a wide range of advantages in terms of economy, efficiency and safety.

Hydraulic drive

For further information please contact:

The operating energy required for the 3AT2/3-DT interrupters is provided by the hydraulic drive, which is manufactured inhouse by Siemens. The functional principle of the hydraulic drive constitutes a technically clear solution which offers certain fundamental advantages. Hydraulic drives provide high amounts of energy economically and reliably. In this way, even the most demanding switching requirements can be mastered in short opening times. Siemens hydraulic drives are maintenancefree and have a particulary long operating life. They meet the strictest criteria for enviromental acceptability. In this respect, too, Siemens hydraulic drives have proven themselves throughout years of operation.

Fax: ++ 49 - 3 03 86 - 2 58 67

Technical data

Interrupter unit The 3AT2/3-DT pole consists of two breaking units in series impressive in the sheer simplicity of their design. The proven Siemens contact system with double graphite nozzles assures faultless operation, consistently high arc-quenching capacity and a long operating life, even at high switching frequencies. Thanks to constant further development, optimization and consistent quality assurance, Siemens arc-quencing systems meet all the requirements placed on modern high-voltage technology.

9

10

Type

3AT 2/3-DT

Rated voltage

[kV]

550


[kV]

860

Rated lighting impulse withstand voltage

[kV]

1800


[kV]

1300

Rated nominal current up to

[A]

4000

Rated breaking current up to

[kA]

50/63

Operating mechanism type

Electrohydraulic mechanism

Fig. 31

2/22


Dead-Tank Circuit-Breakers for 550 kV

1

2

3

4

5

6

7

8

9 Fig. 32: The 3AT2/3-DT circuit-breaker with SIMOTEC composite insulator bushings

10


2/23

Surge Arresters

Nonlinear resistors

Introduction 1

2

3

4

5

The main task of an arrester is to protect equipment from the effects of overvoltages. During normal operation, it should have no negative effect on the power system. Moreover, the arrester must be able to withstand typical surges without incurring any damage. Nonlinear resistors with the following properties fulfill these requirements: ■ Low resistance during surges so that overvoltages are limited ■ High resistance during normal operation, so as to avoid negative effects on the power system and ■ Sufficient energy absorption capability for stable operation With this kind of nonlinear resistor, there is only a small flow of current when continuous operating voltage is being applied. When there are surges, however, excess energy can be quickly removed from the power system by a high discharge current.

6

7

8

Nonlinear resistors, comprising metal oxide (MO), have proved especially suitable for this. The nonlinearity of MO resistors is considerably high. For this reason, MO arresters, as the arresters with MO resistors are known today, do not need series gaps. Siemens has many years of experience with arresters – with the previous gapped SiC-arresters and the new gapless MO arresters – in low-voltage systems, distribution systems and transmission systems. They are usually used for protecting transformers, generators, motors, capacitors, traction vehicles, cables and substations. There are special applications such as the protection of ■ Equipment in areas subject to earthquakes or heavy pollution ■ Surge-sensitive motors and dry-type transformers ■ Generators in power stations with arresters which posses a high degree of short-circuit current strength ■ Gas-insulated high-voltage metalenclosed switchgear (GIS) ■ Thyristors in HVDC transmission installations ■ Static compensators ■ Airport lighting systems ■ Electric smelting furnaces in the glass and metals industries ■ High-voltage cable sheaths ■ Test laboratory apparatus.

MO arresters are used in medium, high and extra-high-voltage power systems. Here, the very low protection level and the high energy absorption capability provided during switching surges are especially important. For high voltage levels, the simple construction of MO arresters is always an advantage. Another very important advantage of MO arresters is their high degree of reliability when used in areas with a problematic climate, for example in coastal and desert areas, or regions affected by heavy industrial air pollution. Furthermore, some special applications have become possible only with the introduction of MO arresters. One instance is the protection of capacitor banks in series reactive-power compensation equipment which requires extremly high energy absorption capabilities. Arresters with polymer housings Fig. 34 shows two Siemens MO arresters with different types of housing. In addition to what has been usual up to now – the porcelain housing – Siemens offers also the latest generation of high-voltage surge arresters with polymer housing.

Rated voltage ÛR

Arrester voltage referred to continuous operating voltage Û/ÛC

Continuous operating voltage ÛC

2

9

10

1 20 °C

Fig. 34: Measurement of residual voltage on porcelain-housed (foreground) and polymer-housed (background) arresters

115 °C 150 °C

0

10-4

10-3

10-2

10-1

1

10

102

103

104

Current through arrester Ia [A] Fig. 33: Current/voltage characteristics of a non-linear MO arrester

2/24


Surge Arresters

Fig. 35 shows the sectional view of such an arrester. The housing consists of a fiberglass-reinforced plastic tube with insulating sheds made of silicon rubber. The advantages of this design which has the same pressure relief device as an arrester with porcelain housing are absolutely safe and reliable pressure relief characteristics, high mechanical strength even after pressure relief and excellent pollution-resistant properties. The very good mechanical features mean that Siemens arresters with polymer housing (type 3EQ/R) can serve as post insulators as well. The pollution-resistant properties are the result of the water-repellent effect (hydrophobicity) of the silicon rubber, which even transfers its effects to pollution.

The polymer-housed high-voltage arrester design chosen by Siemens and the highquality materials used by Siemens provide a whole series of advantages including long life and suitability for outdoor use, high mechanical stability and ease of disposal. Another important design shown in Fig. 36 are the gas-insulated metal-enclosed surge arresters (GIS arresters) which have been made by Siemens for more then 25 years. There are two reasons why, when GIS arresters are used with gas-insulated switchgear, they usually offer a higher protective safety margin than when outdoor-type arresters are used (see also IEC 60099-5, 1996-02, Section 4.3.2.2.): Firstly, they can be installed closer to the item to be protected so that traveling wave effects can

be limited more effectively. Secondly, compared with the outdoor type, inductance of the installation is lower (both that of the connecting conductors and that of the arrester itself). This means that the protection offered by GIS arresters is much better than by any other method, especially in the case of surges with a very steep rate of rise or high frequency, to which gas-insulated switchgear is exceptionally sensitive. Please find an overview of the complete range of Siemens arresters in Figs. 37 and 38, pages 26 and 27.

1

2

3

For further information please contact: Fax: ++ 49 - 3 03 86 -2 67 21 e-mail: [email protected]

4

SF6-SF6 bushing (SF6 -Oil bushing on request)

5

Flange with gas diverter nozzle Seal

Access cover with pressure relief device and filter

6

Pressure relief diaphragm Compressing spring

Spring contact

Metal oxide resistors

Grading hood

Composite polymer housing FRP tube/silicon sheds

Metal-oxide resistors

7

8

Supporting rods Enclosure

9

10 Fig. 36: Gas-insulated metal-enclosed arrester (GIS arrester)

Fig. 35: Cross-section of a polymer-housed arrester


2/25

Low-Voltage and Medium-Voltage Arresters and Limiters (230/400 V to 52 kV)

Type

Low-voltage arresters and limiters

1

3EA2

3EF1 3EF2 3EF3 3EF4 3EF5

3EC3

3EE2

3EH2

3EG5

3EK5

3EK7

3EQ1-B

Applications

Lowvoltage overhead line systems

Motors, dry-type transformers, airfield lighting systems, sheath voltage limiters, protection of converters for drives

DC systems (locomotives, overhead contact lines)

Generators, motors, melting furnaces, 6-arrester connections, power plants

Distribution systems metalenclosed gas-insulated switchgear with plug-in connection

Distribution systems and mediumvoltage switchgear



AC and DC locomotives, overhead contact lines

Nom. syst. [kV] voltage (max.)

1

10

3

30

45

30

60

30

25

12

4

36

52

36

72.5

36

30

2

3

4

5

Highest [kV] voltage for equipment (max.)

6

Medium-voltage arresters

Maximum rated voltage

[kV]

1

15

4

45

52

45

75

45

37 (AC) 4 (DC)

Nominal discharge current

[kA]

5

1

10

10

10

10

10

10

10

Maximum [kJ/kV] energy absorbing capability (at thermal stability)

–

3EF1/2 3EF3 3EF4 3EF5

0.8 9 12.5 8

10

10

1.3

3

5

3

10

[A]

1 x 380 20 x 250

3EF4 3EF5

1500 1200

1200

1200

200

300

500

300

1200

9

Maximum long duration current impulse, 2 ms

[kA]

Line disconnection

40

40

300

16

20

20

20

40

10

Maximum shortcircuit rating

Porcelain

Porcelain

Metal

Porcelain

Porcelain

Polymer

Polymer

7

8

Housing material

Polymer

Polymer

Fig. 37: Low and medium-voltage arresters

2/26


High-Voltage Arresters (72.5 to 800 kV)

Type

Applications

Nom. syst. voltage (max.)

[kV]

3EP1

3EP4

3EP2

3EP3

3EQ1

Mediumand highvoltage systems, outdoor installations


Highvoltage systems, outdoor installations

Highvoltage systems, outdoor installations, HVDC, SC & SVC applications


Metal-oxide surge arresters 3EQ4 3EQ3 3EP2-K 3ER3 Highvoltage systems, outdoor installations

3EP3-K Highvoltage systems, metalenclosed gasinsulated switchgear

Highvoltage systems, outdoor installations, HVDC, SC & SVC applications

Highvoltage systems, metalenclosed gasinsulated switchgear

Highvoltage systems, metalenclosed gasinsulated switchgear

60

150

500

765

275

500

765

150

150

500

Highest [kV] voltage for equip. (max.)

72.5

170

550

800

300

550

800

170

170

550

Maximum rated voltage

[kV]

84

147

468

612

240

468

612

180

180

444

Nominal discharge current

[kA]

2

3

4

5 10

10

10/20

10/20

10

10/20

20

10/20

10/20

20

Maximum line discharge class

2

3

5

5

3

5

5

4

4

5

Maximum [kJ/kV] energy absorbing capability (at thermal stability)

5

8

12.5

20

8

12.5

20

10

10

12.5

Maximum long duration current impulse, 2 ms

[A]

500

Maximum shortcircuit rating

[kA]

40

2.12)

Minimum [kNm]2) breaking moment

Housing material

6

7

1500

3900

850

1500

3900

1200

1200

1500

8

65

65

100

50

65

80

–

–

–

9

4.52)

12.52)

342)

850

10 63)

Maximum [MPSL] permissible service load

1)

1

3EP2-K3

Porcelain Porcelain

Silicon rubber sheds

2) Acc.

to DIN 48113

Porcelain Porcelain 3)

213)

723)

Polymer1) Polymer1) Polymer1)

–

Metal

–

–

Metal

Metal

Acc. to IEC TC 37 WG5 03.99; > 50% of this value are maintained after pressure relief

Fig. 38: High-voltage arresters Siemens Power Engineering Guide · Transmission and Distribution · 4th Edition

2/27

Gas-Insulated Switchgear for Substations

Introduction 1

2

3

Common characteristic features of switchgear installation Because of its small size and outstanding compatibility with the environment, SF6 insulated switchgear (GIS) is gaining constantly on other types. Siemens has been a leader in this sector from the very start. The concept of SF6 - insulated metal-enclosed high-voltage switchgear has proved itself in more than 70,000 bay operating years in over 6,000 installations in all parts of the world. It offers the following outstanding advantages.

Protection of the environment The necessity to protect the environment often makes it difficult to erect outdoor switchgear of conventional design, whereas buildings containing compact SF6-insulated switchgear can almost always be designed so that they blend well with the surroundings. SF6-insulated metal-enclosed switchgear is, due to the modular system, very flexible and can meet all requirements of configuration given by network design and operating conditions.

Each circuit-breaker bay includes the full complement of disconnecting and grounding switches (regular or make-proof), instrument transformers, control and protection equipment, interlocking and monitoring facilities commonly used for this type of installation (Fig. 39). Beside the conventional circuit-breaker bay, other arrangements can be supplied such as single-bus, ring cable with load-break switches and circuit-breakers, single-bus arrangement with bypass-bus, coupler and bay for triplicate bus. Combined circuitbreaker and load-break switch feeder, ring cable with load-break switches, etc. are furthermore available for the 145 kV level.

Minimal space requirements

4

5

6

The availability and price of land play an important part in selecting the type of switchgear to be used. Siting problems arise in ■ Large towns ■ Industrial conurbations ■ Mountainous regions with narrow valleys ■ Underground power stations In cases such as these, SF6-insulated switchgear is replacing conventional switchgear because of its very small space requirements. Full protection against contact with live parts

7

The all-round metal enclosure affords maximum safety for personnel under all operating and fault conditions. Protection against pollution

8

9

10

Its metal enclosure fully protects the switchgear interior against environmental effects such as salt deposits in coastal regions, industrial vapors and precipitates, as well as sandstorms. The compact switchgear can be installed in buildings of uncomplicated design in order to minimize the cost of cleaning and inspection and to make necessary repairs independent of weather conditions. Free choice of installation site The small site area required for SF6-insulated switchgear saves expensive grading and foundation work, e.g. in permafrost zones. Other advantages are the short erection times and the fact that switchgear installed indoors can be serviced regardless of the climate or the weather.

Fig. 39: Typical circuit arrangements of SF6-switchgear

2/28



Main product range of GIS for substations SF6 switchgear up to 550 kV (the total product range covers GIS from 66 up to 800 kV rated voltage): Fig. 40. The development of the switchgear is always based on an overall production concept, which assures the achievement of the high technical standards required of the HV switchgear whilst providing the maximum customer benefit.

This objective is attained only by incorporating all processes in the quality management system, which has been introduced and certified according to DIN EN ISO 9001 (EN 29001). Siemens GIS switchgear meets all the performance, quality and reliability demands such as: Compact space-saving design means uncomplicated foundations, a wide range of options in the utilization of space, less space taken up by the switchgear.

Minimal-weight construction through the use of aluminum alloy and the exploitation of innovations in development such as computer-aided design tools.

1

Safe encapsulation means an outstanding level of safety based on new manufacturing methods and optimized shape of enclosures.

2

Environmental compatibility means no restrictions on choice of location through minimal space requirement, extremely low noise emission and effective gas sealing system (leakage < 1% per year per gas compartment).

3

Economical transport

3500

4740

means simplified and fast transport and reduced costs because of maximum possible size of shipping units. 4480

2850

3470

5170

500

Switchgear type

8DN8

8DN9

8DQ1

Details on page

2/30

2/31

2/32

4

Minimal operating costs means the switchgear is practically maintenance-free, e.g. contacts of circuit-breakers and disconnectors designed for extremely long endurance, motor-operated mechanisms self-lubricating for life, corrosion-free enclosure. This ensures that the first inspection will not be necessary until after 25 years of operation.

5

6

Reliability

Rated voltage

[kV]

up to 145

up to 245

up to 550

Rated powerfrequency withstand voltage

[kV]

up to 275

up to 460

up to 740

Rated lightning impulse withstand voltage

[kV]

up to 650

up to 1050

up to 1800


[kV]

–

up to 850

up to 1250

Rated (normal) current [A] busbar

up to 3150

up to 3150

up to 6300

Rated (normal) current [A] feeder

up to 2500

up to 3150

up to 4000

Rated breaking current

[kA]

up to 40

up to 50

up to 63

Rated short-time withstand current

[kA]

up to 40

up to 50

up to 63

Rated peak withstand current

[kA]

up to 108

up to 135

up to 170

> 25

> 25

> 25

800

1200/1500

3600

means our overall product concept which includes, but is not limited to, the use of finite elements method (FEM), threedimensional design programs, stereolithography, and electrical field development programs assuring the high standard of quality. Smooth and efficient installation and commissioning

7

8

transport units are fully assembled and tested at the factory and filled with SF6 gas at reduced pressure. Plug connection of all switches, all of which are motorized, further improves the speediness of site installation and substantially reduces field wiring errors.

9

Routine tests

Inspection

[Years]

Bay width

[mm]

All dimensions in mm

All measurements are automatically documented and stored in the EDP information system, which enables quick access to measured data even if years have passed. For further information please contact: Fax: ++ 49- 9131-7-34498 e-mail: [email protected]

Fig. 40: Main product range


2/29

10


1

2

3

4

5

6

7

8

9

10

SF6-insulated switchgear up to 145 kV, type 8DN8 Three-phase enclosures are used for type 8DN8 switchgear in order to achieve extremely low component dimensions. The low bay weight ensures minimal floorloading and eliminates the need for complex foundations. Its compact dimensions and low weight enable it to be installed almost anywhere. This means that capital costs can be reduced by using smaller buildings, or by making use of existing ones, for instance when medium voltage switchgear is replaced by 145 kV GIS. The bay ist based on a circuit-breaker mounted on a supporting frame (Fig. 41). A special multifunctional cross-coupling module combines the functions of the disconnector and earthing switch in a threeposition switching device. It can be used as ■ an active busbar with integrated disconnector and work-in-progress earthing switch (Fig. 41/Pos. 3 and 4), ■ outgoing feeder module with integrated disconnector and work-in-progress earthing switch (Fig. 41/Pos. 5), ■ busbar sectionalizer with busbar earthing. For cable termination, a cable termination module can be equipped with either conventional sealing ends or the latest plug-in connectors (Fig. 41/Pos. 9). Flexible singlepole modules are used to connect overhead lines and transformers by using a splitting module which links the 3-phase encapsulated switchgear to the single pole connections. Thanks to the compact design, up to three completely assembled and works-tested bays can be shipped as one transport unit. Fast erection and commissioning on site ensure the highest possible quality. The feeder control and protection can be located in a bay-integrated local control cubicle, mounted in the front of each bay (Fig. 42). It goes without saying that we supply our gas-insulated switchgear with all types of currently available bay control systems – ranging from contactor circuit controls to digital processor bus-capable bay control systems, for example the modern SICAM HV system based on serial bus communication. This system offers ■ Online diagnosis and trend analysis enabling early warning, fault recognition and condition monitoring. ■ Individual parameterization, ensuring the best possible incorporation of customized control facilities. ■ Use of modern current and voltage sensors. This results in a longer service life and lower operating costs, in turn attaining a considerable reduction in life cycle costs.

2/30

7

1

2

8

6

Gas-tight bushing Gas-permeable bushing

10

5 4

9 3

5 Outgoing feeder module

1 Interrupter unit of the circuit-breaker 2 Spring-stored energy mechanism with circuit-breaker control unit 3 Busbar I with disconnector and earthing system 4 Busbar II with disconnector and earthing system

6 7 8 9 10

with disconnector and earthing switch Make-proof earthing switch (high-speed) Current transformer Voltage transformer Cable sealing end Integrated local control cubicle

3

4 1 7 5 8 6 9

Fig. 41: Switchgear bay 8DN8 up to 145 kV

Fig. 42: 8DN8 switchgear for rated voltage 145 kV

Fig. 43



SF6-insulated switchgear up to 245 kV, type 8DN9 The clear bay configuration of the lightweight and compact 8DN9 switchgear is evident at first sight. Control and monitoring facilities are easily accessible in spite of the compact design of the switchgear. The horizontally arranged circuit-breaker forms the basis of every bay configuration. The operating mechanism is easily accessible from the operator area. The other bay modules – of single-phase encapsulated design like the circuit-breaker module – are located on top of the circuit-breaker. The three-phase encapsulated passive busbar is partitioned off from the active equipment. Thanks to “single-function” assemblies (assignment of just one task to each module) and the versatile modular structure, even unconventional arrangements can be set up out of a pool of only 20 different modules. The modules are connected to each other by a standard interface which allows an extensive range of bay structures. The switchgear design with standardized modules and the scope of services mean that all kinds of bay structures can be set up in a minimal area. The compact design permits the supply of double bays fully assembled, tested in the factory and filled with SF6 gas at reduced pressure, which assures smooth and efficient installation and commissioning. The following major feeder control level functions are performed in the local control cubicle for each bay, which is integrated in the operating front of the 8DN9 switchgear: ■ Fully interlocked local operation and state-indication of all switching devices managed reliably by the Siemens digital switchgear interlock system ■ Practical dialog between the digital feeder protection system and central processor of the feeder control system ■ Visual display of all signals required for operation and monitoring, together with measured values for current, voltage and power ■ Protection of all auxiliary current and voltage transformer circuits ■ Transmission of all feeder information to the substation control and protection system Factory assembly and tests are significant parts of the overall production concept mentioned above. Two bays at a time undergo mechanical and electrical testing with the aid of computer-controlled stands.

14

4

6

3

7

Gas-tight bushing Gas-permeable bushing

10

9

12

1

5

2

3

4

5

2 1 Circuit-breaker interrupter unit 2 Spring-stored energy 3 4 5 6 7

mechanism with circuit-breaker control unit Busbar disconnector I Busbar I Busbar disconnector II Busbar II Earthing switch (work-in-progress)

1

11 8

13

6

8 Earthing switch (work-in-progress)

9 Outgoing-disconnector 10 Make-proof earthing switch 11 12 13 14

(high-speed) Current transformer Voltage transformer Cable sealing end Integrated local control cubicle

3

5

7

7 1 11 8 9

12 10

8

13

Fig. 44: Switchgear bay 8DN9 up to 245 kV


9

10

Fig. 45: 8DN9 switchgear for rated voltage 245 kV

2/31


1

2

3

4

5

6

7

SF6-insulated switchgear up to 550 kV, type 8DQ1 The GIS type 8DQ1 is a modular switchgear system for high power switching stations with individual enclosure of all modules for the three-phase system. The base unit for the switchgear forms a horizontally arranged circuit-breaker on top of which are mounted the housings containing disconnectors, grounding switches, current transformers, etc. The busbar modules are also single-phase encapsulated and partitioned off from the active equipment. As a matter of course the busbar modules of this switchgear system are passive elements, too. Additional main characteristic features of the switchgear installation are: ■ Circuit-breakers with two interrupter units up to operating voltages of 550 kV and breaking currents of 63 kA (from 63 kA to 100 kA, circuit-breakers with four interrupter units have to be considered) ■ Low switchgear center of gravity by means of circuit-breaker arranged horizontally in the lower portion ■ Utilization of the circuit-breaker transport frame as supporting device for the entire bay ■ The use of only a few modules and combinations of equipment in one enclosure reduces the length of sealing faces and consequently lowers the risk of leakage

11 10

12

9 8

7

1

6

4 5 3 2

13 1 2 3 4 5 6 7 8

Circuit-breaker Busbar disconnector I Busbar I Busbar disconnector II Busbar II Grounding switch Voltage transformer Make-proof grounding switch 9 Cable disconnector

14 10 11 12 13 14 15 16 17 18

15

16 17 18

Grounding switch Current transformer Cable sealing end Local control cubicle Gas monitoring unit (as part of control unit) Circuit-breaker control unit Electrohydraulic operating unit Oil tank Hydraulic storage cylinder

3 5 2

4 6 1 11 10

9

7 8 12

Fig. 46: Switchgear bay 8DQ1 up to 550 kV

8

9

10

Fig. 47: 8DQ1 switchgear for rated voltage 420 kV

2/32



Some examples for special arrangement Gas-insulated switchgear – usually accommodated in buildings (as shown in a towertype substation) – is expedient whenever the floor area is very expensive or restricted or whenever ambient conditions necessitate their use (Fig. 50, page 2/34). For smaller switching stations, or in cases of expansion when there is no advantage in constructing a building, a favorable solution is to install the substation in a container (Fig. 49).

1 Cable termination 2 Make-proof earthing 3 4 5 6

switch Outgoing disconnector Earthing switch Circuit breaker Earthing switch

7 Current transformer 8 Outgoing disconnector 9 Make-proof earthing switch 10 Voltage transformer 11 Outdoor termination

Fig. 49: 8DN9 switchgear bay in a container

Mobile containerized switching stations can be of single or multi-bay design using a large number of different circuits and arrangements. All the usual connection components can be employed, such as outdoor bushings, cable adapter boxes and SF6 tubular connections. If necessary, all the equipment for control and protection and for the local supply can be accommodated in the container. This allows exten-

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6 7 8

Mobile containerized switchgear – even for high voltage At medium-voltage levels, mobile containerized switchgear is the state of the art. But even high-voltage switching stations can be built in this way and economically operated in many applications. The heart is the metal-enclosed SF6-insulated switchgear, installed either in a sheet-steel container or in a block house made of prefabricated concrete elements. In contrast to conventional stationary switchgear, there is no need for complicated constructions; mobile switching stations have their own ”building“.

1 1

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10 11

5 Fig. 48: Containerized 8DN9 switchgear with stub feed in this example

sively independent operation of the installation on site. Containerized switchgear is preassembled in the factory and ready for operation. On site, it is merely necessary to set up the containers, fit the exterior system parts and make the external connections. Shifting the switchgear assembly work to the factory enhances the quality and operational reliability. Mobile containerized switchgear requires little space and usually fits in well with the environment. Rapid availability and short commissioning times are additional, significant advantages for the operators. Considerable cost reductions are achieved in the planning, construction work and assembly. Building authority approvals are either not required or only in a simple form. The installation can be operated at various locations in succession, and adaptation to local circumstances is not a problem. These are the possible applications for containerized stations: ■ Intermediate solutions for the modernization of switching stations ■ Low-cost transitional solutions when tedious formalities are involved in the new construction of transformer substations, such as in the procurement of land or establishing cable routes ■ Quick erection as an emergency station in the event of malfunctions in existing switchgear ■ Switching stations for movable, geothermal power plants


GIS up to 245 kV in a standard container The dimensions of the 8DN9 switchgear made it possible to accommodate all active components of the switchgear (circuitbreaker, disconnector, grounding switch) and the local control cabinet in a standard container. The floor area of 20 ft x 8 ft complies with the ISO 668 standard. Although the container is higher than the standard dimension of 8 ft, this will not cause any problems during transportation as proven by previously supplied equipment. German Lloyd, an approval authority, has already issued a test certificate for an even higher container construction. The standard dimensions and ISO corner fittings will facilitate handling during transport in the 20 ft frame of a container ship and on a low-loader truck. Operating staff can enter the container through two access doors. Rent a GIS Containerized gas-insulated high voltage substations for hire are now available. In this way, we can step into every breach, instantly and in a remarkably cost-effective manner. Whether for a few weeks, months or even 2 to 3 years, a fair rent makes our Instant Power Service unbeatably economical.

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All dimensions in m

Specification guide for metal-enclosed SF6-insulated switchgear

Air conditioning system

1

26.90

2

The points below are not considered to be comprehensive, but are a selection of the important ones.

Relay room

General 23.20

3

4 Gas-insulated switchgear type 8DN9

Grounding resistor

5 15.95 13.8 kV switchgear

6

Applicable standards

Shunt reactor 11.50

7 Cable duct

8.90

8

Radiators 40 MVA transformer

10 2.20

–1.50 Fig. 50: Special arrangement for limited space. Sectional view of a building showing the compact nature of gas-insulated substations

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All equipment shall be designed, built, tested and installed to the latest revisions of the applicable IEC 60 standards (IEC Publ. 60517 “High-voltage metal-enclosed switchgear for rated voltages of 72.5 kV and above”, IEC Publ. 60129 “Alternating current disconnectors (isolators) and grounding switches”, IEC Publ. 60056 “High-voltage alternating-current circuitbreakers”), and IEC Publ. 60044 for instrument transformers. Local conditions

Compensator

9

These specifications cover the technical data applicable to metal-enclosed SF6 gasinsulated switchgear for switching and distribution of power in cable and/or overhead line systems and at transformers. Key technical data are contained in the data sheet and the single-line diagram attached to the inquiry. A general “Single-line diagram” and a sketch showing the general arrangement of the substation and the transmission line exist and shall form part of a proposal. The switchgear quoted shall be complete to form a functional, safe and reliable system after installation, even if certain parts required to this end are not specifically called for.

The equipment described herein will be installed indoors. Suitable lightweight, prefabricated buildings shall be quoted if available from the supplier. Only a flat concrete floor will be provided by the buyer with possible cutouts in case of cable installation. The switchgear shall be equipped with adjustable supports (feet). If steel support structures are required for the switchgear, these shall be provided by the supplier. For design purposes indoor temperatures of – 5 °C to +40 °C and outdoor temperatures of – 25 °C to +40 °C shall be considered. For parts to be installed outdoors (overhead line connections) the applicable conditions in IEC Publication 60517 shall also be observed.



Work, material and design Aluminium or aluminium alloys shall be used preferabely for the enclosures. Maximum reliability through minimum amount of erection work on site is required. Subassemblies must be erected and tested in the factory to the maximum extent. The size of the subassemblies shall be limited only by the transport conditions. The material and thickness of the enclosure shall be selected to withstand an internal arc and to prevent a burn-through or puncturing of the housing within the first stage of protection, referred to a shortcircuit current of 40 kA. Normally exterior surfaces of the switchgear shall not require painting. If done for aesthetic reasons, surfaces shall be appropriately prepared before painting, i.e. all enclosures are free of grease and blasted. Thereafter the housings shall be painted with no particular thickness required but to visually cover the surface for decorative reasons only. The interior color shall be light (white or light grey). All joints shall be machined and all castings spotfaced for bolt heads, nuts and washers. Assemblies shall have reliable provisions to absorb thermal expansion and contractions created by temperature cycling. For this purpose metal bellows-type compensators shall be installed. They must be provided with adjustable tensioners. All solid post insulators shall be provided with ribs (skirts). For supervision of the gas within the enclosures, density monitors with electrical contacts for at least two pressure levels shall be installed. The circuit-breakers, however, might be monitored by density gauges fitted in circuit-breaker control units. The manufacturer assures that the pressure loss within each individual gas compartment – and not referred to the total switchgear installation only – will be not more than 1% per year per gas compartment.

Each gas-filled compartment shall be equipped with static filters of a capacity to absorb any water vapor penetrating into the switchgear installation over a period of at least 25 years. Long intervals between the necessary inspections shall keep the maintenance cost to a minimum. A minor inspection shall only become necessary after ten years and a major inspection preferably after a period exceeding 25 years of operation, unless the permissible number of operations is met at an earlier date. Arrangement and modules Arrangement The arrangement shall be single-phase or three-phase enclosed. The assembly shall consist of completely separate pressurized sections designed to minimize the risk of damage to personnel or adjacent sections in the event of a failure occurring within the equipment. Rupture diaphragms shall be provided to prevent the enclosures from uncontrolled bursting and suitable deflectors provide protection for the operating personnel. In order to achieve maximum operating reliability, no internal relief devices may be installed because adjacent compartments would be affected. Modular design, complete segregation, arc-proof bushings and “plug-in” connection pieces shall allow ready removal of any section and replacement with minimum disturbance of the remaining pressurized switchgear. Busbars All busbars shall be three-phase or singlephase enclosed and be plug-connected from bay to bay. Circuit-breakers The circuit-breaker shall be of the single pressure (puffer) type with one interrupter per phase*. Heaters for the SF6 gas are not permitted. The arc chambers and contacts of the circuit-breaker shall be freely accessible. The circuit-breaker shall be designed to minimize switching overvoltages and also to be suitable for out-of-phase switching. The specified arc interruption performance must be consistent over the entire operating range, from line-charging currents to full short-circuit currents.

The circuit breaker shall be designed to withstand at least 18–20 operations (depending on the voltage level) at full short-circuit rating without the necessity to open the circuit-breaker for service or maintenance. The maximum tolerance for phase disagreement shall be 3 ms, i.e. until the last pole has been closed or opened respectively after the first. A standard station battery required for control and tripping may also be used for recharging the operating mechanism. The energy storage system (hydraulic or spring operating system) will hold sufficient energy for all standard IEC closeopen duty cycles. The control system shall provide alarm signals and internal interlocks, but inhibit tripping or closing of the circuit-breaker when there is insufficient energy capacity in the energy storage system, or the SF6 density within the circuit-breaker has dropped below a minimum permissible level. Disconnectors All isolating switches shall be of the singlebreak type. DC motor operation (110, 125, 220 or 250 V), completely suitable for remote operation, and a manual emergency drive mechanism is required. Each motor-drive shall be self-contained and equipped with auxiliary switches in addition to the mechanical indicators. Life lubrication of the bearings is required. Grounding switches Work-in-progress grounding switches shall generally be provided on either side of the circuit-breaker. Additional grounding switches may be used for the grounding of bus sections or other groups of the assembly. DC motor operation (110, 125, 220 or 250 V), completely suitable for remote operation, and a manual emergency drive mechanism is required. Each motor drive shall be self-contained and equipped with auxiliary position switches in addition to the mechanical indicators. Life lubrication of the bearings is required.

* two interrupters for voltages exceeding 245 kV Siemens Power Engineering Guide · Transmission and Distribution · 4th Edition

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Make-proof high-speed grounding switches shall generally be installed at cable and overhead-line terminals. DC motor operation (110, 125, 220 or 250 V), completely suitable for remote operation, and a manual emergency drive mechanism is required. Each motor drive shall be self-contained and equipped with auxiliary position switches in addition to the mechanical indicators. Life lubrication of the bearings is required. These switches shall be equipped with a rapid closing mechanism to provide faultmaking capability. Instrument transformers Current transformers (CTs) shall be of the dry-type design not using epoxy resin as insulation material. Cores shall be provided with the accuracies and burdens as shown on the SLD. Voltage transformers shall be of the inductive type, with ratings up to 200 VA. They shall be foil-gas-insulated. Cable terminations Single or three-phase, SF6 gas-insulated, metal-enclosed cable-end housings shall be provided. The stress cone and suitable sealings to prevent oil or gas from leaking into the SF6 switchgear are part of the cable manufacturer’s supply. A mating connection piece, which has to be fitted to the cable end, shall be made available by the switchgear supplier. The cable end housing shall be suitable for oil-type, gas-pressure-type and plasticinsulated (PE, PVC, etc.) cables as specified on the SLD, or the data sheets. Facilities to safely isolate a feeder cable and to connect a high-voltage test cable to the switchgear or the cable shall be provided.

Fig. 52: Cable termination module – Cable termination modules conforming to IEC are available for connecting the switchgear to high-voltage cables. The standardized construction of these modules allows connection of various cross-sections and insulation types. Parallel cable connections for higher rated currents are also possible using the same module.

Fig. 54: Transformer/reactor termination module – These termination modules form the direct connection between the GIS and oil-insulated transformers or reactance coils. They can be matched economically to various transformer dimensions by way of standardized modules.

Overhead line terminations Terminations for the connection of overhead lines shall be supplied complete with SF6-to-air bushings, but without line clamps.

9

Fig. 55: Transformer termination modules

Control

10

Fig. 51: Three phase cable termination module. Example for plug-in type cables.

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Fig. 53: Outdoor termination module – High-voltage bushings are used for transition from SF6-to-air as insulating medium. The bushings can be matched to the particular requirements with regard to arcing and creepage distances. The connection with the switchgear is made by means of variabledesign angular-type modules.

An electromechanical or solid-state interlocking control board shall be supplied as a standard for each switchgear bay. This failsafe interlock system will positively prevent maloperations. Mimic diagrams and position indicators shall give clear demonstration of the operation to the operating personnel. Provisions for remote control shall be supplied.



Tests required

Power frequency tests

Partial discharge tests

Each assembly shall be subjected to power-frequency withstand tests to verify the correct installation of the conductors and also the fact that the insulator surfaces are clean and the switchgear as a whole is not polluted inside.

All solid insulators fitted into the switchgear shall be subjected to a routine partial discharge test prior to being installed. No measurable partial discharge is allowed at 1.1 line-to-line voltage (approx. twice the phase-to-ground voltage). This test ensures maximum safety against insulator failure, good long-term performance and thus a very high degree of reliability. Pressure tests Each cast aluminium enclosure of the switchgear shall be pressure-tested to at least double the service pressure.

Additional technical data The supplier shall point out all dimensions, weights and other applicable data of the switchgear that may affect the local conditions and handling of the equipment. Drawings showing the assembly of the switchgear shall be part of the quotation.

Leakage tests

Instructions

Leakage tests performed on the subassemblies shall ensure that the flanges and cover faces are clean, and that the guaranteed leakage rate will not be exceeded.

Detailed instruction manuals about installation, operation and maintenance of the equipment shall be supplied by the contractor in case of an order.

Fig. 56: The modular system of the 8DQ1 switchgear enables all conceivable customer requirements to be met with just a small number of components


Scope of supply For all types of GIS Siemens supplies the following items and observes these interface points: ■ Switchgear bay with circuit-breaker interrupters, disconnectors and grounding switches, instrument transformers, and busbar housings as specified. For the different feeder types, the following limits apply: – Overhead line feeder: the connecting stud at the SF6-to-air bushing without the line clamp. – Cable feeder: according to IEC 60859 the termination housing, conductor coupling, and connecting plate are part of the GIS delivery, while the cable stress cone with matching flange is part of the cable supply (see Fig. 52 on page 2/36). – Transformer feeder: connecting flange at switchgear bay and connecting bus ducts to transformer including any expansion joint are delivered by Siemens. The SF6to-oil bushings plus terminal enclosures are part of the transformer delivery, unless agreed otherwise (see Fig. 54 on page 2/36)*. ■ Each feeder bay is equipped with grounding pads. The local grounding network and the connections to the switchgear are in the delivery scope of the installation contractor. ■ Initial SF6-gas filling for the entire switchgear as supplied by Siemens is included. All gas interconnections from the switchgear bay to the integral gas service and monitoring panel are supplied by Siemens as well. ■ Hydraulic oil for all circuit-breaker operating mechanisms is supplied with the equipment. ■ Terminals and circuit protection for auxiliary drive and control power are provided with the equipment. Feeder circuits and cables, and installation material for them are part of the installation contractor’s supply. ■ Local control, monitoring, and interlocking panels are supplied for each circuitbreaker bay to form completely operational systems. Terminals for remote monitoring and control are provided. ■ Mechanical support structures above ground are supplied by Siemens; embedded steel and foundation work is part of the installation contractor’s scope. * Note: this interface point should always be closely coordinated between switchgear manufacturer and transformer supplier.

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Gas-Insulated Transmission Lines (GIL)

Introduction 1

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10

For high-power transmission systems where overhead lines are not suitable, alternatives are gas-insulated transmission lines (GIL). The GIL exhibits the following differences in comparison with cables: ■ High power ratings (transmission capacity up to 3000 MVA per System) ■ High overload capability ■ Suitable for long distances (100 km and more without compensation of reactive power) ■ High short-circuit withstand capability (including internal arc faults) ■ Possibility of direct connection to gasinsulated switchgear (GIS) and gas-insulated arresters without cable entrance fitting ■ Multiple earthing points possible ■ Non-flammable, no fire risk in case of failures The innovations in the latest Siemens GIL development are the considerable reduction of costs and the introduction of buried laying technique for GIL for long-distance power transmission. SF6 has been replaced by a gas mixture of SF6 and N2 as insulating medium.

The gas-insulated transmission line technique is a highly reliable system in terms of mechanical and electrical failures. Once a system is commissioned and in service, it runs reliably without any dielectrical or mechanical failures as experience over the course of 20 years shows. For example, one particular Siemens GIL will not undergo its scheduled inspection after 20 years of service, as there has been no indication of any weak point. Fig. 57 shows the arrangement of six phases in a tunnel. Basic design In order to meet mechanical stability criteria, gas-insulated lines need minimum cross-sections of enclosure and conductor. With these minimum cross-sections, high power transmission ratings are given. Due to the gas as insulating medium, low capacitive loads are given so that compensation of reactive power is not needed, even for long distances of 100 km and more.

Fig. 57: GIL arrangement in the tunnel of the Wehr pumped storage station (4000 m length, in service since 1975)

Siemens experience Back in the 1960s with the introduction of sulphur hexafluoride (SF6) as an insulating and switching gas, the basis was found for the development of gas-insulated switchgear (GIS). On the basis of GIS experience, Siemens developed SF6 gas-insulated lines to transmit electrical energy too. In the early 1970s initial projects were planned and implemented. Such gas-insulated lines were usually used within substations as busbars or bus ducts to connect gas-insulated switchgear with overhead lines, the aim being to reduce clearances in comparison to air-insulated overhead lines. Implemented projects include GIL laying in tunnels, in sloping galleries, in vertical shafts and in open air installation. Flanging as well as welding has been applied as jointing technique.

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Fig. 58: Long-term test set-up at the IPH, Berlin

Reduction of SF6 content Several tests have been carried out in Siemens facilities as well as in other test laboratories world-wide since many years. Results of these investigations show that the bulk of the insulating gas for industrial projects involving a considerable amount of gas should be nitrogen, a nontoxic natural gas. However, another insulating gas should be added to nitrogen in order to improve the insulating capability and to minimize size and pressure. A N2/SF6 gas mixture with high nitrogen content (and sulphur hexafluoride portion as low as possible) was finally chosen as insulating medium.

The characteristics of N2/SF6 gas mixtures show that with an SF6 content of only 15–25% and a slightly higher pressure, the insulating capability of pure SF6 can be attained. Besides, the arcing behavior is improved through this mixture. Tests have proven that there would be no external damage or fire caused by an internal failure. The technical data of the GIL are shown in Fig. 59.


Gas-Insulated Transmission Lines (GIL)

Technical data

1 Rated voltage

up to 550 kV

Rated current lr

2000 – 4600 A

Transmission capacity

1500 – 3000 MVA

Capacitance

≈ 60 nF/km

Typical length

1–100 km

Gas mixture SF6/N2 ranging from

10%/90% up to 35%/65%

Laying

D

2

directly buried

Fig. 60: GIL laying technique

in tunnels/ sloping galleries/ vertical shafts

clean assembly and productivity is enhanced by a high level of automation of the overall process.

open air installation

Anti-corrosion protection

Fig. 59: GIL technical data

Jointing technique In order to improve the gas-tightness and to facilitate laying, flanges have been avoided as jointing technique. Instead, welding has been chosen to join the various GIL construction units. The welding process is highly automated, with the use of an orbital welding machine to ensure high quality of the joints. This orbital welding machine contributes to high productivity in the welding process and therefore speeds up laying. The reliability of the welding process is controlled by an integrated computerized quality assurance system. Laying The most recently developed Siemens GILs are scheduled for directly buried laying. The laying technique must be as compatible as possible with the landscape and must take account of the sequence of seasons. The laying techniques for pipelines have been improved over many years and they are applicable for GIL as a ”pipeline for electrical current“too. However, the GIL needs slightly different treatment where the pipeline technique has to be adapted.The laying process is illustrated in Fig. 60. The assembly area needs to be protected against dust, particles, humidity and other environmental factors that might disturb the dielectric system. Clean assembly therefore plays an important role in setting up cross-country GILs under normal environmental conditions. The combination of

Directly buried gas-insulated transmission lines will be safeguarded by a passive and active corrosion protection system. The passive corrosion protection system comprises a PE or PP coating and assures at least 40 years of protection. The active corrosion protection system provides protection potential in relation to the aluminum sheath. An important requirement taken into account is the situation of an earth fault with a high current of up to 63 kA to earth. Testing The GIL is already tested according to the report IEC 61640 (1998) “Rigid highvoltage, gas-insulated transmission lines for voltages of 72.5 kV and above.” Long-term performances Besides nearly 25 years of field experience with GIL installations world wide, the longterm performance of the GIL for long-distance installations has been proven by the independent test laboratory IPH, Berlin, Germany and the Berlin power utility BEWAG according to long-term test proce-

dures for power cables. The test procedure consisted of load cycles with doubled voltage and increased current as well as frequently repeated high-voltage tests. The assembly and repair procedures under realistic site conditions were examined too. The Siemens GIL is the first one in the world that has passed these tests, without any objection. Fig. 58 shows the test setup arranged in a tunnel of 3 m diameter, corresponding to the tunnel used in Berlin for installing a 420 kV transmission link through the city.

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References Siemens has gathered experience with gas-insulated transmission lines at rated voltages of up to 550 kV and with system lengths totalling more than 30 km. The first GIL stretch built by Siemens was the connection of the turbine generator/ pumping motor of a pumped storage station with the switchyard. The 420 kV GIL is laid in a tunnel through a mountain and has a length of 4000 m (Fig. 57). This connection was commissioned in 1975 at the Wehr pumped storage station in the Black Forest in Southern Germany.

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For further information please contact: Fax: ++ 49-9131-7-3 44 98 e-mail: [email protected]

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Fig. 61: Siemens lab prototype for dielectric tests


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Overhead Power Lines

Introduction 1

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Since the very beginning of electric power, overhead lines have constituted the most important component for transmission and distribution. Their portion of overall length of electric circuits depends on the voltage level as well as on local conditions and practice. In densely populated areas like Central Europe, underground cables prevail in the distribution sector and overhead power lines in the high-voltage sector. In other parts of the world, for example in North America, overhead lines are often used also for distribution purposes within cities. Siemens has planned, designed and erected overhead power lines on all important voltage levels in many parts of the world.

2000

MW

Power per circuit

1000

750 kV

500

200

Selection of line voltage 5

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For distribution and transmission of electric power standardized voltages according to IEC 60038 are used worldwide. For three-phase AC applications, three voltage levels are distinguished: ■ The low-voltage level up to 1 kV ■ The medium-voltage level between 1 kV and 36 kV and ■ The high-voltage level up to 800 kV. For DC transmission the voltages vary from the mentioned data. Low-voltage lines serve households and small business consumers. Lines on the medium-voltage level supply small settlements, individual industrial plants and larger consumers, the electric power being typically less than 10 MVA per circuit. The high-voltage circuits up to 145 kV serve for subtransmission of the electric power regionally and feed the mediumvoltage network. This high-voltage level network is often adopted to support the medium-voltage level even if the electric power is below 10 MVA. Moreover, some of these high-voltage lines also transmit the electric power from medium-sized generating stations, such as hydro plants on small and medium rivers, and supply largescale consumers, such as sizable industrial plants or steel mills. They constitute the connection between the interconnected high-voltage grid and the local distribution networks. The bandwidth of electrical power transported corresponds to the broad range of utilization, but, rarely exceeds 100 MVA per circuit, while the surge impedance load is 35 MVA (approximately).

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380 kV

100

220 kV 50

20

110 kV Transmission distance 10 10

20

50

100

200

500 km

Fig. 62: Selection of rated voltage for power transmission

245 kV lines were used in Central Europe for interconnection of utility networks before the changeover to the 420 kV level for this purpose. Long-distance transmission, for example between the hydro power plants in the Alps and the consumers, was performed out by 245 kV lines. Nowadays, the importance of 245 kV lines is decreasing due to the application of 420 kV.

The 420 kV level represents the highest voltage used for AC transmission in Central Europe with the task of interconnecting the utility networks and of transmitting the energy over long distances. Some 420 kV lines connect the national grids of the individual European countries enabling Europewide interconnected network operation. Large power plants, such as nuclear stations, feed directly into the 420 kV network. The thermal capacity of the 420 kV circuits may reach 2000 MVA with a surge impedance load of approximately 600 MVA and a transmission capacity up to 1200 MVA.



Selection of conductors and ground wires

Rated voltage [kV]

20

110

220

380

750

Highest system voltage [kV]

24

123

245

420

800

Nominal cross-section

[mm2]

Conductor diameter

[mm]

Ampacity (at 80 °C conductor temperature) [A] Thermal capacity

[MVA]

150 300

bundle bundle bundle bundle 435 2x240 4x240 2x560 4x560

9.6 15.5 17.1 24.5

28.8 2x21.9 4x21.9 2x32.2 4x32.2

210

410

470 740

900

1290

2580

2080

4160

7

14

90 140

340

490

1700

1370

5400

0.030 0.026

0.013

50

120

Resistance at 20 °C [Ω/km] 0.59 0.24 0.19 0.10 0.067 0.059 Reactance at 50 Hz [Ω/km] 0.39 0.34 0.41 0.38

0.4

0.32

0.26

0.27

0.28

Effective capacitance

[nF/km]

9.7 11.2

9.3

10

9.5

11.5

14.4

13.8

13.1

Capacitance to ground

[nF/km]

3.4

3.6

4.0 4.2

4.8

6.3

6.5

6.4

6.1

[kVA/km]

1.2

1.4

35

38

145

175

650

625

2320

Ground-fault current [A/km] 0.04 0.04 0.25 0.25

0.58

0.76

1.35

1.32

2.48

[Ω]

360

310

375 350

365

300

240

250

260

[MVA]

–

–

35

135

160

600

577

2170

Charging power

Surge impedance Surge impedance load

32

Fig. 63: Electric characteristics of AC overhead power lines (Data refer to one circuit of a double-circuit line)

Overhead power lines with voltages higher than 420 kV are needed to economically transmit bulk electric power over long distances, a task typically arising when utilizing hydro energy potentials far away from consumer centers. Fig. 62 depicts schematically the range of application for the individual voltage levels depending on the distance of transmission and the power rating.

The voltage level has to be selected based on the duty of the line within the network or on results of network planning. Siemens has carried out such studies for utilities all over the world.


1

Conductors represent the most important components of an overhead power line since they have to ensure economical and reliable transmission and contribute considerably to the total line costs. For many years aluminum and its alloys have been the prevailing conducting materials for power lines due to the favorable price, the low weight and the necessity of certain minimum cross-sections. The conductors are prone to corrosion. Aluminum, in principle, is a very corrosive metal. However, a dense oxide layer is formed which stops further corrosive attacks. Therefore, aluminum conductors are well-suited also for corrosive areas, for example a maritime climate. For aluminum conductors there are a number of different designs in use. All-aluminum conductors (AAC) have the highest conductivity for a given cross-section, however possess only a low mechanical strength, which limits their application to short spans and low tensile forces. To increase the mechanical strength, wires made of aluminum-magnesium-silicon alloys are adopted, the strength of which is twice that of pure aluminum. All-aluminum and aluminum alloy conductors have shown susceptibility against eolian vibrations. Compound conductors with a steel core, so-called aluminum cables, steel reinforced (ACSR), avoid this disadvantage. The ratio between aluminum and steel ranges from 4.3:1 to 11:1. Experience has demonstrated that ACSR has a long life, too. Conductors are selected according to electrical, thermal, mechanical and economic aspects. The electric resistance as a result of the conducting material and its crosssection is the most important feature affecting the voltage drop and the energy losses along the line and, therefore, the transmission costs. The cross-section has to be selected such that the permissible temperatures will not be exceeded during normal operation as well as under short circuit. With increasing cross-section the line costs increase, while the costs for losses decrease. Depending on the duty of a line and its power, a cross-section can be determined which results in lowest transmission costs. This cross-section should be aimed for. The heat balance of ohmic losses and solar radiation against convection and radiation determines the conductor temperature. A current density of 0.5 to 1.0 A /mm2 has proven to be an economical solution.

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High voltage results in correspondingly high-voltage gradients at the conductors and in corona-related effects such as visible discharges, radio interference, audible noise and energy losses. When selecting the conductors, the voltage gradient has to be limited to values between 15 and 17 kV/cm. This aspect is important for lines with voltages of 245 kV and above. Therefore, bundle conductors are adopted for extra-high-voltage lines. Fig. 63 shows typical conductor configurations. From the mechanical point of view the conductors have to be designed for everyday conditions and for maximum loads exerted on the conductor by wind and ice. As a rough figure, an everyday stress of approximately 20% of the conductor ultimate tensile stress can be adopted, resulting in a limited risk of conductor damage. Ground wires can protect a line against direct lightning strokes and improve the system behavior in case of short circuits; therefore, lines with single-phase voltages of 110 kV and above are usually equipped with ground wires. Ground wires made of ACSR with a sufficiently high aluminum cross-section satisfy both requirements.

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10

2/42

Selection of insulators Overhead line insulators are subject to electrical and mechanical stress since they have to insulate the conductors from potential to ground and must provide physical supports. Insulators must be capable of withstanding these stresses under all conditions encountered in a specific line. The electrical stresses result from ■ The power frequency voltage ■ Temporary overvoltages at power frequency and ■ Switching and lightning overvoltages. Various insulator designs are in use, depending on the requirements and the experience with certain insulator types. Cap and pin-type insulators (Fig. 64) are made of porcelain or glass. The individual units are connected by fittings of malleable cast iron. The insulating bodies are not puncture-proof which is the reason for relatively numerous insulator failures. In Central Europe long-rod insulators (Fig. 65) are most frequently adopted. These insulators are puncture-proof. Failures under operation are extremely rare. Long-rod insulators show a superior behavior especially under pollution. The tensile loading of the porcelain body forms a disadvantage, which requires relatively large cross-sections. Composite insulators are made of a core with fiberglass-reinforced resin and sheds of differing plastic materials. They offer light weight and high tensile strength and will gain increasing importance for high-voltage lines. Insulator sets must provide a creepage path long enough for the expected pollution level, which is classified according to IEC 60815 from light with 16 mm/kV up to very heavy with 31 mm/kV. To cope with switching and lightning overvoltages, the insulator sets have to be designed with respect to insulation coordination according to IEC 60071-1. These design aspects determine the gap between the grounded fittings and the live parts. Suspension insulator sets carry the conductor weight and are arranged more or less vertically. There are I-shaped (Fig. 66a) and V-shaped sets in use. Single, double or triple sets cope with the mechanical loadings and the design requirements. Tension insulator sets (Fig. 66b, c) terminate the conductors and are arranged in the direction of the conductors. They are loaded by the conductor tensile force and have to be rated accordingly.

Fig. 64: Cap and pin-type insulator

Fig. 65: Long-rod insulator with clevis and tongue connection



Cross arm

1

2

3

4

5

6

Conductor

7

Fig. 66a: I-shaped suspension insulator set for 245 kV

Cross arm

8

9

Fig. 66b: Double tension insulator set for 245 kV (elevation)

Cross arm

Conductor

10

Fig. 66c: Double tension insulator set for 245 kV (plan)


2/43


Selection and design of supports 1

2

3

4

5

6

7

8

9

10

Together with the line voltage, number of circuits and type of conductors the configuration of the circuits determines the design of overhead power lines. Additionally, lightning protection by ground wires, the terrain and the available space at the tower sites have to be considered. In densely populated areas like Central Europe, the width of right-of-way and the space for the tower sites are limited. In the case of extra-high voltages the conductor configuration affects the electrical characteristics and the transmission capacity of the line. Very often there are contradicting requirements, such as a tower height as low as possible and a narrow right-of-way, which can only be met partly by compromises. The mutual clearance of the conductors depends on the voltage and the conductor sag. In ice-prone areas conductors should not be arranged vertically in order to avoid conductor clashing after ice shedding. For low- and medium-voltage lines horizontal conductor configurations prevail which feature line post insulators as well as suspension insulators. Preferably poles made of wood, concrete or steel are used. Fig. 67 shows some typical line configurations. Ground wires are omitted at this voltage level. For high and extra-high-voltage power lines a large variety of configurations are available which depend on the number of circuits and on local conditions. Due to the very limited right-of-way, more or less all high-voltage lines in Central Europe comprise at least two circuits. Fig. 68 shows a series of typical tower configurations. Arrangement e) is called the ”Danube“ configuration and is most often adopted. It represents a fair compromise with respect to width of right-of-way, tower height and line costs. For lines comprising more than two circuits there are many possibilities for configuring the supports. In the case of circuits with differing voltages those circuits with the lower voltage should be arranged in the lowermost position (Fig. 68g). The arrangement of insulators depends on the task of a support within the line. Suspension towers support the conductors in straight-line sections and at small bends. This tower type results in the lowest costs; special attention should therefore be paid to using this tower type as often as possible.

a

b

c

d

Fig. 67: Configurations of medium-voltage supports

a

b

e

f

d

c

h

g

Fig. 68: Tower configurations for high-voltage lines

2/44



Angle towers have to carry the conductor tensile forces at angle points of the line. The tension insulator sets permanently exert high forces on the supports. Various loading conditions have to be met when designing angle towers. The climatic conditions are a determining factor as well. Finally, dead-end towers are used at the ends of a transmission line. They carry the total conductor tensile forces of the connection to the substations. Depending on the size of the supports and the acting forces, differing designs and materials are adopted. Poles made of wood, concrete or steel are very often used for low and medium-voltage lines. Towers with lattice steel design, however, prevail at voltage levels of 110 kV and above (Fig. 69). When designing the support a number of conditions have to be considered. High wind and ice loads cause the maximum forces to act on suspension towers. In ice-prone areas unbalanced conductor tensile forces can result in torsional loading. Additionally, special loading conditions are adopted for the purpose of failure containment, i.e. to limit the extent of damage. Finally, provisions have to be made for construction and maintenance conditions. Siemens adopts modern computer programs for tower design in order to optimize the structures, select components and joints and determine foundation loadings. The stability of the support poles and towers needs also accordingly designed foundations. The type of towers and poles, the loads, the soil conditions as well as the accessibility to the line route and the availability of machinery determine the selection and design of foundation. Concrete blocks or concrete piers are in use for poles which exert bending moments on the foundation. For towers with four legs a foundation is provided for each individual leg (Fig. 70). Pad-andchimney and concrete block foundations require good bearing soil conditions without ground water. Driven or augured piles and piers are adopted for low bearing soil, for sites with bearing soil in a greater depth and for high ground water level. In this case the soil conditions must permit pile driving. Concrete slabs can be used for good bearing soil, when subsoil and ground water level prohibit pad and chimney foundations as well as piles. Siemens can design all types of foundation and has the necessary equipment, such as pile drivers, grouting devices, soil and rock drills, at its command to build all types of power line foundations.

1

2

3

4

5 Fig. 69: Lattice steel towers of a high-voltage line

6 Pad-and-chimney foundation

Auger-bored foundation

7

8

Rock anchor foundation

9

Pile foundation

10

Fig. 70: Foundations for four-legged towers


2/45


f40=6.15 fE =6.60

302.50

1

300.70

6.07 5.74

2

f40= fE =

292.00

0.47

292.00

16.00 10.00

13.00

f40=2.11 282.00

16.20

1 1

279.00 2 T+0 DH

1 WA+0 DA

3

1 1

4

5

6

7

8 255.00 232.50

9

175.00 o. D.

286.50

276.50

273.50 273.00

281.50 0.0

0.1

0.0

10

132.0 106.0

M20 190.00g Left conductor 251.47 m 171°0´ 60.0m 50g 6.0 6.0 60.0m

283.00 275.50 270.50 270.00 265.00 284.50 275.00 270.50 272.50 267.50 264.00

0.2

66.0 36.0

190.00g

280.00 280.50

194.0 166.0

251.0 20 kV line

0.3

462

42

Ro at

M21

Fig. 71: Line profile established by computer

2/46

0.4

264.0 302.0 331.0 360.0 405.0 251.0 291.0 316.0 346.0 386.0 426.0

4.0 4.0

263.


0 64.00


1 f40=17.46 fE =16.52

284.20 17.30 16.75 16.38 15.86

11.38 12.29 263.00

Arable land

Stream

Meadow

Road

Fallow land

Forest

2

Ground wire: ACSR 265/35 * 80.00 N/mm2 Conductor: ACSR 265/35 * 80.00 N/mm2 Equivalent sag: 11.21 m at 40 °C Equivalent span: 340.44 m

7.55 8.44

3

Bushes, height up to 5 m

4

24.20 f40=5.56 fE =5.87

5 4 WA+0 DA

6

223.00

7 1.45 16.00

8 270.00 292.50 263.00 266.50

4

0 426.0

3 T+8 DH

265.50 264.00

261.50

0.5 462.0

258.50

260.00 260.00 260.00

626.0

666.0 688.0 676.0

0.6

534.0 506.0 544.0

236.00 247.50

0.7

586.0

0.8 776.0 744.0

Road to XXX 425.0

13.9g

4.0 4.0

Road crossing at km 10.543


223.00 229.00 215.50

234.0

9

209.00 207.00 0.9

826.0 804.0 848.0

904.0 910.0

10

Left conductor 235.45 m 169.00g 152°6´ 5.8 5.8 169.00g

2/47


1

2

3

4

5

6

Route selection and tower spotting

Siemens’ activities and experience

Route selection and planning represent increasingly difficult tasks since the rightof-way for transmission lines is limited and many aspects and interests have to be considered. Route selection and approval depend on the statutory conditions and procedures and always involve iterative studies carried out in the office and surveys in the terrain which consider and evaluate a great variety of alternatives. After definition of the route the longitudinal profile has to be surveyed, identifying all crossings over roads, rivers, railways, buildings and other overhead power lines. The results are evaluated with computer programs to calculate and plot the line profile. The towers are spotted by means of computer programs as well, which take into account the conductor sags under different conditions, the ground clearances, objects crossed by the line, technical data of the available tower range, tower and foundation costs and costs for compensation of landowners. The result is an economical design of a line, which accounts for all the technical and environmental conditions. Line planning forms the basis for material acquisition and line erection. Fig. 71 shows a line profile established by computer.

Siemens has been active in the overhead power line field for more than 100 years. The activities comprise design and construction of rural electrification schemes, low and medium-voltage distribution lines, high-voltage lines and extra-high-voltage installations. To give an indication of what has been carried out by Siemens, approximately 20,000 km of high-voltage lines up to 245 kV and 10,000 km of extra-high-voltage lines above 245 kV have been set up so far. Overhead power lines have been erected by Siemens in Germany and Central Europe as well as in the Middle East, Africa, the Far East and South America. The 420 kV transmission lines across the Elbe river in Germany comprising four circuits and requiring 235 m tall towers as well as the 420 kV line across the Bosphorus in Turkey with a span of approximately 1800 m (Fig. 72) are worthy of special mention. For further information please contact: Fax: ++ 49 - 9131- 33 5 44 e-mail: heinz-juergen.theymann@erls04. siemens.de

7 BT1

BS1

BS BT

suspension tower tension tower

BS2

BT2

8 37.5 124

124

9 27.5

10 119

112

70

162.5

125

Dimensions in m 674

1757

Europe

Bosphorus

668

Asia

Fig. 72: 420 kV line across the Bosphorus, longitudinal profile

2/48


High-Voltage Direct Current Transmission

HVDC When technical and/or economical feasibility of conventional high voltage AC transmission technology reach their limits, high voltage DC can offer the solution, namely ■ For economical transmission of bulk power over long distances ■ For interconnection of asynchronous power grids ■ For power transmission across the sea, when a cable length is long ■ For interconnection of synchronous but weak power grids, adding to their stability ■ For additional exchange of active power with other grids without having to increase the short-circuit power of the system ■ For increasing the transmission capacity of existing rights-of-way by changing from AC to DC transmission system Siemens offers HVDC systems as ■ Back-to-Back (B/B) stations to interconnect asynchronous networks, without any DC transmission line in between ■ Power transmission via Dc submarine cables ■ Power transmission via long-distance DC overhead lines

1

2

3

4 Fig. 76: Earthquake-proof, fire-retardant thyristor valves in Sylmar East, Los Angeles

Fig. 75: Long-distance transmission

Special features Back-to-Back (B/B): To connect asynchronous high voltage power systems or systems with different frequencies. To stabilize weak AC links or to supply even more active power, where the AC system reaches the limit of short-circuit capability.

Fig. 73: Back-to-back link between asynchronous grids

Cable transmission (CT): To transmit power across the sea with cables to supply islands/offshore platforms from the mainland and vice-versa.

Fig. 74: Submarine cable transmission

Long-distance transmission (LD): For transmission of bulk power over long distances (beyond approx. 600 km, considered as the break-even distance).

5

systems for all functions. Redundant design for fault-tolerant systems.

Valve technology ■ Simple, easy-to-maintain mechanical design ■ Use of fire-retardant, self-extinguishing material ■ Minimized number of electrical connections ■ Minimized number of components ■ Avoidance of potential sources of failure ■ ”Parallel“ cooling for the valve levels ■ Oxygen-saturated cooling water. After more than 20 years of operation, thyristor valves based on this technology have demonstrated their excellent reliability. ■ The recent introduction of direct lighttriggered thyristors with integrated overvoltage protection further simplifies the valve and reduces maintenance requirements. Control system In our HVDC control system, high-performance components with proven records in many other standard fields of application have been integrated, thus adding to the overall reliability of the system. Use of ”state-of-the-art“ microprocessor


Filter technology Single, double and triple-tuned as well as high-pass passive filters, or any combination thereof, can be installed. Active filters, mainly for the DC circuit, are available. Wherever possible, identical filters are selected so that the performance does not significantly change when one filter has to be switched off. Turnkey service Our experienced staff are prepared to design, install and commission the whole HVDC system on a turnkey basis.

6

7

8

Project financing We are in a position to assist our customers in finding proper project financing, too. General services ■ Extended support to customers from the very beginning of HVDC system planning including – Feasibility studies – Drafting the specification – Project execution – System operation and – Long-term maintenance – Consultancy on upgrading/replacement of components/redesign of older schemes, e.g. retrofit of mercury-arc valves or relay-based controls

2/49

9

10


■ Studies during contract execution on:

1

2

3

4

5

6

7

– HVDC systems basic design – System dynamic response – Load flow and reactive power balance – Harmonic voltage distortion – Insulation coordination – Interference of radio and PLC – Special studies, if any Typical ratings Some typical ratings for HVDC schemes are given below for orientation purposes only: B/B: 100 ... 600 MW CT: 100 ... 800 MW LD: 300 ... 3000 MW (bipolar), whereby the lower rating is mainly determined by economic aspects and the higher one limited by the constraints of the interconnected networks. Innovations In recent years, the following innovative technologies and equipment have for example been successfully implemented by Siemens in diverse HVDC projects worldwide: ■ Direct light-triggered thyristors (already mentioned above) ■ Hybrid-optical DC measuring system (Fig. 77) ■ Active harmonic filters ■ Advanced eletrode line monitoring of bipolar HVDC systems ■ An SF6 HVDC circuit-breaker for use as Metallic Return Transfer Breaker, developed from a standard AC high-voltage breaker.

8

2

9

3 1

10

Fig. 78: HVDC outdoor valves, 533 kV (Cahora Bassa Rehabilitation, Southern Africa)

Rehabilitation and modernization of existing HVDC stations (Fig. 78) The integration of state-of-the-art microprocessor systems or thyristors allows the owner better utilization of his investment, e.g. ■ Higher availability ■ Fewer outages ■ Lower losses ■ Better performance values ■ Less maintenance. Higher availability means more operating hours, better utilization and higher profits for the owner. The new Human-Machine Interface (HMI) system enhances the user-friendliness and increases the reliability considerably due to the operator guidance. This rules out maloperation by the operator, because an incorrect command will be ignored by the HMI.

Fig. 77: Conventional DC measuring device (1) vs. the new hybrid-optical device (2) with composite insulator (3) shows the reduced space requirement for the new system (installed at HVDC converter station Sylmar, USA)

2/50



For further information please contact: Fax: ++ 49 - 9131- 73 45 52 e-mail: [email protected]

1

2

3

4

5

HMI

GPS

6 LAN

7 VCS Pole 1

SER

HMI GPS OLC CLC VBE VCS SER

Human-machine Interface Global Positioning System Open-Loop Control Closed-Loop Control Valve Base Electronics Valve Cooling Systems Sequence of Event Recording TFR Transient Fault Recording LAN Local Area Network

OLC Pole 1

OLC SC

CLC VBE Pole 1

OLC Pole 2

CLC VBE Pole 2

VCS Pole 2

8

Communication link to the load dispatch center

9 Communication link to the remote station

TFR

DC Protection

TFR

Communication link to the remote station

10 DC Yard

Fig. 79: Human-Machine Interface with structure of HVDC control system


2/51

Power Compensation in Transmission Systems

Introduction 1

2

3

4

5

In many countries increasing power consumption leads to growing and more interconnected AC power systems. These complex systems consist of all types of electrical equipment, such as power plants, transmission lines, switchgear transformers, cables etc., and the consumers. Since power is often generated in those areas of a country with little demand, the transmission and distribution system has to provide the link between power generation and load centers. Wherever power is to be transported, the same basic requirements apply: ■ Power transmission must be economical ■ The risk of power system failure must be low ■ The quality of the power supply must be high However, transmission systems do not behave in an ideal manner. The systems react dynamically to changes in active and reactive power, influencing the magnitude and profile of the power systems voltage. Fig. 80: STATCOM inverter hall

6

7

8

9

10

Examples: ■ A load rejection at the end of a long-dis-

tance transmission line will cause high overvoltages at the line end. However, a high load flow across the same line will decrease the voltage at its end. ■ The transport of reactive power through a grid system produces additional losses and limits the transmission of active power via overhead lines or cables. ■ Load-flow distribution on parallel lines is often a problem. One line could be loaded up to its limit, while another only carries half or less of the rated current. Such operating conditions limit the actual transmittable amount of active power. ■ In some systems load switching and/or load rejection can lead to power swings which, if not instantaneously damped, can destabilize the complete grid system and then result in a “Black Out”. Reactive power compensation helps to avoid these and some other problems. In order to find the best solution for a grid system problem, studies have to be carried out simulating the behavior of the system during normal and continuous operating conditions, and also for transient events. Study facilities which cover digital simulations via computer as well as analog ones in a transient network analyzer laboratory are available at Siemens.

2/52

Further information please contact: Fax: ++ 49 - 9131- 73 45 54 e-mail: [email protected]



Types of reactive power compensation

Concept

Operating diagram

Parallel compensation

1 Un

1

Parallel compensation is defined as any type of reactive power compensation employing either switched or controlled units, which are connected parallel to the transmission network at a power system node. In many cases switched compensation (reactors, capacitor banks or filters) can provide an economical solution for reactive power compensation using conventional switchgear.

2

3

In comparison to mechanically-switched reactive power compensation, controlled compensation (SVC, Fig. 81) offers the advantage that rapid dynamic control of the reactive power is possible within narrow limits, thus maintaining reactive power balance. Fig. 82 is a general outline of the problemsolving applications of SVCs in high-voltage systems. STATCOM The availability of high power gate-turn-off (GTO) thyristors has led to the development of a Static Synchronous Compensator (STATCOM), Fig. 80, page 2/52. The STATCOM is an “electronic generator” of dynamic reactive power, which is connected in shunt with the transmission line (Fig. 83) and designed to provide smooth, continuous voltage regulation, to prevent voltage collapse, to improve transmission stability and to dampen power oscillations. The STATCOM supports subcycle speed of response (transition between full capacitive and full inductive rating) and superior performance during system disturbances to reduce system harmonics and resonances. Particular advantages of the equipment are the compact and modular construction that enables ease of siting and relocation, as well as flexibility in future rating upgrades (as grid requirements change) and the generation of reactive current irrespective of network voltage.

4

2

Static VAr compensator (SVC)

1 2 3 4

4

Iind

3

Icap

Transformer Thyristor-controlled reactor (TCR) Fixed connected capacitor/filter bank Thyristor-switched capacitor bank (TSC)

4

Fig. 81: Static VAr compensator (SVC)

5 Voltage control Reactive power control Overvoltage limitation at load rejection Improvement of AC system stability Damping of power oscillations Reactive power flow control Increase of transmission capability Load reduction by voltage reduction Subsynchronous oscillation damping

6

7

Fig. 82: Duties of SVCs

8 Concept

Operating diagram

UN

UN

I

9

US

10

Id UD

Iind

Icap

Fig. 83: STATCOM


2/53


1

2

3

4

5

6

Series compensation

Synchronous Series Compensation (SSSC)

Series compensation is defined as insertion of reactive power elements into transmission lines. The most common application is the series capacitor.

The Static Synchronous Series Compensator (SSSC) is a solid-state voltage generator connected in series with the transmission line through an insertion transformer (Fig. 85). The generation of a boost voltage advancing or lagging behind the line current by 90° affects the voltage drop caused at the line reactance and can be used to dampen transient oscillations and control real power flow independent of the magnitude of the line current.

Thyristor-Controlled Series Compensation (TCSC) By providing continuous control of transmission line impendance, the Thyristor Controlled Series Compensation (TCSC, Fig. 84) offers several advantages over conventional fixed series capacitor installations. These advantages include: ■ Continuous control of desired compensation level ■ Direct smooth control of power flow within the network ■ Improved capacitor bank protection ■ Local mitigation of subsynchronous oscillations (SSR). This permits higher levels of compensation in networks where interactions with turbine-generator torsional vibrations or with other control or measuring systems are of concern. ■ Damping of electromechanical (0.5–2 Hz) power oscillations which often arise between areas in a large interconnected power network. These oscillations are due to the dynamics of interarea power transfer and often exhibit poor damping when the aggregate power transfer over a corridor is high relative to the transmission strength.

Concept

Operating diagram

UT

I Inductive

I

Capacitive

Id UD

UT

Fig. 85: Static Synchronous Series Compensator (SSSC)

7 Concept

Operating diagram Bypass switch

8

Bank disconnect switch 1

9

Bypass circuit breaker MOV arrester

Capacitors

10

Thyristor valve

Bank disconnect switch 2

[Z]

Inadmissible area

Damping circuit

Thyristor controlled reactor

Valve arrester

Inductive Triggered spark gap

90°

Ignition angle α

Capacitive

180°

Fig. 84: Thyristor controlled Series Compensation (TCSC). Example: Single line diagram TCSC S. da Mesa

2/54



Unified Power Flow Controller (UPFC)

Concept

The Unified Power Flow Controller (UPFC) is the fastest and most versatile FACTS controller (Fig. 86). The UPFC constitutes a combination of the STATCOM and the SSSC. It can provide simultaneously and independently real time control of all basic power system parameters (transmission voltage, impedance and phase angle), determinig the transmitted real and reactive power flow to optimize line utilization and system capability. The UPFC can enhance transmission stability and dampen system oscillations.

Vector diagram

1

UT Ua

UT

Ub

2 Ua GTO Converter 1

Ub

3

GTO Converter 2

Fig. 86: Unified power-flow controller (UPFC)

4

Comparison of reactive power compensation facilities

5

The following tables show the characteristics and application areas of UPFC (Fig. 87a), parallel compensation and series compensation (Fig. 87b, page 2/56) and the influence on various parameters such as short-circuit rating, transmission phase angle and voltage behavior at this load.

6

7 Compensation element

Location

Shortcircuit level

Behavior of compensation element Voltage TransmisVoltage influence sion phase after load angle rejection

Applications

8

UPFC (Parallel and/or series compensation)

1

UPFC

Reduced E

U UPFC

Controlled

Controlled

Limited by control

Real and reactive power flow control, enhancing transmission stability and dampening system oscillations

9

10 Fig. 87a: Components for reactive power compensation, UPFC


2/55


1

Compensation element

Location

Shortcircuit level

Behavior of compensation element Voltage TransmisVoltage influence sion phase after load angle rejection

Applications

Parallel compensation

2

2

Shunt capacitor

Little influence

Voltage rise

Little influence

High

Voltage stabilization at high load

Little influence

Voltage drop

Little influence

Low

Reactive power compensation at low load; limitation of temporary overvoltage

Little influence

Controlled

Little influence

Limited by control

Reactive power and voltage control, damping of power swings to improve system stability

No influence

Controlled

Little influence

Limited by control

Reactive power and voltage control, damping of power swings

Increased

Very good

Much smaller

(Very) low

Long transmission lines with high transmission power rating

Reduced

(Very) slight

(Much) larger

(Very) high

Short lines, limitation of SC power

Variable

Very good

Much smaller

(Very) low

Long transmission lines, power flow distribution between parallel lines and SSR damping

Reduced

Controlled

Controlled

Limited by control

Real power flow control, damping of transient oscillations

U

E

3 3

Shunt reactor

U

E

4 4

5 5

Static VAr compensator (SVC)

U

STATCOM

6

7

SVC

E

E

ST

U

Series compensation 6

Series capacitor

E

U

8 7

Series reactor

E

U

9 8

10 9

Thyristor Controlled SeriesCompensation (TCSC)

TCSC

E

U

SSSC SSSC

E

U

Fig. 87b: Components of reactive power compensation, parallel compensation/series compensation

2/56


Medium-Voltage Switchgear Contents

Page

Introduction ...................................... 3/2 Primary Distribution Selection Criteria and Explanations ...................................... 3/4 Selection Matrix ............................... 3/6 Air-Insulated Switchgear ............... 3/8 SF6-Insulated Switchgear ............ 3/24 Secondary Distribution General ............................................. 3/46 Selection Matrix ............................. 3/48 Ring-Main Units ............................. 3/50 Consumer Substations .................. 3/60 Transformer Substations .............. 3/66 Industrial Load Center .................. 3/68 Medium-Voltage Devices Product Range ................................ 3/72 Vacuum Circuit-Breakers and Contactors ............................... 3/74 Vacuum Interrupters ..................... 3/85 Disconnectors/ Grounding Switches ...................... 3/86 HRC Fuses ....................................... 3/88 Insulators and Bushings .............. 3/89 Current Transformers/ Voltage Transformers .................... 3/90 Surge Arresters .............................. 3/90

3

Medium-Voltage Switchgear

Introduction 1

2

3

Primary and secondary distribution stands for the two basic functions of the mediumvoltage level in the distribution system. ‘Power Supply Systems’ (PSS) includes the equipment of the Primary and Secondary Distribution, all interconnecting equipment (cables, transformers, control systems, etc.) down to LV consumer distributions as well as all the relating planning, engineering, project/site management, installation and commissioning work involved, including turnkey projects with all necessary electrical and civil works equipment (Fig. 1).

4

5

6

7

8

9

10

3/2

‘Primary distribution’ means the switchgear installation in the HV/MV transformer main substations. The capacity of equipment must be sufficient to transport the electrical energy from the HV/MV transformer input (up to 63 MVA) via busbar to the outgoing distribution lines or cable feeders. The switchgear in these main substations is of high importance for the safe and flexible operation of the distribution system. It has to be very reliable during its lifetime, flexible in configuration, and easy to operate with a minimum of maintenance. The type of switchgear insulation (air or SF6) is determined by local conditions, e.g. space available, economic considerations, building costs, environmental conditions and the relative importance of maintenance. Design and configuration of the busbar are determined by the requirements of the local distribution system. These are: ■ The number of feeders is given by the outgoing lines of the system ■ The busbar configuration depends on the system (ring, feeder lines, opposite station, etc.) ■ Mode of operation under normal conditions and in case of faults ■ Reliability requirements of consumers, etc. Double busbars with longitudinal sectionalizing give the best flexibility in operation. However, for most of the operating situations, single busbars are sufficient if the distribution system has adequate redundancy (e.g. ring-type system). If there are only a few feeder lines which call for higher security, a mixed configuration is advisable. It is important to prepare enough spare feeders or at least space in order to extend the switchgear in case of further development and the need for additional feeders. As these substations, especially in densely populated areas, have to be located right in the load center, the switchgear must be space-saving and easy to install. The installation of this switchgear needs thorough planning in advance, including the system configuration and future area development. Especially where existing installations have to be upgraded, the situation of the distribution system should be analyzed for simplification (system planning and architectural system design).

‘Secondary distribution’ is the local area supply of the individual MV/LV substations or consumer connecting stations. The power capacity of MV/LV substations depends on the requirements of the LV system. To reduce the network losses, the transformer substations should be installed directly at the load centers with typical transformer ratings of 400 kVA to max. 1000 kVA. Due to the great number of stations, they must be space-saving and maintenance-free. For high availability, MV/LV substations are mostly looped in by load-break switches. The line configuration is mostly of the open-operated ring type or of radial strands with opposite switching station. In the event of a line fault, the disturbed section will be switched free and the supply is continued by the second side of the line. This calls for reliable switchgear in the substations. Such transformer substations can be prefabricated units or single components, installed in any building or rooms existing on site, consisting of medium-voltage switchgear, transformers and low-voltage distri-bution. Because of the extremely high number of units in the network, high standardization of equipment is necessary. The most economical solution for such substations should have climate-independent and maintenance-free equipment, so that operation of equipment does not require any maintenance during its lifetime. Consumers with high power requirements have mostly their own distribution system on their building area. In this case, a consumer connection station with metering is necessary. Depending on the downstream consumer system, circuit breakers or loadbreak switches have to be installed. For such transformer substations nonextensible and extensible switchgear, for instance RMUs, has been developed using SF6 gas as insulation and arc-quenching medium in the case of load-break systems (RMUs), and SF6-gas insulation and vacuum (for vcb feeders) as arc-quenching medium in the case of extensible modular switchgear, consisting of load-break panels with or without fuses, circuit-breaker panels and measuring panels.


Medium-Voltage Switchgear

1

Subtransmission up to 145 kV

Main substation

2 HV/MV transformers up to 63 MVA

3

Primary distribution MV up to 36 kV

4

5 Secondary distribution

6

7

open ring

closed ring

8 Diagram 1:

Diagram 2:

Diagram 3:

9

10

Substation

Customer station with circuit-breaker incoming panel and load-break switch outgoing panels

Extensible switchgear for substation with circuit-breakers e.g. Type 8DH

Fig. 1: Medium voltage up to 36 kV – Distribution system with two basic functions: Primary distribution and secondary distribution


3/3

Primary Distribution Selection Criteria and Explanations

General 1

Single busbar with bus-tie breaker

Double busbars with dual-feeder breakers

Double busbars with single-feeder breakers

Double-busbar switchboard with single-busbar feeders

Codes, standards and specifications

2

3

4

5

6

7

8

9

10

Design, rating, manufacture and testing of our medium-voltage switchboards is governed by international and national standards. Most applicable IEC recommendations and VDE/DIN standards apply to our products, whereby it should be noted that in Europe all national electrotechnical standards have been harmonized within the framework of the current IEC recommendations. Our major products in this section comply specifically with the following code publications: ■ IEC 60 298 AC metal-enclosed switchgear and controlgear for rated voltages above 1 kV and up to and including 72.5 kV ■ IEC 60 694 Common clauses for highvoltage switchgear and controlgear standards ■ IEC 60 056 High-voltage alternating-current circuit-breakers ■ IEC 60 265-1 High-voltage switches ■ IEC 60 470 High-voltage alternating current contactors ■ IEC 60 129 Alternating current disconnectors (isolators) and grounding switches ■ IEC 60 185 Current transformers ■ IEC 60 186 Voltage transformers ■ IEC 60 282 High-voltage fuses In terms of electrical rating and testing, other national codes and specifications can be met as well, e.g. ANSI C37, 20C, BS 5227, etc. In case of switchgear manufactured outside of Germany in Siemens factories or workshops, certain local standards can also be met; for specifics please inquire. Busbar system Switchgear installations for normal service conditions are preferably equipped with single-busbar systems. These switchboards are clear in their arrangement, simple to operate, require relatively little space, and are low in inital cost and operating expenses. Double-busbar switchboards can offer advantages in the following cases: ■ Operation with asynchronous feeders ■ Feeders with different degrees of importance to maintain operation during emergency conditions ■ Isolation of consumers with shock loading from the normal network

3/4

Fig. 2: Basic basbar configurations for medium-voltage switchgear ■ Balancing of feeder on two systems dur-

ing operation ■ Access to busbars required during operation. In double-busbar switchboards with dual feeder breakers it is possible to connect consumers of less importance by singlebusbar panels. This assures the high availability of a double-busbar switchboard for important panels, e.g. incoming feeders, with the low costs and the low space requirement of a single-busbar switchboard for less important panels. These composite switchboards can be achieved with the types 8BK20 and 8DC11. Type of insulation The most common insulating medium has been air at atmospheric pressure, plus some solid dielectric materials. Under severe climatic conditions this requires precautions to be taken against internal contamination, condensation, corrosion, or reduced dielectric strength in high altitudes.

Since 1982, insulating sulfur-hexafluoride gas (SF6-gas) at slight overpressure has also been used inside totally encapsulated switchboards as insulating medium for medium voltages to totally exclude these disturbing effects. All switchgear types in this section, with the exception of the gas-insulated models 8D and NX PLUS, use air as their primary insulation medium. Ribbed vacuum-potted epoxy-resin post insulators are used as structural supports for busbars and circuit breakers throughout. In the gas-insulated metal-clad switchgear 8D and NX PLUS, all effects of the environment on high-voltage-carrying parts are eliminated. Thus, not only an extremely compact and safe, but also an exceptionally reliable piece of switchgear is available. The additional effort for encapsulating and sealing the high-voltage-carrying parts requires a higher price – at least in voltage ratings below 24 kV. For a price comparison, see the curves on the following page (Figs. 3, 4).


Primary Distribution Selection Criteria and Explanations

Enclosure, Compartmentalization IEC Publ. 60 298 subdivides metal-enclosed switchgear and controlgear into three types: ■ Metal-clad switchgear and controlgear ■ Compartmented switchgear and controlgear ■ Cubicle switchgear and controlgear. Thus “metal-clad” and “cubicle” are subdivisions of metal-enclosed switchgear, further describing construction details. In metal-clad switchgear the components are arranged in 3 separate compartments: ■ Busbar compartment ■ Circuit-breaker compartment ■ Feeder-circuit compartment with earthed metal partitions between each compartment. IEC 60 298-1990-12 Annex AA specifies a “Method for testing the metal-enclosed switchgear and controlgear under conditions of arcing due to an internal fault”. Basically, the purpose of this test is to show that persons standing in front of, or adjacent to a switchboard during internal arcing are not endangered by the effects of such arcs. All switchboards described in this section have successfully passed these type tests. Isolating method To perform maintenance operations safely, one of two basic precautions must be taken before grounding and short-circuiting the feeder: ■ 1. Opening of an isolator switch with clear indication of the OPEN condition. ■ 2. Withdrawal of the interrupter carrier from the operating into the isolation position. In both cases, the isolation gap must be larger than the sparkover distance from live parts to ground to avoid sparkover of incoming overvoltages across the gap. The first method is commonly found in fixed-mounted interrupter switchgear, whereas the second method is applied in withdrawable switchgear. Withdrawable switchgear has primarily been designed to provide a safe environment for maintenance work on circuit interrupters and instrument transformers. Therefore, if interrupters and instrument transformers are available that do not require maintenance during their lifetime, the withdrawable feature becomes obsolete. With the introduction of maintenance-free vacuum circuit-breaker bottles, and instrument transformers which are not subject

Single busbar

Double busbar

! Percentage (8BK20 = 100)

! Percentage (8BK20 = 100)

160

160

130 120 110 100 90 80 70 0

120 8DA10 NX PLUS 110 100 8BK20 90 NX AIR 80 8DC11 70

1

130

7.2

12

15 24 kV

36 Voltage

0

2 8BK20 8DB10 8DC11 7.2

12

15 24 kV

36 Voltage

Fig. 3: Price relation

Fig. 4: Price relation

to dielectric stressing by high voltage, it is possible and safe to utilize totally enclosed, fixed-mounted and gas-insulated switchgear. Models 8DA, 8DB, 8DC and NX PLUS described in this section are of this design. Due to far fewer moving parts and their total shielding from the environment, they have proved to be much more reliable. All air-insulated switchgear models in this section are of the withdrawable type.

able in all ratings – see selection matrix on pages 3/72–3/73 for all power switchgear listed in this section. Due to their maintenance-free design these breakers can be installed inside totally enclosed and gasinsulated switchgear.

Switching device Depending on the switching duty in individual switchboards and feeders, basically the following types of primary switching devices are used in the switchgear cubicles in this section: (Note: Not all types of switching devices can be used in all types of cubicle.)

■ 1. Vacuum circuit-breakers ■ 2. Vacuum contactors in conjunction

with HRC fuses ■ 3. Vacuum switches, switch disconnec-

tors or gas-insulated three-position switch disconnectors in conjunction with HRC fuses. To 1: Vacuum circuit-breakers In the continuing efforts for safer and more reliable medium-voltage circuit-breakers, the vacuum interrupter is clearly the first choice of buyers of new circuit-breakers worldwide. It is maintenancefree up to 10,000 operating cycles without any limitation in terms of time and it is recommended for all generalpurpose applications. If high numbers of switching operations are anticipated (especially autoreclosing in overhead line systems and switching of high-voltage motors), their use is indicated. They are avail-


3

4

5

To 2: Vacuum contactors Vacuum contactors are used for frequent switching operations in motor, transformer and capacitor bank feeders. They are typetested, extremely reliable and compact devices and they are totally maintenance-free. Since contactors cannot interrupt fault currents, they must always be used with current-limiting fuses to protect the equipment connected. Vacuum contactors can be installed in the metal-enclosed, metalclad switchgear types 8BK20, 8BK30 and NXAIR for 7.2 kV/31.5 kA. To 3: Vacuum switches or … Vacuum switches, switch disconnectors and gas-insulated three-position switch disconnectors in primary distribution switchboards are used mostly for small transformer feeders such as auxiliary transformers or load center substations. Because of their inability to interrupt fault currents they must always be used with currentlimiting fuses. Vacuum switches and switch disconnectors can be installed in the airinsulated switchboard types 8BK20 and NXAIR. Gas-insulated three-position switch disconnectors can be installed in the switchboard type 8DC11.

For further information please contact: ++ 49 - 91 31-73 46 39

3/5

6

7

8

9

10

Primary Distribution Selection Matrix

1

Standards

Insulation

Busbar system

Enclosure, compartmentalization

Isolating method

Sw de

2 Metal-enclosed, metal-clad

Draw-out section

Metal-enclosed, metal-clad

Draw-out section

Vac


Draw-out section

Vac

Metal-enclosed, metal-clad cubicle-type

Draw-out section

Vac Vac Sw Vac


Draw-out section

Vac Vac

Metal-enclosed, metal-clad cubicle-type

Draw-out section

Vac Vac Sw

Triple-pole metal-enclosed, metal-clad

Disconnector, fixed-mounted

Vac



Vac Sw

Single-pole metal-enclosed, metal-clad


Vac



Vac Sw

Single-pole metal-enclosed, metal-clad


Vac

Vac Vac

3 Single busbar

4 Type-tested indoor switchgear to IEC 60 298

Air-insulated

5

6

Double busbar

7

8 Single busbar

9 SF6-insulated

10 Double busbar

Fig. 5: Primary Distribution Selection Matrix

3/6


Primary Distribution Selection Matrix

Switching device

Vacuum circuit-breaker Vacuum switch

Switchgear type

8BK20

Technical data

Page

Maximum rated short-time current [kA], 1/3 s

Maximum busbar rated current [A]

Maximum feeder rated current [A]

7.2 kV

7.2 kV

7.2 kV

50

12/15 17.5/24 36 kV kV kV

50

25

–

12/15 17.5/24 36 kV kV kV

4000 4000

2500

–

4000

12/15 17.5/24 36 kV kV kV

4000

2000

–

1

2 3/8

3 Vacuum contactor

8BK30

50

50

–

–

4000 4000

–

–

400

400

–

–

3/13

8BK40

63

63

63*

–

5000 5000

5000*

–

5000

5000

5000*

–

3/16

Vacuum circuit-breaker Vacuum switch Switch disconnector Vacuum contactor

NXAIR

31.5

31.5

25

–

2500 2500

2500

–

2500

2500

2500

–

3/20

5

Vacuum circuit-breaker Vacuum switch

8BK20

50

50

25

–

4000 4000

2500

–

4000

4000

2000

–

3/8

6

Vacuum circuit-breaker Vacuum switch Switch disconnector

NXAIR

31.5

31.5

25

–

2500 2500

2500

–

2500

2500

2500

–

3/20

4

Vacuumcircuit-breaker

7

Vacuum circuit-breaker

NX PLUS

31.5

31.5

31.5

31.5

2500 2500

2500

2500

2500

2500

2500 2500

3/38

8 Vacuum circuit-breaker Switch disconnector

3/24

8DC11

25

25

25

–

1250 1250

1250

–

1250

1250

1250

8DA10

40

40

40

40

3150 3150

3150

2500

2500

2500

2500 2500

3/30

8DC11

25

25

25

–

1250 1250

1250

–

1250

1250

1250

3/24

8DB10

40

40

40

40

3150 3150

3150

2500

2500

2500

2500 2500

–

9

Vacuum circuit-breaker

Vacuum circuit-breaker Switch disconnector

–

Vacuumcircuit-breaker 3/30

* up to 17.5 kV


3/7

10

Air-Insulated Switchgear Type 8BK20

1

Metal-clad switchgear 8BK20, air-insulated ■ From 7.2 to 24 kV ■ Single and double-busbar

2

3

■ ■ ■ ■ ■ ■ ■

(back-to-back or face-to-face) Air-insulated Type-tested Metal-enclosed Metal-clad Withdrawable vacuum breaker Vacuum switch optional For indoor installation

Specific features

4

■ General-purpose switchgear ■ Circuit-breaker mounted on horizontal

slide behind front door ■ Cable connections from front or rear

5

Safety for operating and maintenance personnel ■ All switching operations behind closed

doors ■ Positive and robust mechanical

6

interlocks ■ Arc-fault-tested metal enclosure ■ Complete protection against contact

7

with live parts ■ Line test with breaker inserted (option) ■ Maintenance-free vacuum breaker Tolerance to environment

8

■ Metal enclosure with optional gaskets ■ Complete corrosion protection and

tropicalization of all parts. ■ Vacuum-potted ribbed epoxy insulators

with high tracking resistance

9

10

General description 8BK20 switchboards consist of metal-clad cubicles of air-insulated switchgear with withdrawable vacuum circuit-breakers. Fused vacuum switches can be used optionally. The breaker carriage is fully interlocked with the interrupter and the stationary cubicle. It is manually moved in a horizontal direction from the ”Connected“ position behind the closed front door and without the use of auxiliary equipment. A fully isolated low-voltage compartment is integrated. All commonly used feeder circuits and auxiliary devices are available. The switchgear cubicles and interrupters are factory-assembled and type-tested as per the applicable standards.

3/8

Fig. 6: Metal-clad switchgear type 8BK20 (inter-cubicle partition removed)

Stationary part

Breaker carriage

The cubicle is built as a self-supporting structure, bolted together from rolled galvanized steel sheets and profile sections. Each cubicle is divided into three sealed and isolated compartments by partitions, i.e. the busbar, cable connection and circuitbreaker compartment. The fixed contacts of the primary disconnectors are located within bushings, effectively maintaining the compartmentalization in all operating states of the switchgear. The bushings are covered by automatic steel safety shutters upon removal of the circuit-breaker carriage from the ”Connected“ position. Each compartment in every model has its own pressure-relief device. To reduce internal arcing times and thus consequential damage, pressure switches can be installed that trip the incoming feeder circuitbreaker(s) in less than 100 msec. This is an economical alternative to busbar differential protection.

The carriage normally supports a vacuum circuit-breaker with the associated operating mechanism and auxiliary devices. Fused vacuum switches are optional. By manually moving the carriage with the spindle drive it can be brought into a distinct ”Connected“ and ”Disconnected/ Test“ position. To this effect, the arc and pressure-proof front door remains closed. To remove the switching element completely from its compartment, a central service truck is used. Inspection can easily and safely be carried out with the circuitbreaker in the ”Disconnected/Test“ position. All electrical and mechanical parts are easily accessible in this position. Mechanical spring-charge and contactposition indicators are visible through the closed door. Local mechanical ON/OFF pushbuttons are actived through the door as well. For complete remote control, the circuitbreaker carriage can be equipped for motor operation.



Cable and bar connections

Fig. 7: Cross-section through 8BK20 cubicle

Low-voltage compartment

Busbars and primary disconnectors

All protective relays, monitoring and control devices of a feeder can be accommodated in a metal-enclosed LV compartment on top of the HV enclosure. Device-mounting plates, cabling troughs, and the central LV terminal strip(s) are located behind a separate lockable door. Full or partial plexiglass windows, or mimic diagrams are available for these doors.

Rectangular busbars drawn from pure copper are used exclusively. They are mounted on ribbed, cast-resin post insulators which are sized to take up the dynamic forces resulting from short circuits. Soliddielectric busbar insulation is available. The movable parts of the line and loadside primary disconnectors have flat, spring-loaded and silver-plated hemispherical pressure contacts for low contact resistance and good ventilation. The parallel connecting arms are designed to increase contact pressure during short circuits. The fixed contacts are silver-plated stubs within the circuit-breaker bushings or the busbar mountings.

Main enclosure The totally enclosed and sealed cubicle permits installation in most equipment rooms. With the optional dust protection, the switchgear is safeguarded against internal contamination, small animals and rodents, and naturally against contact with live parts. This eliminates the usual reasons for arc faults. Should arcing occur, nevertheless, the arc can be guided towards the end of the lineup, where damage is repaired most easily. For the latter reason, parititions between individual cubicles of the same bus sections are normally not used.

Cables and bars are connected from below; entrance from above requires an auxiliary structure behind the cubicle. Single-phase or three-phase solid-dielectric cables can be connected from the front or the rear of the cubicle (specify); stress cones are installed conveniently inside the cubicle. Make-proof grounding switches with manual operation can be installed below the CTs, engaging contacts behind the cable lugs. Operation of the fully interlocked grounding switch is possible only with the breaker carriage in the ”Disconnected/ Test“ position.

1

Interlocking system

4

A series of sturdy mechanical interlocks forces the operator into the only safe operating sequence of the switchgear, preventing positively the following: ■ Moving the carriage with the breaker closed. ■ Switching the breaker in any but the locked ”Connected“ or ”Disconnected/ Test“ position ■ Engaging the grounding switch with the carriage in the ”Connected“ position, and moving the carriage into this position with the grounding switch engaged.

2

3

5

6

Degrees of protection Standard degree of protection IP 3XD according to IEC 60529. Optionally, the cubicles can be protected against harmful internal deposits of dust and against dripping water (IP 51), available only for cubicles without ventilation slots.

7

8

9

Instrument transformers Up to three multicore block-type current transformers plus three single-phase potential transformers can be installed in the lower compartment, PTs optionally on withdrawable modules. The CTs carry the cable-connecting bars and lugs, and the fixed contacts of the (optional) grounding switch. All common burden and accuracy ratings of instrument transformers are available. Busbar metering PTs with their current-limiting fuses are installed on withdrawable carriages, identically to breaker carriages.


10

3/9


Installation

1

2

3

4

The switchboards are shipped in sections of up to three cubicles on stable wooden pallets which are suitable for rolling and forklift handling. These sections are bolted or spot-welded to channel iron sections embedded in a flat and level concrete floor. Front-connected types can be installed against the wall or free-standing; rear-connected cubicles require service aisles. Double-busbar installations in back-to-back configuration are installed free-standing. Cable feed-in is through corresponding cut-outs in the floor, plans for which are part of the switchgear supply. Three-phase (armored) cables for voltages above 12 kV require sufficient clearance below the switchgear to split up the phases (cablefloor, etc.). Circuit-breakers are shipped mounted on their carriages inside the switchgear cubicles. For dimensions and weights, see Fig. 9.

5

Fig. 8: Cross-section through switchgear type 8BK20 in back-to-back double-busbar arrangement for rated voltages up to 24 kV

Weights and dimensions

6

7

8

Rated voltage

[kV]

7.2

12

15

17.5

24

Panel spacing

[mm]

800

800

800

1000

1000

Width

[mm]

2050

2050

2050

2250

2250

Depth front conn. without channel with channel

[mm] [mm]

1650 1775

1650 1775

1650 1775

2025 2150

2025 2150

Depth rear conn.

[mm]

1775

1775

1775

2150

2150

Approx. weight incl. breaker

[kg]

800

800

800

1000

1000

Fig. 9

9

10

3/10



1

Technical data Rated lightning impulse voltage

Rated shorttime power frequency voltage

Rated shortcircuit-breaking current/shorttime current (1 or 3 s available)

Rated shortcircuit making current

[kV]

[kV]

[kV]

[kA] (rms)

[kA]

7.2

60

20

31.5 40* 50*

80 110 125

– – –

■ ■ ■

■ ■ –

■ ■ ■

– ■ ■

– ■ ■

■ ■ ■

■ ■ ■

■ ■ ■

■ ■ ■

■ ■ ■

12

75

28

31.5 40* 50*

80 110 125

– – –

■ ■ ■

■ ■ –

■ ■ ■

– ■ ■

– ■ ■

■ ■ ■

■ ■ ■

■ ■ ■

■ ■ ■

■ ■ ■

15

95

36

31.5 40* 50*

80 110 125

– – –

■ ■ ■

■ ■ –

■ ■ ■

– ■ ■

– ■ ■

■ ■ ■

■ ■ ■

■ ■ ■

■ ■ ■

■ ■ ■

5

17.5

95

38

16 20 25

40 50 63

■ ■ ■

■ ■ ■

– – ■

– – –

– – –

– – –

■ ■ ■

■ ■ ■

■ ■ ■

– – –

– – –

6

125

50

16 20 25

40 50 63

■ ■ –

■ ■ ■

– ■ ■

– – –

– – –

– – –

■ ■ ■

■ ■ ■

■ ■ ■

– – –

– – –

Rated voltage

24

Rated normal feeder current*

Rated normal busbar current

2 630 1250 2000 2500 3150 4000 1) [A] [A] [A] [A] [A] [A]

1250 2000 2500 3150 4000 [A] [A] [A] [A] [A]

3

4

7

*1s 1) Ventilation unit with or without fan and ventilation slots in the front of the cubicle required.

8

Fig. 10

9

10


3/11


1

8BK20 switchgear up to 24 kV Panel Fixed parts

2

Withdrawableparts

Busbar modules

Sectionalizer

Bus riser panel

Metering Busbar connecpanel tion panel

3

4

5

6

Fig. 11: Available circuit options

7

8

9

10

3/12



Vacuum contactor motor starters 8BK30, air-insulated

1

From 3.6–12 kV Single-busbar Type-tested Metal-enclosed Metal-clad Withdrawable vacuum contactors and HRC current-limiting fuses ■ For direct lineup with 8BK20 switchgear ■ For indoor installation ■ ■ ■ ■ ■ ■

2

3

Specific features

4

■ Designed as extension to 8BK20 switch■ ■ ■ ■

gear with identical cross section Contactor mounted on horizontally moving truck – 400 mm panel spacing Cable connection from front or rear Central or individual control power transformer Integrally-mounted electronic multifunction motor-protection relays available.

5

6

Safety of operating and maintenance personnel ■ All switching operations behind closed

doors ■ Positive and robust mechanical inter-

7

locks ■ Arc-fault-tested metal enclosure ■ Complete protection against contact

with live parts ■ Absolutely safe fuse replacement ■ Maintenance-free vacuum interrupter

8

tubes Tolerance to environment ■ Metal enclosure with optional gaskets ■ Complete corrosion protection and tropi-

calization of all parts ■ Vacuum-potted ribbed expoy insulators with high tracking resistance

Fig. 12: Metal-clad switchgear type 8BK30 with vacuum contactor (inter-cubicle partition removed)

9

Technical data Rated voltage

BIL

PFWV

Maximum rating of motor

Feeder rating

Rated busbar current

10

[kV]

[kV]

[kV]

[kW]

[A]

1250 [A]

3.6 7.2 12

40 60 60

10 20 28

1000 2000 3000

400 400 400

■ ■ ■

2000 [A]

2500 [A]

3150 [A]

4000 [A]

■ ■ ■

■ ■ ■

■ ■ ■

■ ■ ■

Fig. 13


3/13


1

Full-voltage nonreversing (FVNR)

Reduced-voltage nonreversing (RVNR) with starter (reactor starting)

Reduced-voltage nonreversing (RVNR) with external reactor autotransformer ”Korndorffer Method“

2

3

4

5

Fig. 14: Available circuits

6

7

8

9

General description

The stationary part

Busbars and primary disconnectors

8BK30 motor starters consist of metalenclosed, air-insulated and metal-clad cubicles. Vacuum contactors on withdrawable trucks, with or without control power transformers, are used in conjunction with current-limiting fuses as starter devices. The truck is fully interlocked with the structure and is manually moved from the ”Connected“ to the ”Disconnected/Test“ position. A fully isolated low-voltage compartment is integrated. All commonly used starter circuits and auxiliary devices are available. The starter cubicles and contactors are factory-assembled and type-tested as per applicable standards.

The cubicle is constructed basically the same as the matching switchgear cubicles 8BK20, with the exception of the contactor truck.

Horizontal busbars are identical to the ones in the associated 8BK20 switchgear. Primary disconnectors are adapted to the low feeder fault currents of these starters. Silver-plated tulip contacts with round contact rods are used.

10

Contactor truck Vacuum contactor, HRC fuses, and control power transformer with fuses (if ordered) are mounted on the withdrawable truck. Auxiliary devices and interlocking components, plus the primary disconnects complete the assembly. Low-voltage compartment Space is provided for regular bimetallic or electronic motor-protection relays, plus the usual auxiliary relays for starter control. The compartment is metal-enclosed and has its own lockable door. All customer wiring is terminated on a central terminal strip within this compartment.

CTs and cable connection Due to the limited let-through current of the HRC fuse, block-type CTs with lower thermal rating can be used. Depending on the protection scheme used, CTs with one or two secondary windings are installed. All commonly used feeder cables up to 300 mm2 can be terminated and connected at the lower CT terminals. Grounding switches or surge-voltage limiters are installed optionally below the current transformers.

Main enclosure Practically identical to the associated 8BK20 switchgear.

3/14



Interlocking system Contactor, truck and low-voltage plugs are integrated into the interlocking system to assure the following safeguards: ■ The truck cannot be moved into the ”Connected“ position before the LV plug is inserted. ■ The LV plug cannot be disconnected with the truck in the ”Connected“ position. ■ The truck cannot be moved with the contactor in the ON position. ■ The contactor cannot be operated with the truck in any other but the locked ”Connected“ or ”Disconnected/Test“ position. ■ The truck cannot be brought into the ”Connected“ position with the grounding switch engaged. ■ The grounding switch cannot be engaged with the truck in the ”Connected“ position.

1

2

3

4

5

Degrees of protection Standard degree of protection IP 3XD according to IEC 60529. Optionally, the starters can be protected against harmful internal deposits of dust and against dripping water in the ”Operating“ position (IP 51).

6 Fig. 15: Cross-section through switchgear type 8BK30

Installation Identical to the procedures outlined for 8BK20 switchgear. Only the HRC fuses are shipped outside the enclosure, separately packed.

7

Weights and dimensions Rated voltage

[kV]

Width

3.6

7.2

12

[mm]

2 x 400

2 x 400

2 x 400

Height

[mm]

2050

2050

2050

Depth

[mm]

1650

1650

1650

Approx. weight incl. contactor

[kg]

700

700

700

8

9

Fig. 16

10


3/15


1

Metal-clad switchgear 8BK40, air-insulated ■ From 7.2 to 17.5 kV ■ Single and double-busbar

2

3

■ ■ ■ ■ ■ ■

(back-to-back or face-to-face) Air-insulated Type-tested Metal-enclosed Metal-clad Withdrawable vacuum breaker For indoor installation

Specific features ■ General-purpose switchgear for rated

4

5

feeder/busbar current up to 5000 A and short-circuit breaking current up to 63 kA ■ Circuit-breaker mounted on horizontally moving truck ■ Cable connections from front Safety of operating and maintenance personnel ■ All switching operations behind closed

6

■ ■

7

■ ■

doors Positive and robust mechanical interlocks Complete protection against contact with live parts Line test with breaker inserted (option) Maintenance-free vacuum circuitbreaker

Fig. 17: Metal-clad switchgear type 8BK40 with vacuum circuit-breaker 3AH (inter-cubicle partition removed)

Tolerance to environment

8

■ Sealed metal enclosure with optional

gaskets ■ Complete corrosion protection and tropi-

calization of all parts ■ Vacuum-potted ribbed epoxy-insulators

9

with high tracking resistance Generator vacuum circuit-breaker panel ■ Suitable for use in steam, gas-turbine,

hydro and pumped-storage power plants

10

■ Suitable for use in horizontal, L-shaped

or vertical generator lead routing

Fig. 18: Cross-section through type 8BK40 generator panel

3/16



General description 8BK40 switchboards consist of metal-clad cubicles of air-insulated switchgear with withdrawable vacuum circuit-breakers. The breaker truck is fully interlocked with the interrupter and the stationary cubicle. It is manually moved in a horizontal direction from the ”Connected“ position behind the closed front door and without the use of auxiliary equipment. A fully isolated lowvoltage compartment is integrated. All commonly used feeder circuits and auxiliary devices are available. The switchgear cubicles and interrupters are factory-assembled and type-tested as per applicable standards.

1

Stationary part

4

The cubicle is built as a self-supporting structure, bolted together from rolled galvanized steel sheets and profile sections. Cubicles for rated voltages up to 17.5 kV are of identical construction. Each cubicle is divided into three sealed and isolated compartments by partitions, i.e. the busbar, cable connection and circuit-breaker compartment. The fixed contacts of the primary disconnectors are located within insulating breaker bushings, effectively maintaining the compartmentalization in all operating states of the switchgear. The bushings are covered by automatic steel safety shutters upon removal of the circuit-breaker element from the ”Connected“ position. Each compartment in every model has its own pressure-relief device. To reduce internal arcing times and thus consequential damage, pressure-switches can be installed that trip the incoming-feeder circuit-breaker(s) in less than 100 msec. This is an economic alternative to busbar differential protection. Interrupter truck The truck normally supports a vacuum circuit-breaker with the associated operating mechanism and auxiliary devices. By manually moving the truck with the spindle drive it can be brought into a distinct ”Connected“ and ”Disconnected/ Test“ position. To this effect, the front door remains closed. Inspection can easily and safely be carried out with the circuit-breaker in the ”Disconnected/Test“ position. All electrical and mechanical parts are easily accessible in this position. Mechanical spring-charge and contact-posi-

2

3

5

Fig. 19: Cross-section through panel type 8BK40

tion indicators are visible through the closed door. Local mechanical ON/OFF pushbuttons are actived through the door as well. For complete remote control, the circuitbreaker carriage can be equipped for motor operation. Low-voltage compartment All protective relays, monitoring and control devices of a feeder can be accommodated in a metal-enclosed LV compartment on top of the HV enclosure. Device-mounting plates, cabling troughs, and the central LV terminal strip(s) are located behind a separate lockable door. Full or partial plexiglass windows, or mimic diagrams are available for these doors. Main enclosure The totally enclosed and sealed cubicle permits installation in most equipment rooms. With the optional dust protection, the switchgear is safeguarded against internal contamination, small animals and rodents, and naturally against contact with live parts. This eliminates the usual reasons for arc faults. Should arcing occur, nevertheless, the arc can be guided


6 towards the end of the lineup, where damage is repaired most easily. For the latter reason, partitions between individual cubicles of the same bus sections are normally not used.

7

Busbars and primary disconnectors Rectangular busbars drawn from pure copper are used exclusively. They are mounted on ribbed, cast-resin post insulators which are sized to take up the dynamic forces resulting from short circuits. The movable parts of the line and loadside primary disconnectors have flat, spring-loaded and silver-plated hemispherical pressure contacts for low contact resistance and good ventilation. The parallel connecting arms are designed to increase contact pressure during short circuits. The fixed contacts are silver-plated stubs within the circuit-breaker bushings. Instrument transformers Up to three multicore block-type current transformers plus three single-phase potential transformers can be installed in the lower compartment, PTs optionally on withdrawable modules.

3/17

8

9

10


1

2

The CTs carry the cable-connecting bars and lugs, and the fixed contacts of the (optional) grounding switch. All common burden and accuracy ratings of instrument transformers are available. Busbar metering PTs with their current-limiting fuses are installed on a withdrawable truck, identical to the breaker truck. Cable and bar connections

3

4

5

Cables and bars are connected from below; entrance from above requires an auxiliary structure behind the cubicle. Single-phase or three-phase solid-dielectric cables can be connected from the front of the cubicle; stress cones are installed conveniently inside the cubicle. Regular and make-proof grounding switches with manual operation can be installed below the CTs, engaging contacts behind the cable lugs. Operation of the fully interlocked grounding switch is possible only with the breaker carriage in the ”Disconnected/Test“ position.

Weight and dimensions 7.2

12

15

17.5

[mm]

1100

1100

1100

1100

Height

[mm]

2500

2500

2500

2500

Depth

[mm]

2300

2300

2300

2300

Approx. weight incl. breaker

[kg]

2800

2800

2800

2800

Rated voltage

[kV]

Width

Fig. 20


Rated lightningimpulse voltage

Rated short-time powerfrequency voltage

Rated shortcircuitbreaking current/ short time current

Rated shortcircuitmaking current

[kV]

[kV]

kA [rms]

[kA]

7.2

60

20

50 63

125 160

12

75

28

50 63

125 160

15

95

36

50 63

125 160

17.5

95

38

50 63

125 160

Interlocking system

6

7

8

A series of sturdy mechanical interlocks forces the operator into the only safe operating sequence of the switchgear, preventing positively the following: ■ Moving the truck with the breaker closed. ■ Switching the breaker in any but the locked ”Connected“ or ”Disconnected/ Test“ position. ■ Engaging the grounding switch with the truck in the ”Connected“ position, and moving the truck into this position with the grounding switch engaged.

[kV]

Rated normal feeder current

1250 2500 3150 5000 [A] [A] [A] [A]

Rated normal busbar current

5000 [A]

Degrees of protection

9

10

Degree of protection IP 4X: In the ”Connected“ and the ”Disconnected/Test“ position of the truck, the switchgear is totally protected against contact with live parts by objects larger than 2 mm in diameter. Optionally, the cubicles can be protected against harmful internal deposits of dust and against drip water (IP 51). Installation The switchboards are shipped in sections of one cubicle on stable wooden pallets which are suitable for rolling and forklift handling. These sections are bolted or spot-welded to channel iron sections embedded in a flat and level concrete floor.

3/18

Fig. 21

Front-connected types can be installed against the wall or free-standing. Doublebusbar installations in back-to-back configuration are installed free-standing. Cable feed-in is through corresponding cutouts in the floor; plans for which are part of the switchgear scope of supply. Threephase (armored) cables for voltages above 12 kV require sufficient clearance below the switchgear to split up the phases (cable floor, etc.). Circuit-breakers are shipped mounted on their trucks inside the switchgear cubicles. For preliminary dimensions and weights, see Fig. 20.



1

8BK40 switchgear up to 17.5 kV

Panel Fixed parts

Withdraw- Metering Busbar modules ableparts panel

Sectionalizer

2

Bus riser panel

3

4

5

6 8BK40 generator vacuum CB panel

7 Variants

Additional parts

Optional parts

8

9

10

Fig. 22: Available circuit options for switchgear/generator panel type 8BK40


3/19

Air-Insulated Switchgear Type NXAIR

1

Renewed availability

Metal-clad or cubicle type switchgear NXAIR, air-insulated

■ Internal fault withstand capability satis-

fied according to standards ■ Separate pressure relief for every com-

partment

■ From 3.6 to 24 kV ■ Single- and double-busbar (back to back

2

3

■ Standard direction of pressure relief

upwards

or face-to-face) Air-insulated Metal-enclosed Metal-clad or cubicle type Modular construction of individual panels Supplied as standard with bushingtype transformers for selective tripping of feeders without any additional measures. ■ Vacuum circuit-breaker module type NXACT

■ Busbar fittings (e.g. voltage transform-

■ ■ ■ ■ ■

■

■ ■

4

■

Specific features ■ General-purpose switchgear ■ Circuit-breaker mounted on horizontal

5

■

slide or truck behind front door ■ Cable connections from front or rear ■

Safety of operating and maintenance personnel

6

doors ■ Switchgear modules with intgrated inter■

7

■ ■

8

■

■ All switching operations behind closed

ers, current transformers in run of busbar or make-proof earthing switches) arranged in separate compartments above busbar compartments Pressure-resistant additional compartments with pressure-proof barrier to busbar compartment Pressure-resistant floor covering Control cables inside panels arranged in metallic cable ducts Cable testing without isolation of busbar assured by separately opening shutters of module compartment Easy replacement of compartments by virtue of self-supporting, modular and bolted construction Replacement of module compartments and/or connection compartments possible without having to isolate busbar Bushing-type transformers for selective disconnection of feeders

■ ■

9

10

■

locking and control board Panels tested for internal arcs to IEC 60 298, App. AA Complete protection against contact with live parts Mechanical switch position indication on panel front for switching device, disconnector and earthing switch Earthing of feeders by means of makeproof earthing switches. Operation of all switching, disconnecting and earthing functions from panel front – Unambiguous assignment of actuating openings and control elements to mechanical switch position indications – Mechanical switch position indications integrated in mimic diagram – Convenient height of actuating openings, control elements and mechanical switch position indications on highvoltage door, as well as low-voltage unit in door of low-voltage compartment. – Logical interlocks prevent maloperation Option: verification of dead state with high-voltage door closed, by means of a voltage detection system according to IEC 61 243-5

3/20

Fig. 23: Metal-clad switchgear type NXAIR

Standards ■ The switchgear cubicles and interrupters

are factory assembled and type-tested according to VDE 0670 Part 6 and IEC 60 298.

Flexibility ■ Wall mounting or free-standing arrange-

ment ■ Cable connection from front or rear ■ Connection of all familiar types of cables ■ Available in truck-type or withdrawable

construction ■ Optional left or right-hand arrangement

■ ■ ■

■

of hinges – of high-voltage doors – of doors of low-voltage compartments Extension of existing switchgear at both ends without modification of panels Easy replacement of bushing-type transformers from front Screw-type mating contacts on bushingtype transformers can be easily replaced from front (from module compartment). Reconnection of current transformers on secondary side

Degrees of protection Standard degree of protection IP3XD according to IEC 60 529 Optionally, the cubicles can be protected against harmful internal deposits of dust and against dripping water (IP 51), available only for cubicles without ventilation slots.



NXAIR is of modular construction. The main components are: A Module compartment B Busbar compartment C Connection compartment D NXACT vacuum circuit-breaker module E Low-voltage compartment Module compartment Basic features ■ Housings are of sendzimir-galvanized ■ ■

■ ■ ■ ■ ■

sheet-steel High-voltage door and front frame with additional epoxy resin powder coating Module compartment to accomodate necessary components (vacuum circuitbreaker module, vacuum contactor module, disconnector module, metering module and transformer feeder module) for implementing various panel versions With shutter operating mechanism High-voltage door pressure-proof in event of internal arcs in panel Metallic cable ducts on side for laying control cables (internal and external) Option: test sockets for capactive voltage detection system Low-voltage plug connectors for connection of switchgear modules to auxiliary voltage circuits.

NXACT vacuum circuit-breaker module Features ■ Integrated mechanical interlocks be-

tween operating mechanisms ■ Integrated mechanical switch position

indications for circuit-breaker, withdrawable part and earthing switch functions ■ Easy movement since only withdrawable part is moved ■ Permanent interlock of carriage mechanism of switchgear module in panel Low-voltage compartment

1

E

B

2

1 2 3 4 5 6

A

3

9

4

10 D

5

12

6 7

11

7 8 9 10 11

C

8

13 14

12 13 14

Pressure relief duct Busbars Bushing-type insulator Bushing-type transformer Make-proof earthing switch Cable connection for 2 cables per phase Cables Cable brackets Withdrawable part Vacuum interrupters Combined operating and interlocking unit for circuitbreaker, disconnector and earthing switch Contact system Earthing busbar Option: truck

1

2

3

4

Fig. 24: Cross-section through cubicle type NXAIR

Solid-state HMI (human-machine interface) Bay controller SIPROTEC 4 type 7SJ62 for control and protection (Fig.25)

5 Door of low-voltage compartment

6

Features 1 LCD for process and equipment data, e.g. for: – Measuring and metering values – Binary data for status of switchpanel and device – Protection data – General signals – Alarm 2 Keys for navigation in menus and for entering values 3 Seven programmable LEDs with possible application-related inscriptions, for indicating any desired process and equipment data 4 Four programmable function keys for frequently performed actions.

7

8

9

1 2

■ Accommodates equipment for protec-

■ ■

■ ■

tion, control, measuring and metering, e.g. bay controller SIPROTEC 4 type 7SJ62 Shock-protected from high-voltage section by barriers Low-voltage compartment can be removed; ring and control cables are plugged in Option: low-voltage compartment of increased height (980 mm) possible Option: partition wall between panels.

3

10

4

Bay controller SIPROTEC 4 type 7SJ62 Fig. 25: Bay controller


3/21


1

2

3

4

5

6


[kV]

12

15

17.5

24

Rated short-time power-frequency voltage

[kV]

28 1)

36

38

50

Rated lightning impulse voltage

[kV]

75

95

95

125

Rated short-circuit breaking current max. [kA]

31.5

31.5

25

25


31.5

31.5

25

25

80

80

63

63

max. [kA]

Rated short-circuit making current max. [kA] Rated normal current of busbar

max. [A]

2500

2500

2500

2500

Rated normal current of feeder

max. [A]

2500

2500

2500

2500

Rated normal current of transformer feeder panels with HV HRC fuses 2)

Depends on rated current of fuse used

1) 42 kV on request 2) At 7.2 kV: max. rated current 250 A at 12 kV: max rated current 150 A at 15/17.5/24 kV: max. rated current 100 A

7

Fig. 26


8

9

Width

[mm]

800

800

800

800*) / 1000

Height

[mm]

2000

2300

2300

2300

Height with high LV compartment

[mm]

2350

2650

2650

2650

Depth

[mm]

1350

1550

1550

1550

Weight (approx.)

[kg]

600

*) up to 1250 A rated normal current of feeder

10

Fig. 27

3/22



Incoming and outgoing feeder panel with circuitbreaker module

Outgoing feeder panel with disconnector module

Metering panel with metering module

Transformer feeder panel with transformer feeder module and fuses

1

2

3

4 Switch disconnector panel

Sectionalizer panel of the bus sectionalizer

Bus riser panel of the bus sectionalizer

Spur panel with circuit-breaker module

5

6

7 Feeder panel with busbar current metering

Feeder panel with busbar earthing switch

Feeder panel with busbar connection

Feeder panel with busbar voltage metering

(optional)*

(optional)*

(optional)*

(optional)*

8

9

10

Components shown with dashes are optional * Not for feeder panels with open-circuit ventilation, busbar current metering up to 12 kV, 25 kA Fig. 28: Available circuit options


3/23

SF6-Insulated Switchgear Type 8DC11

1

2

Gas-insulated switchgear type 8DC11 ■ ■ ■ ■ ■ ■

3

■ ■ ■

4 ■

From 3.6 up to 24 kV Triple-pole primary enclosure SF6-insulated Vacuum circuit-breakers, fixed-mounted Hermetically-sealed, welded, stainlesssteel switchgear enclosure Three-position disconnector as busbar disconnector and feeder earthing switch Make-proof grounding with vacuum circuit breaker Width 600 mm for all versions up to 24 kV Plug-in, single-pole, solid-insulated busbars with outer conductive coating Cable termination with external cone connection system to EN 50181

Operator safety

5

■ Safe-to-touch and hermetically-sealed

primary enclosure ■ All high-voltage parts, including the cable

6

■ ■

7 ■

8

■ ■

sealing ends, busbars and voltage transformers are surrounded by grounded layers or metal enclosures Capacitive voltage indication for checking for ”dead“ state Operating mechanisms and auxiliary switches safely accessible outside the primary enclosure (switchgear enclosure) Type-tested enclosure and interrogation interlocking provide high degree of internal arcing protection Arc-fault-tested acc. to IEC 60 298 No need to interfere with the SF6-insulation

Fig. 29: Gas-insulated swichgear with vacuum circuit-breakers

Operational reliability

9

■ Hermetically-sealed primary enclosure

■

10 ■

■

■

for protection against environmental effects (dirt, moisture, insects and rodents). Degree of protection IP65 Operating mechanism components maintenance-free in indoor environment (DIN VDE 0670 Part 1000) Breaker-operating mechanisms accessible outside the enclosure (primary enclosure) Inductive voltage transformer metalenclosed for plug-in mounting outside the main circuit Toroidal-core current transformers located outside the primary enclosure, i.e. free of dielectric stress

3/24

■ Complete switchgear interlocking with ■ ■ ■ ■

mechanical interrogation interlocks Welded switchgear enclosure, permanently sealed Minimum fire contribution Installation independent of attitude for feeders without HRC fuses Corrosion protection for all climates

General description

The 8DC11 is the result of the economical combination of SF6-insulation and vacuum technology. The insulating gas SF6 is used for internal insulation only; circuit interruption takes place in standard vacuum breaker bottles. The safety for the personnel and the environment is maximized. The 8DC11 is completely maintenance-free. The welded gas-tight enclosure of the primary part assures an endurance of 30 years without any work on the gas system.

Due to the excellent experience with vacuum circuit breaker gas-insulated switchgear, there is a worldwide rapidly increasing demand of this kind of switchgear even in the so-called low-range field.



1. Modular design and compact dimensions The 8DC switchboards consist of: ■ The maintenance-free SF6-gas-insulated switching module is three-phase encapsulated and contains the vacuum circuitbreaker and 3 position selector switch (ON/OFF/READY TO EARTH) ■ Parts for which single-phase encapsulation is essential are safe to touch, easily accessible and not located in the switching module, e.g. current and potential transformers ■ The busbars are even single-phase encapsulated, i.e. they are insulated by silicone rubber with an outer grounded coating. The pluggable design assures a high degree of flexibility and makes also the installation of busbar CTs and PTs simple.

1

1 Low-voltage compartment

1

2 Busbar voltage transformer 3 Busbar current transformer 2

4 Busbar

2

5 SF6-filled enclosure 3 4

6 Three-position switch 7 Three-position switch

5

3

operating mechanism

8 Circuit-breaker operating mechanism

6

7

9 Circuit-breaker

4

(Vacuum interrupter)

10 Current transformers

8 2. Factory-assembled well-proven tested components

9

Switchgear based on well-proven components. The 8DC switchgear design is based on assembling methods and components which have been used for years in our SF6insulated Ring Main Units (RMUs). For example, the stainless-steel switchgear enclosure is hermetically-sealed by welding without any gaskets. Bushings for the busbar, cable and PT connection are welded in this enclosure, as well as the rupture disc, which is installed for pressure relief in the unlikely event of an internal fault. Siemens has had experience with this technique since 1982; 50,000 RMUs are running trouble-free. Cable plugs with the so-called outer-cone system have been on the market for many years. The gas pressure monitoring system is neither affected by temperature fluctuations nor by pressure fluctuations and shows clearly whether the switchpanel is ”ready for service“ or not. The monitor is magnetically coupled to an internal gas-pressure reference cell; mechanical penetration through the housing is not required. A design safe and reliable and, of course, wellproven in our RMUs. The vacuum circuit-breaker, i.e. the vacuum interrupters and the operating mechanism, is also used in our standard switchboards. The driving force for the primary contacts of the vacuum interrupters is transferred via metal bellows into the SF6gas-filled enclosure. A technology that has been successfully in operation in more than 100,000 vacuum interrupters over 20 years.

10

12 PT disconnector

12

13 Voltage transformers

11 Double cable connection with T-plugs

11

5

14 Cable

6

15 Pressure relief duct 13

7 14 15

8

Fig. 30: Cross section through switchgear type 8DC11

2

5

3

9 1 ”Ready for service“ indicator 2 Pressure cell 1

3 Red indicator: Not ready

10

4 Green indicator: Ready 5 Magnetic coupling Stainless-steel enclosure filled with SF6 gas at 0.5 bar (gauge) at 20 °C

4

Fig. 31: Principle of gas monitoring (with ”Ready for service“ indicator)


3/25


1

2

3

4

5

6

7

8

3. Current and potential transformers as per user’s application

4. No gas work at site and simplified installation

A step forward in switchgear design without any restriction to the existing system! New switchgear developments are sometimes overdesigned with the need for highly sophisticated secondary monitoring and protection equipment, because currentand potential-measuring devices are used with limited rated outputs. The result: Limited application in distribution systems due to interface problems with existing devices; difficult operation and resetting of parameters. The Siemens 8DC switchgear has no restrictions. Current and potential transformers with conventional characteristics are available for all kinds of protection requirements. They are always fitted outside the SF6-gas-filled container in areas of singlepole accessibility, the safe-to-touch design of both makes any kind of setting and testing under all service conditions easy. Current transformers can be installed in the cable connection compartment at the bushings and, if required additionally, at the cables (inside the cable connection compartment). Busbar CTs for measuring and protection can be placed around the silicone-rubber-insulated busbars in any panel. Potential transformers are of the metalclad pluggable design. Busbar PTs are designed for repeated tests with 80% of the rated power-frequency withstand voltage, cable PTs can be isolated from the live parts by means of a disconnection device which is part of the SF6-gas-filled switching module. This allows high-voltage testing of the switchboard with AC and the cable with DC without having to remove the PTs.

The demand for reliable, economical and maintenance-free switchgear is increasing more and more in all power supply systems. Industrial companies and power supply utilities are aware of the high investment and service costs needed to keep a reliable network running. Preventive maintenance must be carried out by trained and costly personnel. A modern switchgear design should not only reduce the investment costs, but also the service costs in the long run! The Siemens 8DC switchgear has been developed to fulfill those requirements. The modular concept with the maintenance-free units does not call for installation specialists and expensive testing and commissioning procedures. The switching module with the circuit-breaker and the three-position disconnector is sealed for life by gas-tight welding without any gaskets. All other high-voltage components are connected by means of plugs, a technology well-known from cable plugs with long- lasting service and proven experience. All cables will be connected by cable plugs with external cone connection system. In the case of XLPE cables, several manufacturers even offer cable plugs with an outer conductive coating (also standard for the busbars). Paper-insulated mass-impregnated cables can be connected as well by Raychem heat-shrinkable sealing ends and adapters. The pluggable busbars and PTs do not require work on the SF6 system at site. Installation costs are considerably reduced (all components are pluggable) because, contrary to standard GIS, even the site

9

HV tests can be omitted. Factory-tested quality is ensured thanks to simplified installation without any final adjustments or difficult assembly work. 5. Minimum space and maintenancefree, cost-saving factors Panel dimensions reduced, cable-connection compartment enlarged! The panel width of 600 mm and the depth of 1225 mm are just half of the truth. More important is the maximized size of the 8DC switchgear cable-connection compartment. The access is from the switchgear front and the gap from the cable terminal to the switchgear floor amounts to 740 mm. There is no need for any aisle behind the switchgear lineup and a cable cellar is superfluous. A cable trench saves civil engineering costs and is fully sufficient with compact dimensions, such as width 500 mm and depth 600 mm. Consequently, the costs for the plot of land and civil work are reduced. Even more, a substation can be located closer to the consumer which can also solve cable routing problems. Busbar Features ■ Single-pole, plug-in version ■ Made of round-bar copper, silicon-

insulated ■ Busbar connection with cross pieces

and end pieces, silicon-insulated ■ Field control with the aid of electro-

■ ■ ■ ■

conductive layers on the silicon-rubber insulation (both inside and outside) External layers earthed with the switchgear enclosure to permit access Insensitive to dirt and condensation Shock-hazard protected in form of metal covering Switchgear can be extended or panels replaced without affecting the SF6 gas enclosures.

10

Fig. 32: Plug-in busbar (front view with removed low-voltage panel)

3/26



1

2

3 Fig. 33: Vacuum circuit-breaker (open on operating-mechanism side)

4 4 5

6

7

8

2

9 3

1 Primary part SF6-insulated, with vacuum interrupter 2 Part of switchgear enclosure 3 Operating-mechanism box (open) 4 Fixed contact element 5 Pole support 6 Vacuum interrupter 7 Movable contact element 8 Metal bellows 9 Operating mechanism

1

5

6

Fig. 34: Vacuum circuit-breaker (sectional view)

Circuit-breaker panel

Disconnector panel

7 Switch-disconnector panel with fuses

Busbar section

Metering

8

1)

9

10

Basic versions Vacuum circuit-breaker panel and three-position disconnector

Disconnector panel with three-position disconnector

Switch-disconnector panel with three-position switch disconnector and HV HCR fuses

Optional equipment indicated by means of broken lines can be installed/omitted in part or whole.

Busbar section with 2 three-position disconnectors and vacuum circuit-breaker in one panel

Switch-disconnector panel with three-position switch disconnector and HV HCR fuses

1) Current transformer: electrically, this is assigned to the switchpanel, its actual physical location, however, is on the adjacent panel.

Fig. 35: Switchpanel versions


3/27


1


Technical data

[kV]

Rated voltage

2

3

4

5

7.2

15

17.5

24


[kV]

20

28

36

38

50


[kV]

60

75

95

95

125

Rated short-circuit breaking current Rated short-time current, 3 s

Width

[mm]

600

Height

[mm]

2250

Depth

single-busbar [mm] double-busbar [mm]

1225 2370

Weight single-busbar [kg] (approx.) double-busbar [kg]

max. [kA]

25

[kA]

63

63

63

63

63

Rated busbar current

[A]

1250

1250

1250

1250

1250

Rated feeder current

max. [A]

1250

1250

1250

1250

1250

25

25

25

25 Cable connection systems

Rated short-circuit making current

Features ■ 8DC11 switchgear for thermoplastic-

■ ■

100

80

63

63

50

■

Fig. 36: Technical data of switchgear type 8DC11 ■

7

8

9

10

■

Climate and ambient conditions

Internal arc test

The 8DC11 fixed-mounted circuit breaker is fully enclosed and entirely unaffected by ambient conditions. ■ All medium-voltage switching devices are enclosed in a stainless-steel housing, which is welded gas-tight and filled with SF6 gas ■ Live parts outside the switchgear enclosure are single-pole enclosed ■ There are no points at which leakage currents of high-voltage potentials are able to flow off to ground ■ All essential components of the operating mechanism are made of noncorroding materials ■ Ambient temperature range: –5 to +55°C.

Tests have been carried out with 8DC11 switchgear in order to verify its behavior under conditions of internal arcing. The resistance to internal arcing complies with the requirements of: ■ IEC 60 298 AA ■ DIN VDE 0670 Part 601, 9.84 These guidelines have been applied in accordance with PEHLA Guideline No. 4.

3/28

700 1200

Fig. 37

Rated current of switchdisconnector panels with fuses max. fuse [A]

6

12

Protection against electric shock and the ingress of water and solid foreign bodies

insulated cables with cross-sections up to 630 mm2 Standard cable termination height of 740 mm High connection point, simplifying assembly and cable-testing work Phase reversal simple, if necessary, due to symmetrical arrangement of cable sealing ends Cover panel of cable termination compartment earthed Nonconnected feeders: – Isolate – Ground – Secure against re-energizing (e.g. with padlock)

Types of cable termination Circuit-breaker and disconnector panels with cable T-plugs for bushings, with M16 terminal thread according to EN 50181 type C. Switch disconnector panels with elbow cable plugs for bushings, with plug-in connection according to EN 50181 type A.

The 8DC11 fixed-mounted circuit breaker offer the following degrees of protection in accordance with IEC 60 259: ■ IP3XD for external enclosure ■ IP65 for high-voltage components of switchpanels without HV HRC fuses



1 Low-voltage compartment 5 1

1

2 Operating mechanism 3 Cable connection 4 Current transformer

6 7 8

2

2

5 Panel link 6 Busbar 7 Gas compartment

3

8 Three-position switch 9 Voltage transformer

4 3 4

5 9

6

Fig. 38: Double busbar: Back-to-back arrangement (cross section)

7 Single cable

Double cable

Termination for surge arrester

Termination for switch disconnector panel

8

9

10

Fig. 39: Types of cable termination, outer cone system


3/29

SF6-Insulated Switchgear Type 8DA/8DB10

1

Gas-insulated switchgear type 8DA/8DB10 ■ Single-busbar: type 8DA

2

3

■ ■ ■ ■ ■ ■ ■

Double-busbar: type 8DB From 7.2 to 40.5 kV Single and double-busbar Gas-insulated Type-tested Metal-clad (encapsulated) Compartmented Fixed-mounted vacuum breaker

Specific features ■ Practically maintenance-free compact

4 ■ ■

5

6

■ ■

switchgear for the most severe service conditions Fixed-mounted maintenance-free vacuum breakers Only two moving parts and two dynamic seals in gas enclosure of each pole Feeder grounding via circuit-breaker Only 600 mm bay width and identical dimensions from 7.2 to 40.5 kV

Safety and reliability ■ Safe to touch – hermetically-sealed

grounded metal enclosure. ■ All HV and internal mechanism parts

maintenance-free for 20 years

7

■ Minor gas service only after 10 years ■ Arc-fault-tested ■ Single-phase encapsulation –

no phase-to-phase arcing ■ All switching operations from dead-front

8

freely and safely accessible tions available ■ Positive mechanical interlocking ■ External parts of instrument transform-

ers free of dielectric stresses.

10

The switchgear type 8DA10 represents the successful generation of gas-insulated medium-voltage switchgear with fixed-mounted, maintenance-free vacuum circuit-breakers. The insulating gas SF6 is used for internal insulation only; circuit interruption takes place in standard vacuum breaker bottles. 1. Encapsulation All high-voltage conductors and interrupter elements are enclosed in two identical cast-aluminum housings, which are arranged at 90° angles to each other. The aluminum alloy used is corrosion-free. The upper container carries the copper busbars with its associated vacuum-potted epoxy insulators, and the three-way selector switch for the feeder with the three positions ON/ISOLATED/GROUNDING SELECTED. The other housing contains the vacuum breaker interrupter. The two housings are sealed against each other, and against the cable connecting area by arc-proof and gas-tight epoxy bushings with O-ring seals. Busbar enclosure and breaker enclosures form separate gas compartments. The hermetical sealing of all HV components prevents contamination, moisture, and foreign objects of any kind – the leading cause of arcing faults – from entering the switchgear. This reduces the requirement for maintenance and the probability of a fault due to the above to practically zero. All moving parts and items requiring inspection and occasional lubrication are readily accessible.

operating panel ■ Live line test facility on panel front ■ Drive mechanism and CT secondaries ■ Fully insulated cable and busbar connec-

9

General description

Tolerance to environment ■ Hermetically-sealed enclosure protects

all high-voltage parts from the environment ■ Installation independent of altitude ■ Corrosion protection for all climates.

3/30

2. Insulation medium Sulfur-hexafluoride (SF6) gas is the prime insulation medium in this switchgear. Vacuum-potted cast-resin insulators and bushings supplement the gas and can withstand the operating voltage in the extremely unlikely case of a total gas loss in a compartment. The SF6 gas serves additionally as corrosion inhibiter by keeping oxygen away from the inner components. The guaranteed leakage rate of any gas compartment is less than 1% per year. Thus no scheduled replenishment of gas is required. Each compartment has its own gas supervision by contact-pressure gauges.

3. Three-position switch and circuitbreaker The required isolation of any feeder from the busbar, and its often desired grounding is provided by means of a sturdy, maintenance-free three-way switch arranged between the busbars and the vacuum breaker bottles. This switch is mechanically interlocked with the circuit breaker. The operations ”On/Isolated“ and ”Isolated/ Grounding selected“ are carried out by means of two different rotary levers. The grounding of the feeder is completed by closing the circuit-breaker. To facilitate replacement of a vacuum tube with the busbars live, the switch is located entirely within the busbar compartment. The vacuum circuit-breakers used are of the type 3AH described on pages 3/74 ff of this section. Mounted in the gas-insulated switchgear, the operating mechanism is placed at the switchgear front and the vacuum interrupters are located inside the gas filled enclosures. The number of operating cycles is 30,000. Since any switching arc that occurs is contained within the vacuum tube, contamination of the insulating gas is not possible. 4. Instrument transformers Toroidal-type current transformers with multiple secondary windings are arranged outside the metallic enclosure around the cable terminations. Thus there is no high potential exposed on these CTs and secondary connections are readily accessible. All commonly used burden and accuracy ratings are available. Bus metering and measuring are by inductive, gas-insulated potential transformers which are plugged into fully insulated and gas-tight bushings on top of the switchgear. 5. Feeder connections All commonly used solid-dielectric insulated single and three-phase cables can be connected conveniently to the breaker enclosures from below. Normally, fully insulated plug-in terminations are used. Also, fully insulated and gas-insulated busbar systems of the DURESCA/GAS LINK type can be used. The latter two termination methods maintain the fully insulated and safe-to-touch concept of the entire switchgear, rendering the terminations maintenance-free as well. In special cases, air-insulated conventional cable connection is available.



8DA10

1 1

1 2 3 4 5 6

2 3 4

6

7 8

7 8

9 10 11 12 13

9 10 11

Low-voltage cubicle Secondary equipment (SIPROTEC 4) Busbar Cast aluminum Disconnector Operating mechanism and interlocking device for three-position switch Three-position switch CB pole with upper and lower bushings CB operating mechanism Vacuum interrupter Connection Current transformer Rack

12

2

3

4

5

13

6

Fig. 40: Schematic cross-section for switchgear type 8DA10, single-busbar

8DB10

7 1 2 3 4 5

8

9 6 7 8

10

9 10 11 12 13

Fig. 41: Schematic cross-section for switchgear type 8DB10, double-busbar


3/31


6. Low-voltage cabinet

1

2

3

4

5

6

All feeder-related electronic protection devices, auxiliary relays, and measuring and indicating devices are installed in metal-enclosed low-voltage cabinets on top of each breaker bay. A central terminal strip of the lineup type is also located there for all LV customer wiring. PCB-type protection relays and individual-type protection devices are normally used, depending on the number of protective functions required.

2250

7. Interlocking system The circuit-breaker is fully interlocked with the isolator/grounding switch by means of solid mechanical linkages. It is impossible to operate the isolator with the breaker closed, or to remove the switch from the GROUND SELECTED position with the breaker closed. Actual grounding is done via the circuit-breaker itself. Busbar grounding is possible with the available make-proof grounding switch. If a bus sectionalizer or bus coupler is installed, busbar grounding can be done via the three-way switch and the corresponding circuit-breaker of these panels. The actual isolator position is positively displayed by rigid mechanical indicators.

600 1525

Fig. 42: Dimensions of switchgear type 8DA10, double-busbar

Switchgear type 8DB10, double-busbar

8

9

The double-busbar switchgear has been developed from the components of the switchgear type 8DA10. Two three-position switches are used for the selection of the busbars. They have their own gas-filled components. The second busbar system is located phasewise behind the first busbar system. The bay width of the switchgear remains unchanged; depth and height of each bay are increased (see dimension drawings Fig. 43). For parallel bus couplings, only one bay is required.

850**

7

2350

10

2660

Fig. 43: Dimensions of switchgear type 8DB10, double-busbar

3/32



Degrees of protection In accordance with IEC 60529: ■ Degree of protection IP 3XD: The operating mechanism and the lowvoltage cubicle have degree of protection IP 3XD against contact with live parts with objects larger than 1 mm in diameter. Protection against dripping water is optionally available. Space heaters inside the operating mechanism and the LV cabinet are available for tropical climates. ■ Degree of protection IP 65: By the nature of the enclosure, all highvoltage-carrying parts are totally protected against contact with live parts, dust and water jets.

Cable cross-sections for plug-in terminations 1) Interface type

1

Rated voltage 7.2/12/15 kV

17.5/24 kV

36 kV

Cable cross-section [mm2]

[mm2]

[mm2]

2

up to 300

up to 300

up to 185

3

400 to 630

400 to 630

240 to 500

4

up to 1200

up to 1200

up to 1200

2

3 1) The plug-in terminations are of the inside cone type acc. to EN 50181: 1997

Fig. 44

4

Installation The switchgear bays are shipped in prefabricated assemblies up to 5 bays wide on solid wooden pallets, suitable for rolling, skidding and fork-lift handling. Double-busbar sections are shipped as single or double bays. The switchgear is designed for indoor operation; outdoor prefabricated enclosures are available. Each bay is set onto embedded steel profile sections in a flat concrete floor, with suitable cutouts for the cables or busbars. All conventional cables can be connected, either with fully insulated plug-in terminations (preferred), or with conventional air-insulated stress cones. Fully insulated busbars are also connected directly, without any HV-carrying parts exposed. Operating aisles are required in front of and (in case of double-busbar systems) behind the switchgear lineup.


Width

[mm]

600

single-busbar (8DA) double-busbar (8DB)

[mm] [mm]

2250 2350

Depth


[mm] [mm]

1525 2660

Weight per bay


[kg] [kg]

Height

5

6

7

approx. 600 approx. 1150

Fig. 45

8 Ambient temperature and current-carrying capacity: Rated ambient temperature (peak)

40 °C

Rated 24-h mean temperature

35 °C

Minimum temperature

–5 °C

At elevated ambient temperatures, the equipment must be derated as follows (expressed in percent of current at rated ambient conditions).

30 °C

=

110%

35 °C

=

105%

40 °C

=

100%

45 °C

=

90%

50 °C

=

80%

9

10

Fig. 46


3/33


1

Options for circuit-breaker feeder of switchgear type 8DA10, single-busbar

Busbar accessories

2

Mounted on breaker housing

Mounted on current transformer housing Panel connection options per phase

3 Voltage transformer, nondisconnectable or disconnectable

4 or

5

Totally gas or solid-insulated bar

Mounted on panel connections

or

or

Sectionalizer without additional space required

or

3 x plug-in cable termination Interface type 3


or

Busbar current transformer

or



2 x plug-in cable termination Interface type 2 and 3 with plug-in voltage transformer


6

8

or


Cable or bar connection, nondisconnectable or disconnectable

or

7

Make-proof earthing switch

1 x plug-in cable termination Interface type 2 and 3



or

Current transformer

or

9

Totally solid-insulated bar with plug-in voltage transformer or

10

Air-insulated cable termination or

Surge arrester

Air-insulated bar

Plug-in cable terminations are of the Inside Cone Type acc. to EN 50181: 1997 Fig. 47

3/34



Options for circuit-breaker feeder of switchgear type 8DB10, double-busbar

1 BB1 BB2

Busbar accessories

2 Mounted on breaker housing

Mounted on current transformer housing Panel connection options per phase BB1

BB1

BB2

or

BB2

Voltage transformer, nondisconnectable

Voltage transformer, disconnectable

BB1

BB1

BB1

BB2

BB2

or

or and

BB2

BB1 BB2

or BB1 and BB2

or

BB2

or

BB1

Make-proof earthing switch

or

or


5



Cable or bar connection, nondisconnectable

or

Cable or bar connection, disconnectable

or


or

Sectionalizer BB2 without additional space required


4 1 x plug-in cable termination Interface type 2 and 3

Totally gas or solid-insulated bar BB1

3

6


7


Current transformer

2 x plug-in cable termination Interface type 2 and 3 with plug-in voltage transformer


8

9

or Totally solid insulated bar with plug-in voltage transformer or Air-insulated cable termination or

10

Surge arrester

Air-insulated bar

Plug-in cable terminations are of the Inside Cone Type acc. to EN 50181: 1997 Fig. 48


3/35


1

2

3

4

5


[kV]

7.2

12

15

17.5

24

36

40.5


[kV]

20

28

36

38

50

70

85

Rated lightning-impulse withstand voltage

[kV]

60

75

95

95

125

170

180 (200)

Rated short-circuit breaking current and rated short-time current 3s,

max.

[kA]

40

40

40

40

40

40

40


max.

[kA]

110

110

110

110

110

110

110

Rated current busbar with twin busbar

max. max.

[A] [A]

3150 4500

3150 4500

3150 4500

3150 4500

3150 4500

2500 4500

2500 4500

Rated current feeder

max.

[A]

2500

2500

2500

2500

2500

2500

2500

Fig. 49

6

Further Applications Power Supply for Railway Systems

7

8

9

10

Type 8DA10 SF6 gas-insulated switchgear (single and double-pole) (Fig. 50a). This type has been upgraded for service in railway networks with a basic-impulse insulation level (BIL) of 200 (230) kV. It is therefore the ideal switchgear for 1 x 25 kV and 2 x 25 kV (50/60 Hz) railway networks. Typical occurrences in railway networks prove the suitability of the switchgear for such applications: ■ Effects of lightning strikes ■ Switching impulse voltage ■ Breaking under asynchronous conditions with a 180° phase difference ■ Recovery voltage after breaking under asynchronous conditions with a 180° phase difference.

3/36

Twin-Busbar System (TBS) This primary distribution switchgear is based on the worldwide proven SF6-insulated type 8DA / 8DB switchgear and has been supplemented by a twin busbar (Fig. 50b). The use of standard components allowed us in a remarkably short time to create from a modular, compact type of switchgear a high-current system unbeatable in terms of minimal space requirement. The modular-structure busbars were arranged in twin-busbar form. This twin-busbar system is supplied via a twin circuit-breaker and respective twin disconnector. All standard panel types required (incoming feeder, coupler, outgoing feeder) are available.



Further applications for 8DA/8DB

1

a) Power Supply for Railway Systems 1-pole

2-pole

2

3

4

5

6 b) High Power Busbar 4500 A with Twin Busbar System (TBS) 8DA (single busbar)

8DB (double busbar)

7

8

9

10

Fig. 50 a/b


3/37

SF6-Insulated Switchgear Type NX PLUS

1

Gas-insulated switchgear type NX PLUS

Specific features

Panel construction

■ Used in transformer stations and sub-

stations ■ Practically maintenance-free compact

2

3

From 7.2 up to 36 kV Single-busbar Metal enclosed/metal-clad Three-pole primary enclosure Gas-insulated Fixed-mounted circuit-breakers Three-position switch as busbar disconnector and feeder earthing switch ■ Make-proof earthing with vacuum circuit-breaker ■ ■ ■ ■ ■ ■ ■

switchgear for the most severe service conditions ■ Panel width 600 mm (with bus sectionalizer panel 900 mm) for all voltages up to 36 kV

Panel with integrated inside cone Features ■ Rated voltage up to 36 kV ■ Rated short-circuit breaking current

up to 31.5 kA

General description The switchgear type NX PLUS combines compact design, long service life, climateresistance and freedom from maintenance

■ Rated normal currents of busbars and

feeders up to 2500 A.

1. Reliablility ■ Hermetically sealed primary enclosure

4

■

■

5

■

6

■ ■ ■

7 ■

for protection against environmental effects (dirt, moisture and small animals) Operating mechanism components maintenance-free in indoor environment (DIN VDE 0670 Part 1000) Breaker operating mechanisms accessible outside the switchgear container (primary enclosure) Inductive voltage transformers metalenclosed for plug-in mounting outside the main circuit Ring-core current transformers located outside the primary enclosure Complete interrogative interlocking system Welded switchgear container, sealed for life Minimum fire load.

2. Insulation medium Due to the excellent experience with vacuum circuit-breaker gas-insulated switchgear, there is a worldwide rapidly increasing demand of this kind of switchgear even in the so-called low-range field. The insulating gas SF6 is used for internal insulation only; circuit interruption takes place in standard vacuum breaker bottles. The safety for the personnel and the environment is maximized. The NX PLUS is completely maintenancefree. The welded gas-tight enclosure of the primary part assures a full service life without any work on the gas system.

8

9

10 Fig. 51: SF6-insulated switchgear Type NX PLUS with SIPROTEC

Panel with separate inside cone Features ■ Rated voltage up to 36 kV ■ Rated short-circuit breaking current

up to 31.5 kA ■ Rated normal currents of busbars and

feeders up to 2500 A.

Panel with outside cone Features ■ Rated voltage up to 24 kV ■ Rated short-circuit breaking current up

to 25 kA ■ Rated normal currents of busbars up

to 2500 A and feeders up to 1250 A.

Fig. 52

3/38



1 1 Door of low-voltage compartment 2 SIPROTEC 4 bay controller, type 7SJ63, for control and protection

3 EMERGENCY OFF pushbutton 4 Door to mechanical control board 6 7 29 8 1

9

15

10 18

4 5

3

SF6-insulated

8 Three-pole busbar system 9 Three-position switch, SF6-insulated, with the three positions: ON – OFF – EARTH

4

10 Module coupling between busbar

11 3

5 Cover of connection compartment 6 Busbar cover 7 Busbar module, welded,

16 17

2

2

module and circuit-breaker module

12

19

29

20

13

21

12 Vacuum interrupter of circuit-breaker 13 Pressure-relief duct

14

22

14 Integrated cable connection as inside

11 Circuit-breaker module, welded, SF6-insulated, with integrated cable connection

cone

5

6

15 Optional low-voltage compartment 1100 mm high

16 Standard low-voltage compartment 730 mm high

17 Ring-core current transformer 18 Manual and motor operating

29 23 17 24 29 25

7

mechanism of three-position switch

19 Mechanical control board 20 Manual and motor operating

8

mechanism of circuit-breaker

21

21 Voltage transformer connection

22

22 Cable connection compartment 23 Module coupling between

socket as inside cone

circuit-breaker and cable connection module

9

24 Cable connection module, welded, SF6-insulated, with separate cable connection

29 11

25 Separate cable connection as inside cone

17

26 Voltage transformer connection

26 27 28

socket as outside cone

22

27 Cable connection as outside cone 28 Connection cables 29 Rupture diaphragm


3/39

10


Tolerance to environment

1

2

■ Hermetically-sealed enclosure protects

all high-voltage parts from the environment ■ Installation independent of altitude ■ Corrosion protection for all climates.

up to [kV]

24

Rated frequency

[Hz]

50/60

50/60

Rated short-time power-frequency voltage

[kV]

50

70 (85*)

Operator safety

Rated lightning impulse voltage

[kV]

125

170 (185*)

■ Safe-to-touch and hermetically sealed

Rated short-circuit breaking current and rated short-time withstand current, 3 s

max. [kA]

31.5

31.5


max. [kA]

80

80

Rated normal current of busbar

max.

[A]

2500

2500

Rated normal current of feeder

max.

[A]

2500

2500

■

3 ■

4

■

■ ■

5

Technical data

primary enclosure All HV parts, including the cable sealing ends, busbars and voltage transformers, are surrounded by earthed layers or metal enclosures Capacitive voltage detection system for verification of safe isolation from supply Operating mechanisms and auxiliary switches safely accessible outside the primary enclosure (switchgear container) Protective system interlock to prevent operation when enclosure is open Type-tested enclosure and interrogative interlocks provide high degree of internal arcing protection.

Rated voltage

*) On request Fig. 53

Weights and dimensions Width Width of sectionalizer panel (≤ 2000 A)

6

7

36 (40.5*)

[mm]

600 900

Width sectionalizer panel (> 2000 A)

[mm]

1200

Height Height with higher LV compartment

[mm] [mm]

2450 2630

Depth

[mm]

1600

[kg]

800

Weight per panel (approx.) Fig. 54

8

9

10

3/40



Control board

Solid-state HMI with panel door closed

SIPROTEC 4 bay controller, type 7SJ63

1

(The basic unit for this is in the low-voltage compartment)

Bay controller Solid-state HMI (human-machine interface) SIPROTEC 4 bay controller, type 7SJ63, PROFIBUS-capable, control and protection for stand-alone or master operation.

2 5

1 2

3 3

6

4

4 1 LCD for process and equipment information, graphically as feeder mimic control diagram and as text Keys for navigating in menus, in feeder mimic control diagram and for entering values Keys for controlling the process Four programmable function keys for frequently performed actions Fourteen programmable LEDs with possible application-related inscriptions for indicating any desired process and equipment data 6 Two key-operated switches for “changeover between local and remote control“ and “changeover between interlocked and non-interlocked position“.

2 3 4 5

5

6

Fig. 55

Mechanical control board Features

Mechanical control board with panel door open

1 ON/OFF position indication for threeposition switch

■ Arranged behind panel door ■ Opening of door switches of the

2 ON/OFF operating shaft for three-position

1 2 3 4

SIPROTEC 4 bay controller, type 7SJ63, automatically ■ Three-position switch interlocked with circuit-breaker ■ Cancelling of feeder earthing can be blocked mechanically.

5 6 7 8 9 10 11 12 13 14 15

switch 3 OFF/EARTHING PREPARED operating shaft for three-position switch 4 OFF/EARTHING PREPARED position indication for three-position switch 5 Mimic diagram 6 Ready indication for busbar module (gas compartment monitoring) 7 Ready indication for circuit-breaker module (gas compartment monitoring) 8 Interlocking for preselection 9 ON/OFF position indication for circuitbreaker 10 Manual spring charging for circuit-breaker 11 ON pushbutton for circuit-breaker with sealable cap 12 OFF pushbutton for circuit-breaker 13 Locking device for ”feeder earthed” 14 ”Spring charged” indication for circuitbreaker 15 Operating cycle counter for circuit-breaker

Fig. 56


3/41

7

8

9

10


Options for circuit-breaker panel

1

2

with cable connection as inside cone for: ■ Rated voltage up to 36 kV ■ Rated short-circuit breaking current up to 31.5 kA ■ Rated normal currents of busbars and feeders up to 2500 A.

Busbar fittings

Fittings before circuit-breaker module Fittings after circuit-breaker module 4) 1)

Also available as Disconnector panel.

Panel connection fittings

1)

3 Panel connection versions

4

Capacitive voltage detection system

1 x plug-in cable, sizes 2 or 3

Voltage transformer, plug-in type

Current transformer

5 or 2)

1 x plug-in cable, size 2

or


or 2)


or


or 2)

Surge arrester, plug-in type

or


and 3)


or

Solidinsulated bar (e.g. Duresca bar)

6

7

8

9

10


1) Capacitive voltage detection system according to LRM or IVDS system. 2) Not possible with rated normal current of feeder of 2500 A. 3) Not possible with busbar voltage transformer. 4) Requires cable connection with container for separate inside cone.

Fig. 57

3/42



Options for circuit-breaker panel with cable connection as outside cone for: ■ Rated voltage up to 24 kV ■ Rated short-circuit breaking current up to 25 kA ■ Rated normal currents of busbars up to 2500 A and feeders up to 1250 A.

1

Busbar fittings

Fittings before circuit-breaker module Fittings after circuit-breaker module

Also available as Disconnector panel.

1) 1)

2

Panel connection fittings

3 Panel connection versions Capacitive voltage detection system

1 x plug-in cable

Voltage transformer, disconnectable

Current transformer

4

5 or


or

2 x plug-in cable

6 or

or

and 2)


or

3 x plug-in cable

7


8


9

10

Surge arrester or limiter, plug-in type

1) Capacitive voltage detection system according to LRM or IVDS system. 2) Not possible with busbar voltage transformer.

Fig. 58


3/43


Options for sectionalizer panel

1

■ Rated voltage up to 36 kV ■ Rated short-circuit breaking current up to

Sectionalizer panel

31.5 kA ■ Rated normal currents of busbar up to

2500 A.

Busbar fittings

2

Fittings before circuitbreaker module

1)

3

4

1)

5

and

Capacitive voltage detection system

Current transformer


6 1) Not possible with rated normal current of busbar of 2500 A.

Fig. 59

7

8

9

10

3/44



Standards, specifications, guidelines

Internal arc test, resistance to internal arcs Internal arc test

Standards The NX PLUS switchgear complies with the standards and specifications listed below: ■ VDE 0670, Part 1000 ■ VDE 0670, Part 6 ■ VDE 0670, Part 101 et seq. ■ VDE 0670, Part 2 ■ IEC 60 694 ■ IEC 60 298 ■ IEC 60 056 ■ IEC 60 129. In accordance with the obligatory harmonization in the European Community, the national standards of the member countries conform to IEC 60 298. Type of service location NX PLUS switchgear can be used as an indoor installation in accordance with VDE 0101: ■ Outside closed electrical operating areas in locations not accessible to the general public. Tools are required to remove switchgear enclosures. ■ In closed electrical operating areas. A closed electrical operating area is a room or area which is used solely for the operation of electrical installations. This type of area is locked at all times and accessible only to authorized trained personnel and other skilled staff. Untrained or unskilled persons must be accompanied by authorized personnel. Definition “Make-proof earthing switches“ are earthing switches with short-circuit making capacity (VDE 0670, Part 2).

Tests have been carried out with NX PLUS switchgear, in order to verify its behaviour under conditions of internal arcing. The resistance to internal arcing complies with the requirements of ■ VDE 0670, Part 6, Appendix AA ■ IEC 60 298, Appendix AA. Resistance to internal arcs The possibility of faults in the NX PLUS fixed-mounted circuit-breaker switchgear is much less than in previous types, due to the single-pole enclosure of external components and the SF6 insulation of the switchgear: ■ All external fault-causing factors have been eliminated, such as: – Pollution deposits – Moisture – Small animals and foreign bodies ■ Maloperations are prevented by the clear, logical layout of the operating elements ■ The three-position switch and the vacuum circuit-breaker provide short-circuitproof earthing of the feeder. Should arcing occur in spite of this, the pressure is relieved towards the rear into a duct. In the improbable event of a fault inside the switchgear container, the SF6 insulation restricts the arc energy to only about 1/3 of that for air. The pressure-relief facility in the rear panel of the switchgear container is designed to operate in an overpressure range of 2 to 3.5 bar. The gases are discharged towards the rear into a duct. The pressure-relief duct diverts the gases upwards.

Protection against electric shock, the ingress of water and solid foreign bodies The NX PLUS fixed-mounted circuit-breaker switchgear is fully enclosed and entirely unaffected by climatic influences. ■ All medium-voltage switching devices are enclosed in a stainless steel container, which is welded gas-tight and filled with SF6 gas. ■ Live parts outside the switchgear container are single-pole insulated and screened. ■ There are no points at which leakage currents of high-voltage potential are able to flow off to earth. ■ All essential components of the operating mechanism are made of non-corroding materials.

1

2

3

4

Degrees of protection The NX PLUS fixed-mounted circuit-breaker switchgear offers the following degrees of protection in accordance with IEC 60 529: ■ IP3XD for external enclosure ■ IP65 for parts under high voltage

5

6

7

8

9

10


3/45

Secondary Distribution Switchgear and Transformer Substations

General 1

2

3

4

5

6

7

8

9

10

Features

Standards ■ The fixed-mounted ring-main units

Maximum personnel safety The secondary distribution network with its basic design of ring-main systems with counter stations as well as radial-feed transformer substations is designed in order to reduce network losses and to provide an economical solution for switchgear and transformer substations. These are installed with an extremely high number of units in the distribution network. Therefore, high standardization of equipment is necessary and economical. The described switchgear will show such qualities. To reduce the network losses the transformer substations should be installed directly at the load centers. The transformer substations consisting of medium-voltage switchgear, transformers and low-voltage distribution can be designed as prefabricated units or single components installed in any building or rooms existing on site. Due to the large number of units in the networks the most economical solution for such substations should have climate-independent and maintenance-free equipment so that operation of the equipment does not need any maintenance work during its lifetime. For such transformer substations, nonextensible and extensible switchgear, for instance ring-main units (RMUs), have been developed using SF6 gas as insulation and arc-quenching medium in the case of loadbreak systems (RMUs), and SF6 gas insulation and vacuum as arc-quenching medium in the case of extensible modular switchgear, consisting of load-break panels with or without fuses, circuit-breaker panels and metering panels. Siemens has developed RMUs in accordance with these requirements. Ring-main units type 8DJ10, 8DJ20, 8DJ40 and 8DH10 are type-tested, factory-finished, metal-enclosed, SF6-insulated indoor switchgear installations. They verifiably meet all the demands encountered in network operation by virtue of the following features:

3/46

■ High-grade steel housing and cable con-

■ ■ ■ ■ ■

nection compartment tested for resistance to internal arcing Logical interlocking Guided operating procedures Capacitive voltage indication integrated in unit Safe testing for dead state on the closed-off operating front Locked, grounded covers for fuse assembly and cable connection compartments

type 8DJ10, 8DJ20, 8DJ40 and 8DH10 comply with the following standards:

IEC Standard

VDE Standard

IEC 60 694

VDE 0670 Part 1000

IEC 60 298

VDE 0670 Part 6

IEC 60 129

VDE 0670 Part 2

IEC 60 282

VDE 0670 Part 4

IEC 60 265-1

VDE 0670 Part 301

Safe, reliable, maintenance-free

IEC 60 420

VDE 0670 Part 303

■ Corrosion-resistant hermetically welded

IEC 60 056

VDE 0670 Part 101–107

IEC 61 243-5

EVDE 0682 Part 415 EN 61 243-5(E)

■

■ ■

■

■

high-grade steel housing without seals and resistant to pressure cycles Insulating gas retaining its insulating and quenching properties throughout the service life Single-phase encapsulation outside the housing Clear indication of readiness for operation, unaffected by temperature or altitude Complete protection of the switch disconnector/fuse combination, even in the event of thermal overload of the HV HRC fuse (thermal protection function) Reliable, maintenance-free switching devices

Fig. 60

In accordance with the harmonization agreement reached by the European Union member states that their national specifications conform to IEC Publication No. 60 298. Resistance to internal arcing – IEC Publ. 60 298, Annex AA – VDE 0670, Part 6

Excellent resistance to ambient conditions


■ Robust, corrosion-resistant and mainte-

Fax: ++ 49 - 91 31-73 46 36

nance-free operating mechanisms ■ Maintenance-free, all-climate, safe-totouch cable terminations ■ Creepage-proof and free from partial discharges ■ Maintenance-free, safe-to-touch, all-climate HV HRC fuse assembly Environmental compatibility ■ Simple, problem-free disposal of the

SF6 gas ■ Housing material can be recycled by

normal methods


Secondary Distribution Switchgear and Transformer Substations

1 Primary distribution G

2

3

4 Secondary distribution

5

6

7

8

9

RMU for transformer substations Type 8DJ

Extensible switchgear for consumer substations Type 8DH or 8AA

Extensible switchgear for substations with circuit-breakers Type 8DH or 8AA

10

Fig. 61: Secondary Distribution Network


3/47

Secondary Distribution Selection Matrix

1

2

Switchgear

Codes, standards

Type of installation

Insulation

Enclosure

Switching device

Appl

3

RMU subst conve conne Stand

4 Nonextensible

5

6

SF6-gas-insulated

Metal-enclosed fixed-mounted

Load-break switch

Medium-voltage indoor switchgear, type-tested according to: IEC 60 298 DIN VDE 0670, Part 6

RMU subst cable Stand

RMU low s housi

SF6-gas-insulated

Metal-enclosed fixed-mounted

Load-break switch Vacuum CB Measurement panels

Cons CB sw up to

Air-insulated

Metal-enclosed

Load-break switch Vacuum CB Measurement panels

Cons CB sw up to

7 Extensible

8

9 Transformer substations

Execution of the transformer substation

10 Prefabricated, factory-assembled substations, with different type of housings, made of concrete, galvanized sheet steel or aluminium

Fig. 62

3/48


Secondary Distribution Selection Matrix

1 Application

Switchgear type

Technical data Rated lightning impulse withstand voltage at: 7.2/12 17.5/24 [kV] [kV]

RMU for transformer substations, plug and conventional cable connection, Standard Range 1

8DJ10

RMU for transformer substations, high cable connection, Standard Range 2

8DJ20

60/75

Page Rated voltage [kV]

95/125

7.2–24

Maximum rated short-time withstand current [kA] [kA] 1s 3s

25

20

2 Rated normal current Busbar max. [A]

Feeder [A]

3 630

up to 630

3/50

4 60/75

7.2–12

25

14.3

7.2–24

20

20

630

95/125

up to 630

3/53

5 RMU for extremely low substation housings

8DJ40

60/75

95/125

7.2–24

20

11.5

630

up to 630

3/58

6 Consumer substation/ CB switchgear up to 630 A

Consumer substation/ CB switchgear up to 630 A

8DH10

8AA20

7.2–15

25

20

17.5–24

20

11.5

7.2–12

20

11.5

1000

up to 1000

17.5–24

16

9.3

630

up to 630

Type of housing

HV section Medium-voltage switchgear type

Transformer rating

8FB10

8DJ10

630 kVA

8FB11

8DJ20

8FB12

8DJ40

60/75

60/75

95/125

1250

up to 630

3/60

7

95/125

3/64

8

9 Package substation type (Example)

8FB1

8FB15

Page

10 3/66

up to 1000/1250 kVA

8FB16 8FB17


3/49

Secondary Distribution Switchgear Type 8DJ10

1

2

3

4

Ring-main unit type 8DJ10, 7.2–24 kV nonextensible, SF6-insulated Standard Range 1 Typical use SF6-insulated, metal-enclosed fixed-mounted ring-main units (RMU) type 8DJ10 are used for outdoor transformer substations and indoor substation rooms with a variability of 25 different schemes as a standard delivery program. More than 60,000 RMUs of type 8DJ10 are in worldwide operation. Specific features ■ Maintenance-free, all-climate ■ SF6 housings have no seals ■ Remote-controlled motor operating

5 ■

■

6

■ ■

7

■

■

8

mechanism for all auxiliary voltages from 24 V DC to 230 V AC Easily extensible by virtue of trouble-free replacement of units with identical cable connection geometry Standardized unit variants for operatorcompatible concepts Variable transformer cable connection facilities Excellent economy by virtue of ambient condition-resistant, maintenance-free components Versatile cable connection facilities, optional connection of mass-impregnated or plastic-insulated cables or plug connectors Cables easily tested without having to be dismantled

Fig. 63: Example: Scheme 10

9

10

3/50



Technical data (rated values)1)

1

Rated voltage

[kV]

7.2

12

15

17.5

24

Rated frequency

[Hz]

50/60

50/60

50/60

50/60

50/60

Rated current of cable feeders

[A]

400/630

400/630

400/630

400/630

400/630

Rated current of transformer feeders2)

[A]

200

200

200

200

200


[kV]

20

28

36

38

50


[kV]

60

75

95

95

125

Rated short-circuit making current of cable feeder switches

[kA]

63

52

52

52

40

Rated short-circuit making current of transformer switches

[kA]

25

25

25

25

25

Rated short-circuit current, 1s

[kA]

25

21

21

21

16

Ambient temperature

[°C]

min. – 50 max. +80

min. – 50 max. +80

min. – 50 max. +80

min. – 50 max. +80

min. – 50 max. +80

2

3

4

5

6

1) Higher values on request 2) Depending on HV HRC fuse assembly

7

Fig. 64

8 1 2 3

1

HRC fuse boxes

2

Hermetically-scaled welded stainless steel enclosure

3

SF6 insulation/quenching gas

4

Three-position load-break switch

5

Feeder cable with insulated connection alternative with T-plug system

6

Maintenance-free stored energy mechanism

4 6

9

10

5

Fig. 65: Cross section of SF6-insulated ring-main unit 8DJ10


Fig. 66: “Three-position load-break switch” ON–OFF–EARTH

3/51


1

Examples out of 25 standard schemes With integrated HV HRC fuse assembly

2

3 Scheme 10

Scheme 71

Scheme 81

4 Dimensions [mm]

5

6

Width Depth Height Version with low support frame Version with high support frame

800

1170

1630

800

800

800

1360

1360

1360

1760

1760

1760

Scheme 61

Scheme 64

Without HV HRC fuses

Combinations

7

8

Scheme 70

9

10

Dimensions [mm] Width Depth Height Version with low support frame Version with high support frame

1450

1700

2070

800

800

800

1105

1360

1360

1505

1760

1760

Fig. 67: Schemes and dimensions

3/52



Ring-main unit type 8DJ20, 7.2–24 kV non extensible, SF6-insulated Standard Range 2

1

2

Typical use Same system as type 8DJ10 (page 3/50) but other geometrical dimensions and design, also single panel for transformer feeder. ■ Substations with control aisles ■ Compact substations, substations by pavements ■ Tower base substations ■ 7.2 kV to 24 kV ■ Up to 25 kA

3

4

Specific features ■ Minimal dimensions ■ Ease of operation ■ Proven components from the ■ ■ ■ ■

■ ■ ■ ■

8DJ10 range Metal-enclosed All-climate Maintenance-free Capacitive voltage taps for – incoming feeder cable – outgoing transformer feeder Optional double cable connection Optional surge arrester connection Transformer cable connected via straight or elbow plug Motor operating mechanism for auxiliary voltages of 24 V DC – 230 V AC

5

6 Fig. 68: Example: Scheme 10 (width 1060 mm)

7

8

8DJ20 switchgear ■ Overall heights 1200 mm, 1400 mm ■ ■ ■ ■

or 1650 mm High cable termination For cable T-plugs Detachable lever mechanism Option: rotary operating mechanism

9

10


3/53


Technical data

1

2

Rated voltage Ur

[kV]

7.2

12

15

17.5

24

Rated insulation level: Rated power-frequency withstand voltage Ud

[kV]

20

28

36

38

50

[kV]

60

75

95

95

125

[Hz]

50/60

50/60

50/60

50/60

50/60

[A]

400 630

400 630

400 630

400 630

400 630

[A]

200

200

200

200

200

Rated short-time withstand current Ik, 1 s

[kA]

20 25

20 25

21 25

21 25

16 21

Rated short-time withstand current Ik, 3 s

[kA]

20

20

20

20

20

Rated peak-withstand current Ip

[kA]

50 63

50 63

52 63

52 63

40 52

Rated short-time making current Ima for transformer feeder

[kA]

25

25

25

25

25

[kA]

50 63

50 63

52 63

52 63

40 52

[°C]

–40 to +70

[hpa]

500

500

500

500

500

Rated lightning impulse voltage Up Rated frequency fr

3

Rated normal current Ir for ring-main feeders for transformer feeders depending on the HV HRC fuse

4

5

for ring-main feeder

6

Ambient temperature T Rated filling pressure (at 20 °C) for insulation pre and for operation prm

7

Fig. 69

8

9

10

3/54



1

Transformer feeder Section A-A

A

1 HV HRC fuse compartment

1

2 RMU vessel, filled with SF6 gas

2

3 Three position load-break switch ON-OFF-Earth

2

4 Transformer cable with elbow

3

5 Spring-assisted/stored-energy

plugs

3

mechanism

5

4 4

5

6 A

Standard Cable termination for elbow plugs (Option:cable-T-plugs), cable bushing directed downlwards

7

Fig. 70: Panel design / Example: ring-main transformer block, scheme 10

8

9

10


3/55


Transformer feeder panels with HV HRC fuses

1

Ring-main units without HV HRC fuses

Combinations with HV HRC fuses2)

2

3

4 Scheme 01

Scheme 21

Scheme 11/32/70/84

Scheme 20

Scheme 10

5

6

7

Ring-main feeders

9

0

2–5

1

2

1

1

0

1

1

Cable connection with cable plugs, compatible with bushings ASG 36-400 to DIN 47 636 with thread connection M 16 x 2, connection at front Transformer feeders

8

0

Cable connection with cable plugs, compatible with bushings ASG 24-250 to DIN 47 636, optionally ASG 36 400 with plug/thread connection M 16 x 2 Location of bushings optionally at front or at bottom

10

–

Dimensions in mm Width

510

710

710 + 350/per additional feeder

710

1060

Depth

780

780

780

780

780

Height

1200

1200

1200

1200

1200

1400

1400

1400

1400

1400

1760

1760

1760

1760

1760

Fig. 71

3/56

2)

others on request


e 10


1

2

3

4 Scheme 71

Scheme 72

Scheme 81

Scheme 82

5

3

4

2

6

3

7 1

1

2

2

8

9

10 1410

1760

1410

1760

780

780

780

780

1200

1200

1200

1200

1400

1400

1400

1400

1760

1760

1760

1760


3/57


1

Ring-main unit type 8DJ40, 7.2–24 kV nonextensible, SF6-insulated Typical use

2

3

SF6-insulated, metal-enclosed, fixedmounted. Ring-main units type 8DJ40 are mainly used for transformer compact substations. The main advantage of this switchgear is the extremely high cable termination for easy cable connection and cable testing work. Specific features

4

5

6

7

8

8DJ40 units are type-tested, factoryfinished, metal-enclosed SF6-insulated switchgear installations and meet the following operational specifications: ■ High level of personnel safety and reliability ■ High availability ■ High-level cable connection ■ Minimum space requirement ■ Uncomplicated design ■ Separate operating mechanism actuation for switch disconnector and make-proof grounding switch, same switching direction in line with VDEW recommendation ■ Ease of installation ■ Motor operating mechanism retrofittable ■ Optional stored-energy release for ring cable feeders ■ Maintenance-free ■ All-climate

9

10

Fig. 72: Nonextensible RMU, type 8DJ40

Technical data (rated values)1) Rated voltage

[kV]

12

24

Rated frequency

[Hz]

50

50

Rated current of cable feeders

[A] 400/630*

400/630*

Rated current of transformer feeders

[A]

≤ 200

≤ 200


[kV]

28

50


[kV]

75

125

Rated short-circuit making current of cable feeder switches

[kA] 50 (31.5)*

40 (31.5)*

Rated short-circuit making current of transformer switches2)

[kA]

25

25

Rated short-time current of cable feeder switches

[kA] 20 (12.5)*

16 (12.5)*

Rated short-circuit time

[s]

1

1

Rated filling pressure at 20 °C

[barg]

0.5

0.5

Ambient temperature

[°C]

min. – 40 max. + 70

min. – 40 max. + 70

1) Higher values on request 2) Depending on HV HRC fuse assembly * With snap-action/stored-energy operating mechanism up to 400 A/12.5 kA, 1s

Fig. 73

3/58



1

2

3 Scheme 10

Scheme 32

Scheme 71

4

5 Dimensions [mm] Width

1140

909

1442

Depth

760

760

760

Height

1400/1250

1400/1250

1400/1250

6


7

8

9

10


3/59

Secondary Distribution Switchgear Type 8DH10

1

Consumer substation modular switchgear type 8DH10 extensible, SF6-insulated Typical use

2

3

4

SF6-insulated, metal-enclosed fixed-mounted switchgear units type 8DH10 are indoor installations and are mainly used for power distribution in customer substations or main substations. The units are particularly well suited for installation in industrial environments, damp river valleys, exposed dusty or sandy areas and in built-up urban areas. They can also be installed at high altitude or where the ambient temperature is very high. Specific features

5

6

7

8

9

10

8DH10 fixed-mounted switchgear units are type-tested, factory-assembled, SF6-insulated, metal-enclosed switchgear units comprising circuit-breaker panels, disconnector panels and metering panels. They meet the demands made on medium-voltage switchgear, such as ■ High degree of operator safety, reliability and availability ■ No local SF6 work ■ Simple to install and extend ■ Operation not affected by environmental factors ■ Minimum space requirements ■ Freedom from maintenance is met substantially better by these units than by earlier designs. ■ Busbars from panel blocks are located within the SF6 gas compartment. Connections with individual panels and other blocks are provided by solid-insulated plug-in busbars ■ Single-phase cast-resin enclosed insulated fuse mounting outside the switchgear housing ensures security against phase-to-phase faults ■ All live components are protected against humidity, contamination, corrosive gases and vapours, dust and small animals ■ All normal types of T-plugs for thermoplastic-insulated cables up to 300 m2 cross-section can be accommodated

Fig. 75: Extensible, modular switchgear type 8DH10

■ The units have a grounded outer enclo-

■ ■

■

■

■ ■

3/60

sure and are thus shockproof. This also applies to the fuse assembly and the cable terminations. Plug-in cable sealing ends are housed in a shock-proof metalenclosed support frame Fuses and cable connections are only accessible when earthed All bushings for electrical and mechanical connections are welded gas-tight without gaskets Three-position switches are fitted for load switching, disconnection and grounding, with the following switch positions: closed, open and grounded. Make-proof earthing is effected by the three-position switch (shown on page 3/51) Each switchgear unit can be composed as required from single panels and (preferably) panel blocks, which may comprise up to three combined single panels The 8DH10 switchgear is maintenancefree Integrated current transformer suitable for digital protection relays and protection systems for CT operation release



1 1 1

2

2 3 4

2

5

3

3

6 7

4

8

5

4

9 10

1 2 3 4 5

Fuse assembly Three-position switch Transformer/cable feeder connection Hermetically-welded gas tank Plug-in busbar up to 1250 A

1 2 3 4 5

6 Three-position switch 7 Ring-main cable termination

Low-voltage compartment Circuit-breaker operating mechanism Metal bellow welded to the gas tank Pole-end kinematics Spring-assisted mechanism

(400/630 A T-plug system) 8 Hermetically-welded RMU housing 9 Busbar (up to 1250 A) 10 Overpressure release system

5

6 Fig. 76: Cross section of transformer feeder panel

Fig. 77: Cross section of circuit-breaker feeder panel

7

LV cabinet 1 2

8 3 4

9 extensible

extensible

1 Plug bushing welded to the gas tank

10

2 Silicon adapter 3 Silicon-insulated busbar 4 Removable insulation cover to assemble the system at site

Fig. 78: Combination of single panels with plug-in type, silicon-insulated busbar. No local SF6 gas work required during assembly or extension


Fig. 79: Cross-section of silicon-plugged busbar section.

3/61


1

2

3

4

5

Technical data (rated values)1) Rated voltage

[kV]

7.2

12

15

17.5

24

Rated frequency

[Hz]

50/60

50/60

50/60

50/60

50/60


[kV]

20

28

36

38

50


[kV]

60

75

95

95

125

Rated short-circuit breaking current of circuit-breakers

[kA]

25

25

20

20

16

Rated short-circuit current, 1s

[kA]

25

25

20

20

16


[kA]

63

63

50

50

50

[A]

630 1250

630 1250

630 1250

630 1250

630 1250

– Circuit-breaker panels [max. A] [max. A] – Ring-main panels [max. A] – Transformer panels2)

400/630 400/630 200

400/630 400/630 200

400/630 400/630 200

400/630 400/630 200

400/630 400/630 200

Rated current of bus sectionalizer panels – without HV HRC fuses – with HV HRC fuses2)

400/630 200

400/630 200

400/630 200

400/630 200

400/630 200

Busbar rated current Feeder rated current

6

7

[A] [A]

1) Higher values on request 2) Depending on HV HRC fuse assembly

8

Fig. 80

9

10

3/62



Individual panels

1

2

3 Ring-main panel

Transformer panel

Circuit-breaker panel

Billing metering panel

Busbar metering and grounding panel

4

5

Dimensions [mm] Width

500

500

350

600*/850

500

Depth

780

780

780

780

780

Height

1400

2000

1400

1400/2000**

1450

6

* Width for version with combined instrument transformer ** With low-voltage compartment

7

Blocks

8

9 2

Ring-main feeders

3 Ring-main feeders

2

Transformer feeders

3

Transformer feeders

10 Dimensions [mm] Width

700

1050

1000

1500

Depth

780

780

780

780

Height

1400

1400

1400

1400



3/63

Secondary Distribution Switchgear Type 8AA20

1

2

3

4

Consumer substation modular switchgear type 8AA20, 7.2–24 kV extensible, air-insulated Typical use This air-insulated modular indoor switchgear is used as a flexible system with a lot of panel variations. Panels with fused and unfused load-break switches, with trucktype vacuum circuit-breakers and metering panels can be combined with air-insulated busbars. The 8AA20 ring-main units are type-tested, factory-assembled metal-enclosed indoor switchgear installations. They meet operational requirements by virtue of the following features: Personnel safety

5

Fig. 82: Extensible modulares switchgear type 8AA20

■ Sheet-steel enclosure tested for resist-

ance to internal arcing ■ All switching operations with door

Technical data (rated values)1)

closed

6

7

■ Testing for dead state with door closed ■ Insertion of barrier with door closed

Rated voltage and insulation level

Safety, reliability/maintenance


■ Complete mechanical interlocking ■ Preventive interlocking between barrier


and switch disconnector ■ Door locking

8

Excellent resistance to ambient conditions ■ High level of pollution protection by

virtue of sealed enclosure in all operating states ■ Insulators with high pollution-layer resistance

9

7.2

12

17.5

24

[kV]

20

28

38

50

[kV]

60

75

95

125

Rated short-time current 1s [kA]

20

20

16

16


[kA]

50

50

40

40

Rated busbar current1)

[A]

630

630

630

630

Rated feeder current

[A]

630

630

630

630

1) Higher values on request

Fig. 83

Dimensions

Width

Height

Depth

12/24 kV [mm]

[mm]

12/24 kV [mm]

Load-breaker panels

600/750

2000

665/790 or 931/1131

Circuit-breaker panels

750/750

2000

931/1131

Metering panels

600/750

2000

665/790 or 931/1131

10

Fig. 84: Dimensions

3/64


Secondary Distribution Switchgear Type 8AA20

Standards ■ The switchgear complies with the

1

following standards:

IEC Standard

VDE Standard

IEC 60 694

VDE 0670 Part 1000

IEC 60 298

VDE 0670 Part 6

IEC 60 129

VDE 0670 Part 2

IEC 60 282

VDE 0670 Part 4

IEC 60 265-1

VDE 0670 Part 301

IEC 60 420

VDE 0670 Part 303

IEC 60 056

VDE 0670 Part 101–107

IEC 61 243-5

EVDE 0682 Part 415 EN 61 243-5(E)

1 1

2

2 2

3

3

4 1 Load-break switch 2 Grounding switch

1 2 3 4

Fig. 86a: Cross-section of cable feeder panel

Fig. 86b: Cross-section of withdrawable type vacuum circuit-breaker panel

Vacuum circuit-breaker Current transformer Potential transformer Grounding switch

4

Fig. 85

In accordance with the harmonization agreement reached by the EC member states, their national specifications conform to IEC Publ. No. 60 298.

5

Resistance to internal arcing – IEC Publ. 60298, Annex AA – VDE 0670, Part 6

6

Type of service location

Individual panels

Air-insulated ring-main units can be used in service locations and in closed electrical service locations in accordance with VDE 0101.

Circuit-breaker panels Scheme 11/12

7 Scheme 13/14

Specific features

8

■ Switch disconnector fixed-mounted ■ Switch disconnector with integrated

central operating mechanism ■ Standard program includes numerous ■

■ ■ ■ ■ ■

circuit variants Operations enabled by protective interlocks; the insulating barrier is included in the interlocking Extensible by virtue of panel design Cubicles compartmentalized (option) Minimal cubicle dimensions without extensive use of plastics Lines up with earlier type 8AA10 Withdrawable circuit-breaker section can be moved into the service and disconnected position with the door closed

Load-break panels Scheme 21/22

Scheme 23/24

9

Scheme 25/26

10 Metering and cable panels Scheme 33/34

Fig. 87: Schemes


3/65

Secondary Distribution Transformer Substations

1

2

3

4

5

Factory-assembled packaged substations type 8FB1 (example) Factory-assembled transformer substations are available in different designs and dimensions. As an example of a typical substation program, type 8FB1 is shown here. Other types are available on request. The transformer substations type 8FB1 with up to 1000 kVA transformer ratings and 7.2–24 kV are prefabricated and factory-assembled, ready for connection of network cables on site. Special foundation not necessary. ■ Distribution substations for public power supply ■ Nonwalk-in type ■ Switchgear operated with open substation doors General features/Applications ■ Power supply for LV systems, especially

in load centers for public supply

Fig. 88: Steel-clad outdoor substation 8FB1 for rated voltages up to 24 kV and transformers up to 1000 kVA

■ Power supply for small and medium

6

7

8

9

10

industrial plants with existing HV side cable terminations ■ Particularly suitable for installation at sites subject to high atmospheric humidity, hostile environment, and stringent demands regarding blending of the station with the surroundings ■ Extra reliability ensured by SF6-insulated ring-main units type 8DJ, which require no maintenance and are not affected by the climate Brief description The substation housing consists of a torsion-resistant bottom unit, with a concrete trough for the transformer, embedded in the ground, and a hot-dip galvanized steel structure mounted on it. It is subdivided into three sections: HV section, transformer section and LV section. The lateral section of the concrete trough serves as mounting surface for the HV and LV cubicles and also closes off the cable entry compartments at the sides. These compartments are closed off at the bottom and front by hot-dip galvanized bolted steel covers. Four threaded bushes for lifting the complete substation are located in the floor of the concrete trough. The substations are arc-fault-tested in order to ensure safety for personnel during operation and for the pedestrians passing by the installed substation.

3/66

HV section (as an example):

LV section:

8DJ SF6-insulated ring-main unit (for details please refer to RMUs pages 2/48–2/61)

The LV section can take various forms to suit the differing base configurations. The connection to the transformer is made by parallel cables instead of bare conductors. Incoming circuit: Circuit breaker, fused load disconnector, fuses or isolating links. Outgoing circuits: Tandem-type fuses, load-break switches, MCCB, or any other requested systems. Basic measuring and metering equipment to suit the individual requirements.

Technical data: ■ Rated voltages and insulation levels

■ ■ ■ ■

7.2 kV 12 kV 15 kV 17.5 kV 24 kV 60 75 95 95 125 kV (BIL) Rating of cable circuits: 400 / 630 A Rating of transformer circuits: 200 A Degree of protection for HV parts: IP 65 Ambient temperature range: –30°C/+55°C (other on request)

Transformer section: Oil-cooled transformer with ratings up to max. 1000 kVA. The transformer is connected with the 8DJ10 ring-main unit by three single-core screened 35 mm2 plastic insulated cables. The connection is made by means of right-angle plugs or standard air-insulated sealing ends possible at the transformer side.


Secondary Distribution Transformer Substations

Substation housing type:

8FB10

8FB11

8FB12

8FB15

8FB16

8FB17

1

HV section: SF6 -insulated ring-main unit (RMU)

2

H High-voltage

H

T

L

section

H

H

T

T L

T

L

H

T L

T

T Transformer section

L

H

L

H

3

L Low-voltage section

Transformer rating

630 kVA

630 kVA

630 kVA

1000 kVA

1000 kVA

1000 kVA

4

Overall dimensions, weights: Length Width Height above ground Height overall Floor area Volume Weight without transformer

[mm] [mm] [mm] [mm] [mm2] [mm3] [kg]

3290 1300 1650

2570 2100 1650

2100 2100 1650

3860 1550 1700

3120 2300 1700

2350 2300 1700

2100 4.28 7.06 approx. 2280

2100 5.40 8.91 approx. 2530

2100 4.41 7.28 approx. 2400

2350 5.98 10.17 approx. 3400

2350 7.18 12.20 approx. 3800

2350 5.41 9.19 approx. 3600

5

6

Fig. 89: Technical data, dimensions and weights

7

8

9 Fig. 90: HV section: Compact substation 8FB with SF6-insulated RMU (two loop switches, one transformer feeder switch with HRC fuses)

Fig. 91: Transformer section: Cable terminations to the transformer, as a example


Fig. 92: LV section: Example of LV distribution board

10

3/67

Industrial Load Center Substation

Introduction 1

2

3

Industrial power supply systems call for a maximum level of operator safety, operational reliability, economic efficiency and flexibility. And they likewise necessitate an integral concept which includes “before” and “after” customer service, which can cope with the specific load requirements and, above all, which is tailored to each individually occurring situation. With SITRABLOC® such a concept can be easily turned into reality.


4

Fax: ++ 49 - 91 31-73 15 73

General 5

6

Fig. 93

SITRABLOC is an acronym for SIemens TRAnsformer BLOC-type. SITRABLOC is supplied with power from a medium-voltage substation via a fuse/ switch-disconnector combination and a radial cable. In the load center, where SITRABLOC is installed, several SITRABLOCs are connected together by means of cables or bars.

Substation

8DC11/8DH10

7

Load-centre substation

Features ■ Due to the fuse/switch-disconnector

8

9

10

combination, the short-circuit current is limited, which means that the radial cable can be dimensioned according to the size of the transformer. ■ In the event of cable faults, only one SITRABLOC fails. ■ The short-circuit strength is increased due to connection of several stations in the load center. The effect of this is that, in the event of a fault, large loads are selectively disconnected in a very short time. ■ The transmission losses are optimized since only short connections to the loads are necessary. ■ SITRABLOC has, in principle, two transformer outputs: – 1250 kVA during AN operation (ambient temperature up to 40 °C) – 1750 kVA during AF operation (140% with forced cooling). These features ensure that, if one station fails for whatever reason, supply of the loads is maintained without interruption.

3/68

Supply company's substation

LV busways

Fig. 94: Example of a schematic diagram



The SITRABLOC components are: ■ Transformer housing with roof-mounted ventilation for AN/AF operating mode ■ GEAFOL Transformer (cast-resin insulated) with make-proof earthing switch AN operating mode: 100% load up to an ambient temperature of 40 °C AF operating mode: 140% load ■ LV circuit-breaker as per transformer AF load ■ Automatic power factor correction equipment (tuned/detuned) ■ Control and metering panel as well as central monitoring interface ■ Universal connection to the LV distribution busway system

LV Busway

1

Tap-Off Unit with HRC Fuses

2 Consumer Distribution incl. Control

3 SITRABLOC

Fig. 95: Location sketch

4 Whether in the automobile or food industry, in paintshops or bottling lines, putting SITRABLOC to work in the right place considerably reduces transmission losses. The energy is transformed in the production area itself, as close as possible to the loads. For installation of the system itself, no special building or fire-protection measures are necessary. Available with any level of output SITRABLOC can be supplied with any level of power output, the latter being controlled and protected by a fuse/switch-disconnector combination. A high-current busbar system into which up to four transformers can feed power ensures that even large loads can be brought onto load without any loss of energy. Due to the interconnection of units, it is also ensured that large loads are switched off selectively in the event of a fault. Integrated automatic power factor correction With SITRABLOC, power factor correction is integrated from the very beginning. Unavoidable energy losses – e.g. due to magnetization in the case of motors and transformers – are balanced out with power capacitors directly in the low-voltage network. The advantages are that the level of active power transmitted increases and energy costs are reduced (Fig. 97).

Technical data Rated voltage Transformer rating AN/AF Transformer operating mode

12 kV and 24 kV

5

1250 kVA/1750 kVA 100% AN up to 40 °C 140% AF

Power factor correction

up to 500 kVAr without reactors up to 300 kVAr with reactors

Busway system Degree of protection

1250 A, 1600 A, 2500 A

Dimensions (min) (LxHxD) Weight approx.

3600 mm x 2560 mm x 1400 mm

6

IP 23 for transformer housing IP 43 for LV cubicles

7

6000 kg

Fig. 96

Reliability of supply

8

With the correctly designed transformer output, the n-1criterion is no longer a problem. Even if one module fails (e.g. a medium-voltage switching device, a cable or transformer) power continues to be supplied without the slightest interruption. None of the drives comes to a standstill and the whole manufacturing plant continues to run reliably. These examples show that, with SITRABLOC, the power is there when you need it – and safe, reliable and economical into the bargain.

9

10

Fig. 97: Capacitor Banks


3/69


N -1 criteria

N-1 operating mode

With the respective design of a factory grid on the MV side as well as on the LV side the so called n-1 criteria is fulfilled. In case one component fails on the line side of the transformer e.g. circuit breaker or transformer or cable to transformer, no interuption of the supply on the LV side will occur.

1 How to understand this mode: Normal operating mode: 4x1250 kVA N -1 operating mode: 3x1750 kVA

AN operating mode (100%) AF operating mode (≤ 140%)

2 Power distribution

Example Fig 98: Load required 5000 kVA = 4 x 1250 kVA. In case one load centre (SITRABLOC) is disconnected from the MV network the missing load will be supplied via the remaining three (N-1) load centres.

3 Supply company’s substation

4 Circuit-breakers and switch disconnectors with HV HRC fuses

Substation

5

t < 10 ms

SITRABLOC SITRABLOC SITRABLOC SITRABLOC

6

M

M

M Production M

M

M

Operator safety Reduced costs Low system losses

7

Fig. 98: N-1 operating mode

8

SITRABLOC is a combination of everything which present-day technology has to offer. Just one example of this are our GEAFOL® cast-resin transformers. Their output: 100% load without fans plus reserves of up to 140% with fans. And as far as persons are concerned, their safety is ensured even in the direct vicinity of the installation. Another example is the SENTRON highcurrent busbar system. It can be laid out in any arrangement, is quick to install and conducts the current wherever you like – with almost no losses. The most important thing, however, is the uniformity of SITRABLOC throughout, irrespective of the layout of the modules.

9

10

Fig. 99: Transformer and earthing switch, LV Bloc

3/70



The technology at a glance

Information distribution

SITRABLOC can cope with any requirements. Its features include ■ A transformer cubicle with or without fans (AN/AF operation) ■ GEAFOL cast-resin transformers with make-proof earthing switch – AN operation 1250 kVA, AF operation 1750 kVA ■ External medium-voltage switchgear with fuse switch-disconnectors ■ Low-voltage circuit-breakers ■ Automatic reactive-power compensation – up to 500 kVAr unrestricted, up to 300 kVAr restricted ■ The SENTRON high-current busbar system – Connection to high-current busbar systems from all directions ■ An ET 200 /PROFIBUS interface for central monitoring system (if required).

1

2 S7-400

S7-300

S5-155U PROFIBUS-DP

3

4 COROS OP

PG/PC

5 PROFIBUS ET 200B

ET 200C

Field devices

6 Communications interface

7

SITRABLOC ET 200M

12/24 kV P

P

8

GEAFOL transformer with built-on make-proof earthing switch

9 LV installation with circuitbreakers and automatic reactivepower compensation

10 0.4 kV LV busbar system with sliding link (e.g. SENTRON busways)

Option

Fig. 100


3/71

Medium-Voltage Devices Product Range

1

2

3

Devices for medium-voltage switchgear With the equipment program for switchgear Siemens can deliver nearly every device which is required in the mediumvoltage range between 7.2 and 36 kV. Fig. 101 gives an overview of the available devices and their main characteristics. All components and devices conform to international and national standards, as there are:

Device

Rated voltage

Shortcircuit current

Short-time current (3s)

[kV]

[kA]

[kA]

3AH

7.2 … 36

13.1 … 80

13.1 … 80

NX ACT

12

25

25

Outdoor vacuum circuit-breaker

3AF

36

25

25

Components for 3AH VCB

3AY2

12 … 36

16 … 40

16 … 40

Indoor vacuum switch

3CG

7.2 … 24

–

16 … 20

Indoor vacuum contactor

3TL

7.2 … 24

–

8 (1s)

Vacuum interrupter

VS

7.2 … 40.5

12.5 … 80

12.5 … 80

Indoor switch disconnector

3CJ

12 … 24

–

18 … 26 (1s)

Indoor disconnecting and grounding switch

3D

12 … 36

–

16 ... 63 (1s)

HV HRC fuses

3GD

7.2 … 36

31.5 … 80

–

Fuse bases

3GH

7.2 … 36

44 peak withstand current

–

Indoor post insulators, Bushings

3FA 3FH/3FM

3.6 … 36

–

–

Indoor and outdoor current and voltage transformers

4M

12 … 36

–

–

Surge arresters

3E

3.6 … 42

–

–

Indoor vacuum circuit-breaker

Type

Vacuum circuit-breakers

4

■ IEC 60 056 ■ IEC 60 694 ■ BS5311

Vacuum switches ■ IEC 60 265-1

5

in combination with Siemens fuses: ■ IEC 60 420 Vacuum contactors

6

■ IEC 60 470 ■ UL 347

Switch disconnectors

7

■ IEC 60 129 ■ IEC 60 265-1

HV HRC fuses ■ IEC 60 282

8

Current and voltage transformers ■ IEC 60 185, 60 186 ■ BS 3938, 3941 ■ ANSI C57.13

9 For further information please contact: Fax: ++ 49 - 91 31 - 73 46 54

10

Fig. 101: Equipment program for medium-voltage switchgear

3/72


Medium-Voltage Devices Product Range

Operating cycles

Rated current mechanical

with rated current

Applications/remarks

Page

All applications, e.g. overhead lines, cables, transformers, motors, generators, capacitors, filter circuits, arc furnaces

3/74

1

with shortcircuit current

[A] 800 … 12,000

10,000 … 120,000

10,000 … 30,000

25 … 100

1250 … 2500

10,000

10,000

25 … 50

1600

10,000

10,000

50

All applications, e.g. overhead lines, cables, transformers, motors, generators, capacitors, filter circuits

3/80

1250 … 2500

–

–

–

Original equipment manufacturer (OEM) and retrofit

3/81

2

3/78

3

4 800

10,000

10,000

–

All applications, e.g. overhead lines, cables, transformers, motors, capacitors; high number of operations; fuses necessary for short-circuit protection

3/82

400 … 800

1x106 ... 3x106

0.25x105 ... 2x106

–

All applications, especially motors with very high number of operating cycles

3/84

630 … 4000

10,000 … 30,000

10,000 … 30,000

25 … 100

For circuit breakers, switches and gas-insulated switchgear

3/85

630

1000

20

–

Small number of operations, e.g. distribution transformers

3/86

5

6

7 630 … 3000

–

–

–

Protection of personnel working on equipment

3/87

6.3 … 250

–

–

–

Short-circuit protection; short-circuit current limitation

3/88

400

–

–

–

Accommodation of HV HRC fuse links

3/88

–

–

–

–

Insulation of live parts from another, carrying and supporting function

3/89

9

10

–

–

–

–

Measuring and protection

3/90

–

–

–

–

Overvoltage protection

3/90


8

3/73

Medium-Voltage Devices Type 3AH

1

2

3

4

Indoor vacuum circuit-breakers type 3AH The 3AH vacuum circuit-breakers are three-phase medium-voltage circuit-breakers for indoor installations. The 3AH circuit-breakers are suitable for: ■ Rapid load transfer, synchronization ■ Automatic reclosing up to 31.5 kA ■ Breaking short-circuit currents with very high initial rates of rise of the recovery voltage ■ Switching motors and generators ■ Switching transformers and reactors ■ Switching overhead lines and cables ■ Switching capacitors ■ Switching arc furnaces ■ Switching filter circuits

5

As standard circuit-breakers they are available for the entire medium-voltage range. Circuit-breakers with reduced pole center distances, circuit-breakers for very high numbers of switching cycles and singlephase versions are part of the program. The following breaker types are available: ■ 3AH1 – the maintenance-free circuitbreaker which covers the range between 7.2 kV and 24 kV. It has a lifetime of 10,000 operating cycles ■ 3AH2 – the circuit-breaker for 60,000 operating cycles in the range between 7.2 kV and 24 kV ■ 3AH3 – the maintenance-free circuitbreaker for high breaking capacities in the range between 7.2 kV and 36 kV. It has a lifetime of 10,000 operating cycles ■ 3AH4 – the circuit-breaker for up to 120,000 operating cycles ■ 3AH5 – the economical circuit-breaker in the lower range for 10,000 maintenancefree operating cycles

Properties of 3AH circuit breakers: No relubrication Nonwearing material pairs at the bearing points and nonaging greases make relubrication superfluous on 3AH circuit-breakers up to 10,000 operating cycles, even after long periods of standstill. High availability Continuous tests have proven that the 3AHs are maintenance-free up to 10,000 operating cycles: accelerated temperature/ humidity change cycles between –25 and +60 °C prove that the 3AH functions reliably without maintenance. Assured quality Exemplary quality control with some hundred switching cycles per circuit-breaker, certified to DIN/ISO 9001. No readjustment Narrow tolerances in the production of the 3AH permanently prevent impermissible play: even after frequent switching the 3AH circuit-breaker does not need to be readjusted up to 10,000 operating cycles.

6 Electrical data and products summary

7

8

at Rated short-circuit breaking current1) (Rated short-circuit making current)

[kV]

[kA]

[kA]

[kA]

[kA]

[kA]

[kA]

[kA]

[kA]

[kA]

13.1 (32.8)

16 (40)

20 (50)

25 (63)

31.5 (80)

40 (100)

50 (125)

63 (160)

up to 80 (225)

7.2 12

9

10

Vacuum circuit-breaker (Type)

Rated voltage

3AH1 3AH5

3AH5

3AH5 3AH1

15

3AH1

17.5

3AH1

24

3AH1 3AH5

36

3AH5 800 A

800 A 800 A to to 1250 A 1250 A Rated normal current 1) DC component 36% (higher values on request).

3AH5

3AH5 3AH1

3AH1

3AH1 3AH2

3AH1 3AH2

3AH3

3AH3

3AH1

3AH1 3AH2

3AH1 3AH2

3AH3

3AH3

3AH1

3AH1 3AH2

3AH1 3AH2

3AH3

3AH3

3AH1

3AH1 3AH2

3AH1 3AH2

3AH3

3AH3

3AH38*)

1250 A to 3150 A

1250 A to 3150 A

1250 A to 4000 A

8000 A to 12000 A

3AH1 3AH2

3AH3 3AH4 3AH3 3AH4

800 A to 2500 A

800 A to 1250 A

800 A 1250 A to to 2500 A 2500 A2)

2) 3150 A for rated voltage 17.5 kV.

3AH3 3AH4 2500 A

*) 3 switches in parallel

Fig. 102: The complete 3AH program

3/74



3AH1 24 kV, 25 kA, 1250 A

3AH2 24 kV, 25 kA, 2500 A

3AH4 24 kV, 40 kA, 2500 A

1

2

3

4 Fig. 103: Vacuum circuit-breakers type 3AH

5

Advantages of the vacuum switching principle The most important advantages of the principle of arc extinction in a vacuum have made the circuit-breakers a technically superior product and the principle on which they work the most economical extinction method available: ■ Constant dielectric: In a vacuum there are no decomposition products and because the vacuum interrupter is hermetically sealed there are no environmental influences on it. ■ Constant contact resistance: The absence of oxidization in a vacuum keeps the metal contact surface clean. For this reason, contact resistance can be guaranteed to remain low over the whole life of the equipment. ■ High total current: Because there is little erosion of contacts, the rated normal current can be interrupted up to 30,000 times, the short-circuit breaking current an average of 50 times ■ Low chopping current: The chopping current in the Siemens vacuum interrupter is only 4 to 5 A due to the use of a special contact material. ■ High reliability: The vacuum interrupters need no sealings as conventional circuit-breakers. This and the small number of moving parts inside makes them extremely reliable.

6

7

8

Fig. 104: Front view of vacuum circuit-breaker 3AH1


9

10

3/75


1

3AH1, 12 kV 20 kA, up to 1250 A 25 kA, up to 1250 A

604 522

520

210

190

210 105

2

473

437

3

60

4

5

Dimensions in mm

3AH1, 3AH2, 12 kV

604 549 210

550 190

210

25 kA, 2500 A, 31.5 kA, 2500 A, 40 kA, 3150 A

105

6 437

587

7 109 Dimensions in mm

565

8 3AH1, 24 kV

9

16 kA, up to 1250 A, 20 kA, up to 1250 A, 25 kA, up to 1250 A

708 662 275

565 190 275 105

10

535 437

60 Dimensions in mm Fig. 105a: Dimensions of typical vacuum circuit-breakers type 3AH (Examples)

3/76



708 670

3AH1, 3AH2, 24 kV 20kA, 2500 A 25 kA, 2500 A

595

1

190 275

275

105

2 648

437

3 109 Dimensions in mm

3AH3, 12 kV

610

750 275

211

4 483

275

5

63 kA, 4000 A

6 733

564

7 776

Dimensions in mm

8 3AH3, 3AH4, 36 kV

820 350

211

526

350

31.5 kA, 2500 A, 40 kA, 2500 A

9

734 1000

564

Dimensions in mm

853

10

612

Fig. 105b: Dimensions of typical vacuum circuit-breakers type 3AH (Examples)


3/77

Medium-Voltage Devices Type NXACT

1

Indoor vacuum circuit-breaker module type NXACT General

2

NXACT combines the advantages of vacuum circuit-breakers with additional integrated functions. More functions

3

Disconnector, earthing switch, operator panel and interlock are integrated in a single breaker module. The module is supplied pretested and ready for installation. Ease of integration …

4

5

6

For the system builder, this means minimum project planning, ease of installation even with subsequent retrofitting, no more testing, simplified logistics – these features mean that NXACT is unbeatable, even with the overall cost of the substation. Its compact design minimizes installation and commissioning time. In operation, NXACT is notable for the clear layout of its control panel, which is always accessible at the front of the switchgear. Applications

7

common medium-voltage switchgear breakers for all switching duties in indoor installations ■ For switching all resistive, inductive and capacitive currents. Typical uses

9

10

Technical data

■ Universal circuit-breaker module for all ■ As three-pole medium-voltage circuit-

8

Fig. 106: NXACT vacuum circuit-breaker module, 12 kV

■ ■ ■ ■ ■ ■ ■

Overhead transmission lines Cables Transformers Capacitors Filter circuits* Motors Reactor coils

Rated voltage

[kV]

12


[kV]

28


[kV]

75

Rated frequency

[Hz]

50/60

Rated short-circuit breaking current (max.)

[kA]

25

Rated short-circuit making current (max.)

[kA]

63

Rated short-time withstand current 3 sec. (max.)

[kA]

25

Rated normal current

[A]

1250/2500

Fig. 107

* Filter circuits cause an increase in voltage at the series-connected switching device.

3/78


Medium-Voltage Devices Type NXACT

Features ■ Integrated, mechanical interlocks be-

1

tween operating mechanisms. ■ Integrated, mechanical switch position

■ ■ ■ ■

■

indications for circuit-breaker, withdrawable part and earthing switch function (optional). Easy to withdraw, since only withdrawable part is moved. Fixed interlocking of circuit-breaker module with a switchpanel is possible. Manual or motor operating mechanism (optional for the operating mechanisms). Enforced connection of low-voltage plug with the switchpanel, as soon as the module is installed in a panel. Maintenance-free operating mechanisms within scope of switching cycles.

2

3

4

5

6

Fig. 108

NXACT vacuum circuit-breaker module

7 Front view

Side view 188

200

517

8 275 730

140*

375

767

9

100

10 586 646

156

584 Operating mechanism for earthing switch

Dimensions in mm

* Travel

Fig. 109


3/79

Medium-Voltage Devices Type 3AF

1

2

3

4

5

Outdoor vacuum circuitbreakers type 3AF The Siemens outdoor vacuum circuitbreakers are structure-mounted, easy-toinstall vacuum circuit-breakers for use in systems up to 36 kV. The pole construction is a porcelain-clad construction similar to conventional outdoor high-voltage switchgear. The triple-pole circuit-breaker is fitted with reliable and well proven vacuum interrupters. Adequate phase spacing and height have been provided to meet standards and safety requirements. It is suitable for direct connection to overhead lines. The type design incorporates a minimum of moving parts and a simplicity of assembly assuring a long mechanical and electrical life. All the fundamental advantages of using vacuum interrupters like low operating energy, lightweight construction, virtually shock-free performance leading to ease of erection and reduction in foundation requirements, etc. have been retained. The Siemens outdoor vacuum circuitbreakers are designed and tested to meet the requirements of IEC 60 056/IS 13118.

Technical data Vacuum circuit-breaker type Rated voltage

[kV]

36

Rated frequency

[Hz]

50/60

Rated lightningimpulse withstand voltage

[kV]

170

Rated power-frequency withstand voltage (dry and wet)

[kV]

70

Rated short-circuit breaking current

[kA]

25


[kA]

63

Rated current

[A]

Side view

Advantages at a glance

7

■ ■ ■ ■ ■

High reliability Negligible maintenance Suitable for rapid autoreclosing duty Long electrical and mechanical life Completely environmentally compatible

1600

Fig. 111: Ratings for outdoor vacuum circuit-breakers

Front view

6

Type 3AF

1830 190

285

725

725

350

350

285

8

3045

9

2410 1810

10

450 650

1730 1930 Dimensions in mm Fig. 110: Outdoor vacuum circuit-breaker type 3AF for 36 kV

3/80

Fig. 112: Dimensions of outdoor circuit-breaker type 3AF for 36 kV


Medium-Voltage Devices Components, Type 3AY2

Components for vacuum circuitbreaker type 3AH

1

Vacuum circuit-breakers are available in fixed-mounted as well as withdrawable form. When they are installed in substations, isolating contacts, as well as fixed mating contacts and bushings are necessary. With the appropriate components, the 3AH vacuum circuit-breakers can be upgraded to the status of switchgear module.

2

3

Components The following components can be ordered: ■ Isolating contacts ■ Cup-type bushings with fixed mating contacts ■ Truck with/or without interlocks ■ Switchgear module (Dimensions as per Figs. 115 and 116)

Fig. 114: Switchgear module 12 kV, 25 kA, 1250 A

4 Front view

Side view

800

227

5

1019

Technical data and product range Components for 12 kV Up to 2500 A /to 40 kA /1 sec. For 800 mm switchgear panel width: With 3AH1 – 7.2/12 kV breaker 210 mm pole centre distance With 3AH5 – 12 kV breaker 210 mm pole centre distance

Components for 24 kV To 2500 A /to 25 kA /1 sec. For 1000 mm switchgear panel width: With 3AH1 – 24 kV breaker 275 mm pole centre distance With 3AH5 – 24 kV breaker 275 mm pole centre distance

6

945

7 Dimensions in mm Fig. 115: 12 kV switchgear module

8 Front view

On request: components for 15 kV

Side view 1000

295

1224

9

To 2500 A /to 40 kA /1 sec. For 800 mm switchgear panel width: With 3AH1 – 15 kV breaker 210 mm pole centre distance With 3AH5 – 17.5 kV breaker 210 mm pole centre distance

10 1030

Components for 36 kV To 1250 A /to 16 kA /1 sec. For 1200 mm switchgear panel width: With 3AH5 – 36 kV breaker 350 mm pole centre distance Fig. 113

Dimensions in mm Fig. 116: 24 kV switchgear module


3/81

Medium-Voltage Devices Type 3CG

1

2

3

4

5

6

Indoor vacuum switches type 3CG The 3CG vacuum switches are multipurpose switches conforming to IEC 60 265-1 and DIN VDE 0670 Part 301. With these, all loads can be switched without any restriction and with a high degree of reliability. The electrical and mechanical data are greater than for conventional switches. Moreover, the 3CG are maintenance free. The vacuum switch is therefore extremely economical. Vacuum switches are suitable for the following switching duties: ■ Overhead lines ■ Cables ■ Transformers ■ Motors ■ Capacitors ■ Switching under ground-fault conditions 3CG switches can be combined with HV HRC fuses up to 250 A. When installed in Siemens switchgear they comply with the specifications of IEC 60 420 and VDE 0670, Part 303. Maximum ratings of fuses on request.

7

Technical data Rated voltage U

[kV]

7.2

12

15

24

Rated lightning-impulse withstand voltage Ul,

[kV]

60

75

95

125

Rated short-circuit making current I ma

[kA]

50

50

50

40

Rated short-time current I m (3s)

[kA]

20

20

20

16

Rated normal current I n

[A]

800

800

800

800

Rated ring-main breaking current I c 1

[A]

800

800

800

800

Rated transformer breaking current

[A]

10

10

10

10

Rated capacitor breaking current

[A]

800

800

800

800

Rated cable-charging breaking current I c

[A]

63

63

63

63

Rated breaking current for stalled motors I d

[A]

2500

1600

1250

–

Transfer current according to IEC 60 420, [A] Inductive switching capacity (cosϕ ≤ 0.15)

5000

3000

2000

2000

630 63

630 63

630 63

630 63

63+800

63+800

63+800

63+800

10,000

10,000

10,000

10,000

Switching capacity under ground fault conditions: – Rated ground fault breaking current I e [A] – Rated cable-charging breaking [A] current – Rated cable charging breaking [A] current with superimposed load current Number of switching cycles with I n

8

Fig. 117: Ratings for vacuum switches type 3CG

9

10

Fig. 118: Vacuum switch type 3CG for 12 kV, 800 A

3/82


Medium-Voltage Devices Type 3CG

3CG, 7.2 and 12 kV

1 530 210

492 210

2

3 264

482

435

4

568

5

43 170

592 Dimensions in mm

6 3 CG, 24 kV

7

630 537 275

275

8

379

9

597 435

10

684 Dimensions in mm

708

43 170

Fig. 119: Dimensions of vacuum switch type 3CG (Examples)


3/83

Medium-Voltage Devices Type 3TL

1

2

3

4

5

6

7

8

Vacuum contactors Type 3TL The three-pole vacuum contactors type 3TL are for medium-voltage systems between 7.2 kV and 24 kV and incorporate a solenoid-operated mechanism for high switching frequency and unlimited closing duration.They are suitable for the operational switching of AC devices in indoor systems and can perform, for example, the following switching duties: ■ Switching of three-phase motors in AC-3 and AC-4 operation ■ Switching of transformers ■ Switching of capacitors ■ Switching of ohmic loads (e.g. arc furnaces) 3TL vacuum contactors have the following features: ■ Small dimensions ■ Long electrical life (up to 106 operating cycles) ■ Maintenance-free ■ Vertical or horizontal mounting The vacuum contactors comply with the standards for high-voltage AC contactors between 1 kV and 12 kV according to IEC Publication 60 470-1970 and DIN VDE 0660 Part 103. 3TL 6 and 3TL 8 contactors also comply with UL Standard 347. The vacuum contactors are available in different designs: ■ Type 3TL 6 with compact dimensions ■ Type 3TL 71 and 3TL 81 with slender design

220 mm

280 mm

375 mm 325 mm

390 mm

340 mm Fig. 120: Vacuum contactor type 3TL6 for fixed mounting

Fig. 121: Vacuum contactor type 3TL8 for fixed mounting

Technical data of the 3TL 6/7/8 vacuum contactor Vacuum contactor type

3TL 61

3TL 65

3TL 71

[kV] Rated normal voltage [Hz] Rated frequency [A] Rated normal current Switching capacity according to utilization category AC-4 (cos ϕ = 0.35) [A] Rated making current [A] Rated breaking current Mechanical life of contactor Switching cycles Mechanical life of vacuum interrupter Switching cycles Electrical life of vacuum interrupter (Rated normal current) Switching cycles

7.2 50/60 450

12 50/60 450

24 50/60 800

7.2 50/60 400

4500 3600

4500 3600

4500 3600

4000 3200

3 x 106

1 x 106

1 x 106

1 x 106

2 x 106

1 x 106

1 x 106

0.25 x 106

1 x 106

0.5 x 106

1 x 106

0.25 x 106

3TL 81

Fig. 122: Ratings for vacuum contactors type 3TL

9

10

3/84


Medium-Voltage Devices Type VS

Vacuum interrupters 1

Vacuum interrupters for the medium-voltage range are available from Siemens for all applications on the international market from 1 kV up to 40.5 kV.

2

Applications ■ ■ ■ ■ ■ ■ ■

Vacuum circuit-breakers Vacuum switches Vacuum contactors Transformer tap changers Circuit breakers for railway applications Autoreclosers Special applications, e.g. in nuclear fusion

3

4 Compact designs Siemens vacuum interrupters provide very high switching capacity in very compact dimensions: for example vacuum interrupters for 15 kV/40 kA with housing dimensions of 125 mm diameter by 161 mm length, or for 12 kV/13.1 kA with 68 mm diameter by 115 mm length. Consistant quality assurance Complete quality assurance (TQM and DIN/ISO 9001), rigorous material checking of every delivery and 100% tests of the interrupters for vacuum sealing assure reliable operation and the long life of Siemens vacuum interrupters. Environmental protection In the manufacture of our vacuum interrupters we only use environmentally compatible materials, such as copper, ceramics and high-grade steel. The manufacturing processes do not damage the environment. For example, no CFCs are used in production (fulfilling the Montreal agreement); the components are cleaned in a ultrasonic plant. During operation vacuum interrupters do not affect the environment and are themselves not affected by the environment.

5

Fig. 123: Vacuum interrupters from 1 kV up to 40.5 kV

6

Product range (extract) Interrupters for vacuum circuit-breakers Rated voltage Rated normal current Rated short-circuit breaking current

7 [kV] [A] [kA]

7.2

to 40.5

630

to 4000

12.5

to 80

8

Interrupters for vacuum contactors Rated voltage Rated normal current

[kV] [A]

1

to 24

400

to 800

9

Fig. 124a: Range of ratings for vacuum interrupters for CBs

10

Know-how for special applications If necessary, Siemens is prepared to supplement the wide standard program by way of tailored, customized concepts.


3/85

Medium-Voltage Devices Type 3CJ1

1

2

3

4

Switch disconnectors type 3CJ1 Indoor switch disconnectors type 3CJ1 are multipurpose types and meet all the relevant standards both as the basic version and in combination with (make-proof) grounding switches. The 3CJ1 indoor switch-disconnectors have the following features: ■ A modular system with all important modules such as fuses, (make-proof) grounding switches, motor operating mechanism, shunt releases and auxiliary switches ■ Good dielectric properties even under difficult climatic conditions because of the exclusive use of standard post insulators for insulation against ground ■ No insulating partitions even with small phase spacings ■ Simple maintenance and inspection

5 Fig. 125: Switch disconnector type 3CJ1

6

Technical data

7

Rated voltage

[kV]

12

15

24


[kA]

20

26

18


[kA]

50

65

45

[A]

630

630

630

8 Rated normal current

Fig. 126: Ratings for switch disconnectors type 3CJ1

9

10

3/86


Medium-Voltage Devices Type 3D

Disconnecting and grounding switches type 3D

1

Disconnecting and grounding switches type 3D are suitable for indoor installations from 12 kV up to 36 kV. Disconnectors are mainly used to protect personnel working on equipment and must therefore be very reliable and safe. This is assured even under difficult climatic conditions. Disconnecting and grounding switches type 3D are supplied with a manual or motor drive operating mechanism.

2

3

4

5 Fig. 127: Disconnecting switch type 3DC

6


[kV]

12

24

36

Rated short-time withstand current (1s)

[kA]

20 to 63

20 to 31.5

20 to 31.5


[kA]

50 to 160

50 to 80

50 to 80

630 to 2500

630 to 2500

630 to 2500

7

8


[A]

Fig. 128: Ratings for disconnectors type 3DC

9 Technical data Rated voltage

[kV]

Rated short-time withstand current (1s)

[kA]

Rated peak withstand current

[kA]

12

24

36

20 to 63

20 to 31.5

20 to 31.5

50 to 160

50 to 80

50 to 80

10

Fig. 129: Ratings for grounding switches type 3DE


3/87

Medium-Voltage Devices Type 3GD/3GH

1

2

3

4

5

6

7

HV HRC fuses type 3GD HV HRC (high-voltage high-rupturing-capacity) fuses are used for short-circuit protection in high-voltage switchgear. They protect switchgear and components, such as transformers, motors, capacitors, voltage transformers and cable feeders, from the dynamic and thermal effects of high shortcircuit currents by breaking them as they occur. The HV HRC fuse links can only be used to a limited degree as overload protection because they only operate with certainty when their minimum breaking current has already been exceeded. Up to this current the integrated thermal striker prevents a thermal overload on the fuse when used in circuit breaker/fuse combinations. Siemens HV HRC fuse links have the following features: ■ Use in indoor and outdoor installations ■ Nonaging because the fuse element is made of pure silver ■ Thermal tripping ■ Absolutely watertight ■ Low power loss With our 30 years of experience in the manufacture of HV HRC fuse links and with production and quality assurance that complies with DIN/ISO 9001, Siemens HV HRC fuse links meet the toughest demands for safety and reliability.

Fig. 130: HV HRC fuse type 3GD


[kV]

7.2

12

24

36

Rated short-circuit breaking current

[kA]

63 to 80

40 to 63

31.5 to 40

31.5

6.3 to 250

6.3 to 160

6.3 to 100

6.3 to 40


[A]

Fig. 131: Ratings for HV HRC fuse links type 3GD

Fuse-bases type 3GH 8

9

3GH fuse bases are used to accomodate HV HRC fuse links in switchgear. These fuse bases are suitable for: ■ Indoor installations ■ High air humidity ■ Occasional condensation 3GH HV HRC fuse bases are available as single-phase and three-phase versions. On request, a switching state indicator with an auxiliary switch can be installed.

10

Fig. 132: Fuse bases type 3GH with HV HRC fuse links


[kV]

3.6/7.2

12

24

36

Peak withstand current

[kA]

44

44

44

44

[A]

400

400

400

400

Rated current

Fig. 133: Ratings for fuse bases type 3GH

3/88


Medium-Voltage Devices Insulators and Bushings

Insulators: Post insulators type 3FA and bushings type 3FH/3FM Insulators (post insulators and bushings) are used to insulate live parts from one another and also fulfill mechanical carrying and supporting functions. The materials for insulators are various cast resins and porcelains. The use of these materials, which have proved themselves over many years of exposure to the roughest operating and ambient conditions, and the high quality standard to DIN/ISO 9001 assure the high degree of reliability of the insulators. Special ribbed forms ensure high electrical strength even when materials are deposited on the surface and occasional condensation is formed. Post insulators and bushings are manufactured in various designs for indoor and outdoor use depending on the application. Innovative solutions, such as the 3FA4 divider post insulator with an integrated expulsion-type arrester, provide optimum utility for the customer. Special designs are possible if requested by the customer.

1

2

3

4

5 Fig. 135: Post insulators type 3FA1/2

Technical data

6

Rated voltage

[kV]

3.6

12

24

36

Lightning-impulse withstand voltage

[kV]

60 to 65

65 to 90

100 to 145

145 to 190


[kV]

27 to 40

35 to 50

55 to 75

75 to 105

Minimum failing load

[kN]

3.75 to 16

3.75 to 25

3.75 to 25

3.75 to 16

7

8

Fig. 136: Ratings for post insulators type 3FA1/2

9

L

U1

C1

L Conductor U Operating voltage U1 Partial voltage across C1 U2 Partial voltage across C2 and indicator

M

U U2

V

C2

A

C1 Coupling capacitance C2 Undercapacitance V Arrester A Indicator M Measuring socket

Fig. 134: Draw-lead bushing type 3FH5/6

Fig. 137: The principle of capacitive voltage indication with the 3FA4 divider post insulator


3/89

10

Medium-Voltage Devices Type 4M and Type 3E

1

2

3

4

5

Current and voltage transformers type 4M Measuring transformers are electrical devices that transform primary electrical quantities (currents and voltages) to proportional and in-phase quantities which are safe for connected equipment and operating personnel. The indoor post insulator current and voltage transformers of the block type have DIN-conformant dimensions and are used in air-insulated switchgear. A maximum of operational safety is assured even under difficult climatic conditions by the use of cycloalyphatic resin systems and proven cast-resin technology. Special customized versions (e.g. up to 3 cores for current transformers, switchable windings, capacitance layer for voltage indication) can be supplied on request. The program also includes cast-resin insulated-bushing current transformers and outdoor current and voltage transformers.

Fig. 138: Block current transformer type 4MA

Technical data Current transformers

Voltage transformers

Rated voltage

[kV]

12

24

36

Primary rated current

[A]

10 to 2500

10 to 2500

10 to 2500

80

80

80

Max. thermal rated [kA] short time current

6

Fig. 139: Outdoor voltage transformer type 4MS4

Sec. thermal limit current

[A]

12

24

36

5 to 10

5 to 13

8 to 17

Fig. 140: Ratings for current and voltage transformers

7 Surge arresters type 3E 8

9

10

Surge arresters have the function of protecting the insulation of installations or components from impermissible strain due to voltage surges. The product range includes: ■ Surge arresters for the protection of high-voltage motors and dry-type transformers. Range 3EF for cable networks up to 15 kV. ■ Plug-in surge arresters for the protection of distribution networks. Range 3EH2 for networks up to 42 kV. ■ Special arresters for the protection of rotary machines and furnaces. Range 3EE2 for networks up to 42 kV.

Fig. 141: Surge arrester type 3EE2

Technical data and product range 3EF

3EH2

3EE2

For networks of

[kV]

3.6 to 15

4.7 to 42

4.5 to 42

Rated discharge surge current

[kA]

1

10

10

Short-circuit current strength

[kA]

1 to 40

16

50 to 300

Fig. 142

3/90


Low-Voltage Switchboards SIVACON

Contents

Page

Introduction .................................... 4/2 Advantages .................................... 4/2 Technical data ............................... 4/3 Cubicle design ............................... 4/4 Busbar system ............................... 4/5 Installation designs ...................... 4/6 Circuit-breaker design ................. 4/6 Withdrawable-unit design .......... 4/7 In-line plug-in design ................. 4/13 In-line-type plug-in design 3NJ6 ................................. 4/14 Fixed-mounted design ................ 4/15 Communication with PROFIBUS®-DP ........................... 4/16 Frame and enclosure ................. 4/17 Forms of internal separation .... 4/18 Installation details ...................... 4/19

4

Low-Voltage Switchboards

Introduction 1

2

3

Low-voltage switchboards form the link between equipment for generation, transmission (cables, overhead lines) and transformation of electrical energy on the one hand, and the loads, such as motors, solenoid valves, actuators and devices for heating, lighting and air conditioning on the other. As the majority of applications are supplied with low voltage, the low-voltage switchboard is of special significance in both public supply systems and industrial plants.

Reliable power supplies are conditional on good availability, flexibility for processrelated modifications and high operating safety on the part of the switchboard. Power distribution in a system usually comes via a main switchboard (power control center or main distribution board) and a number of subdistribution boards or motor control centers (Fig. 1).

4

5

up to 4 MVA up to 690 V

Cable or busbar system

up to 6300 A

Incoming circuit-breaker

6

Main switchboard

LT

3-50 Hz

Circuit-breakers as feeders to the subdistribution boards

up to 5000 A

General The SIVACON low-voltage switchboard is an economical, practical and type-tested switchgear and controlgear assembly (Fig. 3), used for example in power engineering, in the chemical, oil and capital goods industries and in public and private building systems. It is notable for its good availability and high degree of personnel and system safety. It can be used on all power levels up to 6300 A: ■ As main switchboard (power control center or main distribution board) ■ As motor control centre ■ As subdistribution board. With the many combinations that the SIVACON modular design allows, a wide range of demands can be met both in fixed-mounted plug-in and in withdrawableunit design. All modules used are type-tested (TTA), i.e they comply with the following standards: ■ IEC 60439-1 ■ DIN EN 60439-1 ■ VDE 0660 Part 500 also ■ DIN VDE 0106 Part 100 ■ VDE 0660 Part 500, supplement 2, IEC 61641 (arcing faults) Certification DIN EN ISO 9001

Connecting cables

7 ST

ET

8

up to 630 A

Advantages of a SIVACON switchboard

FT

■ Type-tested standard modules ■ Space-saving base areas from

up to 630 A

up to 100 A

400 x 400 mm ■ Solid wall design for safe cubicle-

9

up to 630 A

Subdistribution board e. g. services (Lighting, heating, air conditioning, etc.)

up to 100 A

to-cubicle separation ■ High packing density with

up to 40 feeders per cubicle ■ Standard operator interface for all

withdrawable units ■ Test and disconnected position

M

10

M

M

M

Motor control center 1 in withdrawable-unit design for production/ manufacturing

LT ET FT ST

M

M

M

M

Motor control center 2 in withdrawable-unit design for production/ manufacturing

= Circuit-breaker design = Withdrawable-unit design = Fixed-mounted design = Plug-in design

with door closed

up to 100 A

■ Visible isolating gaps and points

of contact

Control

■ Alternative busbar positioning

at top or rear ■ Cable/bar connection from above

or below

Fig. 1: Typical low-voltage network in an industrial plant

4/2



Technical data at a glance 1 Rated insulation voltage (Ui)

1000 V

Rated operational voltage (Ue)

up to

690 V

up to up to up to

6300 A 250 kA 100 kA

2

Busbar currents (3- and 4-pole): Horizontal main busbars Rated current Rated impulse withstand current (Ipk) Rated short-time withstand current (Icw) Vertical busbars

3

for circuit-breakers design

4

See horizontal main busbars for fixed-mounted design / plug-in design Rated current Rated impulse withstand current (Ipk) Rated short-time withstand current (Icw)

up to 2000 A up to 110 kA up to 50 kA*

5

up to 1000 A up to 143 kA up to 65 kA*

6

for withdrawable-unit design Rated current Rated impulse withstand current (Ipk) Rated short-time withstand current (Icw) Device rated Circuit-breakers Cable feeders Motor feeders

up to up to up to

Power loss per cubicle with combination of various cubicles (Pv) Degree of protection to IEC 60529, EN 60529

6300 A 1600 A

7

630 A

approx. 600 W** IP 20 up to IP 54

* Rated conditional short-circuit current Icc up to 100 kA ** Mean value at simultaneity factor of all feeders of 0.6

8

Fig. 2

1

2

3

4

9

1 Circuit-breaker-design cubicle with withdrawable circuit-breaker 3WN, 1600 A

2 Withdrawable-unit-design cubicle

10

with miniature and normal withdrawable units up to 250 kW

3 Plug-in design cubicle with in-line modules and plug-in fuse strips 3NJ6

4 Fixed-mounted-design cubicle with modular function units

Fig. 3: SIVACON low-voltage switchboard


4/3


Cubicle design 1

2

3

4

5

6

7

The cubicle is structured in modular grid based on one modular spacing (1 M) corresponding to 175 mm. The effective device installation space with a height of 1750 mm therefore represents a height of 10 M. The top and bottom space each has a height of 225 mm (Fig. 5). A cubicle is subdivided into four function compartments: ■ Busbar compartment ■ Device compartment ■ Cable connection compartment ■ Cross-wiring compartment In 400 mm deep cubicles, the busbar compartment is at the top; in 600 mm deep cubicles it is at the rear. In double-front systems (1000 mm depth) and in a power control center (1200 mm depth), the busbar compartment is located centrally. The switching device compartment accommodates switchgear and auxiliary equipment. The cable connection compartment is located on the right-hand side of the cubicle. With circuit-breaker design, however, it is below the switching device compartment (Fig. 4). The cross-wiring compartment is located at the top front and is provided for leading control and loop lines from cubicle to cubicle.

400

600 400

600

400 400 400

8

9

10 Busbar compartment Device compartment

Cable connection compartment Cross-wiring compartment

Dimensions in mm

Fig. 4: Cubicle design

4/4



Busbar system Together with the PEN or PE busbars, and if applicable the N busbars, the phase conductor busbars L1, L2 and L3 form the busbar system of a switchboard. One or more distribution buses and/or incoming and outgoing feeders can be connected to a horizontal main busbar. Depending on requirements, this main busbar passes through several cubicles and can be linked with another main busbar via a coupling. A vertical distribution busbar is connected with the main busbar and supplies outgoing feeders within a cubicle. In a 400 mm deep cubicle (Fig. 5a) the phase conductors of the main busbar are always at the top; the PEN or PE and N conductors are always at the bottom. The maximum rated current at 35 °C is 1965 A (non-ventilated), and 2250 A (ventilated); the maximum short-circuit strength is Ipk = 110 kA or Icw = 50 kA, respectively. In single-front systems with 600 mm cubicle depth (Fig. 5b), the main busbars are behind the switching device compartment. In double-front systems of 1000 mm depth (Fig. 5c), they are between the two switching device compartments (central). The phase conductors can be arranged at the top or bottom; PEN, PE and N conductors are always at the bottom. The maximum rated current is at 35 °C 3250 A (non-ventilated) or 3500 A (ventilated); Ipk = 250 kA or Icw = 100 kA, respectively. In 1200 mm deep systems (power control center) (Fig. 5d) the conductors are arranged as for double-front systems, but in duplicate; the phase conductors are always at the top. The maximum rated current at 35 °C is 4850 A (non-ventilated) or 6300 A (ventilated); Ipk = 220 kA, Icw = 100 kA.

1 Top space

Switching device compartment

2 225

225

3 10 x 175

10 x 175

2200

4

225

225

5

200 400

400

Bottom space a)

b)

6

7 225

225

8 10 x 175

2200

10 x 175

2200

9 225

225

400 200 400

c)

400

400

400

10

d)

Dimensions in mm

Fig. 5: Modular grid and location of main busbars


4/5


Installation designs 1

2

3

4

5

6

7

The following designs are available for the duties specified: ■ Circuit-breaker design ■ Withdrawable-unit design ■ Plug-in design ■ Fixed-mounted design

Circuit-breaker design Distribution boards for substantial energy requirements are generally followed by a number of subdistribution boards and loads. Particular demands are therefore made in terms of long-term reliability and safety. That is to say, ”supply“, ”coupling“ and ”feeder“ functions must be reliably available over long periods of time. Maintenance and testing must not involve long standstill times. The circuit-breaker design components meet these requirements. The circuit-breaker cubicles have separate function spaces for a switching device compartment, auxiliary equipment compartment and cable/busbar connection compartment (Fig. 7). The auxiliary equipment compartment is above the switching device compartment. The cable or busbar connection compartment is located below. With supply from above, the arrangement is a like a mirror image. The cubicle width is determined by the breaker rated current.

8

9

Breaker rated current [A]

Cubicle width

IN to 1600 IN to 2500 IN to 3200 IN to 6300

400/500 600 800 1000

[mm]

Fig. 6

Circuit-breaker design 3WN

10

The 3WN circuit-breakers in withdrawableunit or fixed-mounted design are used for incoming supply, outgoing feeders and couplings (longitudinal and transverse). The operational current can be shown on an LCD display in the control panel; there is consequently no need for an ammeter or current transformer.

4/6

Fig. 7: Circuit-breaker cubicle with withdrawable circuit-breaker 3WN, 1600 A rated current

The high short-time current-carrying capacity for time-graded short-circuit protection (up to 500 ms) assures reliable operation of sections of the switchboard not affected by a short circuit. With the aid of short-time grading control for very brief delay times (50 ms), the stresses and damage suffered by a switchboard in the event of a short-circuit can be substantially minimized, regardless of the preset delay time of the switching device concerned. The withdrawable circuit-breaker has three positions between which it can be moved with the aid of a crank or spindle mechanism. In the connected position the main and auxiliary contacts are closed.

In the test position the auxiliary contacts are closed. In the disconnected position both main and auxiliary contacts are open. Mechanical interlocks ensure that, in the process of moving from one position to another, the circuit-breaker always reaches the OPEN state or that closing is not possible when the breaker is between two positions. The circuit-breaker is always moved with the door closed. The actual position in which it is can be telecommunicated via a signaling switch. A kit, switch or withdrawable unit can be used for grounding and short-circuiting.



Withdrawable-unit design A major feature of withdrawable-unit design is removability and ease of replacement of equipment combinations under operating conditions, i.e. a switchboard can be adapted to process-related modifications without having to be shut down. Withdrawable-unit design is used therefore mainly for switching and control of motors (Fig. 8). Withdrawable units

A distinction is made between miniature (sizes 1/4 and 1/2) and normal withdrawable units (sizes 1, 2, 3 and 4) (Fig. 9). The normal withdrawable unit of size 1 has a height of one modular spacing (175 mm) and can, with the use of a miniature withdrawable unit adapter, be replaced by 4 withdrawable units of size 1/4 or 2 units of size 1/2. The withdrawable units of sizes 2, 3 and 4 have a height of 2, 3 and 4 modular spacings, respectively. The maximum complement of a cubicle is, for example, 10 full-size withdrawable units of size 1 or 40 miniature withdrawable units of size 1/4 .

1

2

3

The equipment of the main circuit of an outgoing feeder and the relevant auxiliary equipment are integrated as a function unit in a withdrawable unit, which can be easily accommodated in a cubicle. In basic state, all equipment and movable parts are within the withdrawable unit contours and thereby protected from damage. The facility for equipping the withdrawable units from the rear allows plenty of space for auxiliary devices. Measuring instruments, indicator lights, pushbuttons, etc. are located on a hinged instrument panel, such that settings (e.g. on the overload relay) can be easily performed during operation.

4

5

6

7

8

9

10

Fig. 8: High packing density with up to 40 feeders per cubicle

Fig. 9: SIVACON withdrawable units size 1, size 1/4 and 1/2


4/7


Moving isolating contact system

1

L3 L2 L1 N

Connected position

L3 L2 L1 N

Disconnected position

2

3

4

5

6 L3 L2 L1 N

7

For main and auxiliary circuits the withdrawable units are equipped with a moving isolating contact system. It has contacts on both the incoming and outgoing side; they can be moved by handcrank such that they come laterally out of the withdrawable unit and engage with the fixed contacts in the cubicle. On miniature withdrawable units the isolating contact system moves upwards into the miniature withdrawable unit adapter. A distinction is made between connected, disconnected and test position (Fig. 10). In the connected position both main and auxiliary contacts are closed; in the disconnected position they are open. The test position allows testing of the withdrawable unit for proper function in no-load (cold) state, in which the main contacts are open, but the auxiliary contacts are closed for the incoming control voltage. In all three positions the doors are closed and the withdrawable unit mechanically connected with the switchboard. This assures optimal safety for personnel and the degree of protection is upheld. Movement from the connected into the test position and vice-versa always passes through the disconnected position; this assures that all contactors drop out. Operating error protection Integrated maloperation protection in each withdrawable unit reliably prevents moving of the isolating contacts with the main circuit-breaker ”CLOSED“ (handcrank cannot be attached) (Fig. 11).

Test position

8 Fig. 10: Withdrawable-unit principle

9

10

Fig. 11: Operating error protection prevents travel of the isolating contacts when the master switch is “ON”

4/8



Indicating and signaling

AZNV

Test

AZNV/Test 21

- S21 - X19

- X19

- X19

22

21

21

- Q1

- S21

- Q1

Compt.

- S21

- S20

22

WU

COM

WU

The current position of a withdrawable unit is clearly indicated on the instrument panel. Such signals as ”feeder not available“ (AZNV), ”test“ and ”AZNV and test“ can be given by additional alarm switches. The alarm switch in the compartment (S21) is a limit switch of NC design; that in the withdrawable unit (S20) is of NO design. Both are actuated by the main isolating contacts of the withdrawable unit (Fig. 12).

WU

2

3

22 AZNV

Compt.

1

Test Compt.

4 X19 = Auxiliary isolating contact S20 = Alarm switch in withdrawable unit* S21 = Alarm switch in compartment* WU = Withdrawable unit Compt. = Compartment

5

*actuated by main isolating contact

Main isolating contact

Aux. isolating contact

6

7 In withdrawable unit - S 20 1 NO

In compartment - S 21 1 NC

8 Connected

9 * Disconnected

10 Test

*No signal, as auxiliary isolating contact open Fig. 12: Circuitry and position of main and auxiliary contacts


4/9


Vertical distribution bus (plug-on bus)

1

2

The vertical plug-on bus with the phase conductors L1, L2 and L3 is located on the left-hand side of the cubicle and features safe-to-touch tap openings (Fig. 13). The vertical PE, PEN and N busbars are on the right-hand side of the cubicle in a separate, 400 mm wide cable connection compartment, equipped with variable cable brackets.

3

4

Fig. 13: Arcing fault-protected plug-on bar system embedded in the left of the cubicle

5 Rated currents – fused and withdrawable unit sizes of cable feeders

Device

Rated current

Type

[A]

D306 3KL50 3KL52 3KL53 3KL55 3KL57 3KL61

35 63 125 160 250 400 630

1/4 / 1/2 1 1 2 2 2 3

Device

Rated current

Withdrawable unit size

Type

[A]

3RV101 3RV102 3RV103 3RV104 3VF3 3VF4 3VF5 3VF6

12 25 50 160 160 250 400 630

6

7

8

9

Rated currents – non-fused and withdrawable unit sizes of cable feeders

10 I


1/4 / 1/2 1/4 / 1/2 / 1 1/2 / 1 1 1 2 2 4

Fig. 14

4/10



Power ratings – fused and withdrawable unit sizes of motor feeders

1

FVNR

FVR

Star-delta starters

2

3

4

5 Full-voltage non-reversing (FVNR) motor starters Normal-duty start [kW]

Full-voltage non-reversing (FVNR) motor starters Heavy-duty start [kW]

Full-voltage reversing (FVR) motor starters Reversing circuit [kW]

Star-delta starters [kW]

400 V

500 V

690 V

400 V

500 V

690 V

400 V

500 V

690 V

400 V

500 V

690 V

11 18.5 22 75 160 250 – –

11 22 22 90 200 355

11 22 37 90 160 500

7.5 15 22 45 90 160 – –

7.5 15 30 55 132 200

11 22 37 90 132 375

5.5 18.5 22 45 110 250 – –

5.5 22 22 55 132 315

5.5 22 22 55 160 375

– – 30 55 132 – 250 355

– – 37 75 160 – 315 355

– – 55 90 160 – 400 500


6

1/4 1/2 1 2 3 4 3+3 4+4

7

8

Fig. 15

9

10


4/11


1

Power ratings – non-fused with overload relay and withdrawable unit sizes of motor feeders

FVNR

FVR

Star-delta starters

2

3

I

I

I

4

5 Coordination type 1

6

7

8

Full-voltage non-reversing (FVNR) motor starters Normal-duty start [kW]




400 V

500 V

690 V

400 V

500 V

690 V

400 V

500 V

690 V

400 V

500 V

690 V

11 18.5 22 75 160 250

11

– – – – – –

4 11 11 37 132 160

3 15 15 45 160 200

– – – – – –

5.5

5.5 11 30 90 200 315

– – – – – –

– – 22 55 110 200

– – 30 75 132 250

– – – – – –

18.5 30 90 200 250

11 22 75 160 250


1/4 1/2 1 2 3 4

Coordination type 2

9

10





400 V

500 V

690 V

400 V

7.5 18.5 22 75 160 250

7.5 18.5 30 90 200 315

– – – – –

4 11 11 37 132 160


500 V

690 V

400 V

500 V

690 V

400 V

500 V

690 V

0.37 11 15 45 160 200

– – – – – –

0.55 7.5 22 55 160 250

0.75 7.5 30 75 200 315

– – – – – –

– – 22 55 110 160

– – 30 75 132 100

– – – – – –

1/4 1/2 1 2 3 4

Fig. 16

4/12



In-line plug-in design The in-line plug-in design represents a lowpriced alternative to both the classic fixedmounted and the convenient withdrawable unit design. By virtue of the supply-side plug-in contact, the modules provide the facility for quick interchangeability without the switchboard having to be isolated. This design is therefore used wherever changing requirements are imposed on operation, if for example motor ratings have to be changed or new loads connected. In-line plug-in modules, a cost-effective, compact design for: ■ Load outgoing feeders up to 45 kW ■ 3RV outgoing circuit-breaker units up to 100 A The modules are fitted with the new SIRIUSTM 3R switching devices. The compact overall width of the SIRIUS 3R devices, as well as the facility for lining them up with connecting modules, are particulary noticeable in the extremely narrow construction of the in-line modules. A lateral guide rail in the cubicle facilitates handling when replacing a module and at the same time ensures positive contact with the plug-in bus system.

Rated currents – non fused and modulheight of cable feeders

1 Rated current

Modulheight

Type

[A]

[mm]

3RV101 3RV102 3RV103 3RV104

12 25 50 100

50 50 100 100

Device

I

2

3

Fig. 18

4

Power ratings – non-fused with overload relay and module height of motor feeders

FVNR

FVR

5

I

6

I

7

Coordination type 1



400 V 11 45 –

400 V – 11 45

Modulheight [mm]

9

50 100 200

Coordination type 2

Fig. 17: In-line plug-in design combined with plug-in fuse strips 3NJ6

10



400 V 7.5 45 –

400 V – 7.5 45

Modulheight [mm]

50 100 200

Fig. 19


8

4/13


In-line-type plug-in design 3NJ6 1

2

3

4

5

6

7

8

9

In-line-type switching devices allow spacesaving installation of cable feeders in a cubicle and are particularly notable for their compact design (Fig. 20). The in-line-type switching devices feature plug-in contacts on the incoming side. They are alternatively available for cable feeders up to 630 A as: ■ Fuse module ■ Fuse-switch disconnectors (single-break) ■ Fuse-switch disconnectors (double-break) with or without solid-state fuse monitoring ■ Switch disconnectors

The single- or double-break in-line-type switching devices allow fuse changing in dead state. The main switch is actuated by pulling a vertical handle to the side. The modular design allows quick reequipping and easy replacement of in-line-type switching devices under operating conditions. The in-line-type switching devices have a height of 50 mm, 100 mm or 200 mm. A cubicle can consequently be equipped with up to 35 in-line-type switching devices. Vertical distribution bus (plug-on bus) The vertical plug-on bus with the phase conductors L1, L2 and L3 is located at the back in the cubicle and can be additionally fitted with a shock-hazard protection. The vertical PE, PEN and N busbars are on the right-hand side of the cubicle in a separate, 400 mm wide cable connection compartment, equipped with variable cable brackets.

Fig. 20: Cubicle with in-line-type switching devices

Fuse-switch disconnector (single break)

10

Device

Rated current

In-linetype size

Type

[A]

Height [mm]

3NJ6110

160

50

3NJ6120

250

100

3NJ6140

400

200

3NJ6160

630

200

Fig. 21: Rated currents and installation data of in-line-type switching devices

4/14



Fixed-mounted design 1

In certain applications, e.g. in building installation systems, either there is no need to replace components under operating conditions or short standstill times do not result in exceptional costs. In such cases the fixed-mounted design (Fig. 22) offers excellent economy, high reliability and flexibility by virtue of: ■ Any combination of modular function units ■ Easy replacement of function units after deenergizing the switchboard ■ Brief modification or standstill times by virtue of lateral vertical cubicle busbars ■ Add-on components for subdivision and even compartmentalization in accordance with requirements.

2

3

4

Modular function units

5

The modular function units enable versatile and efficient installation, above all whenever operationally required changes or adaptations to new load data are necessary (Fig. 23). The subracks can be equipped as required with switching devices or combinations thereof; the function units can be combined as required within one cubicle. When the function modules are fitted in the cubicle they are first attached in the openings provided and then bolted to the cubicle. This securing system enables uncomplicated ”one-man assembly“.

6

7

Vertical distribution bus (cubicle busbar) The vertical cubicle busbar with the phase conductors L1, L2 and L3 is fastened to the left-hand side wall of the cubicle and offers many connection facilities (without the need for drilling or perforation) for cables and bars. It can be subdivided at the top or bottom once per cubicle (for group circuits or couplings). The connections are easily accessible and therefore equally easy to check. A transparent shock-hazard protection allows visual inspection and assures a very high degree of personnel safety. The vertical PE, PEN and N busbars are on the right-hand side of the cubicle in a separate, up to 400 mm wide cable connection compartment, equipped with variable cable brackets.

8 Fig. 22: Variable fixed-mounted design

9

10

Fig. 23: Fused modular function unit with direct protection, 45 kW


4/15


1

2

3

4

Communication with PROFIBUS® -DP With SIMOCODE®-DP for motor and cable feeders and the interface DP/3WN for circuit-breakers type 3WN, SIVACON offers an economical possibility of exchanging data with automation systems. The widespread standardized, cross-manufacturer-PROFIBUS®-DP serves as the bus system, offering links to a very diverse range of programmable controllers. ■ Easy installation planning ■ Saving in wiring Communication-capable circuit-breaker 3WN (Fig. 25) ■ Remote-control for opening and closing ■ Remote diagnostics for preventive main-

tenance

5

6

■ Signalling of operating states ■ Transmission of current values e.g. for

Fig. 25: 3WN circuit-breaker

Fig. 26: SIMOCODE-DP in size 1/4 withdrawable unit

Fig. 27: AS-interface modules 41

power management Communication-capable motor protection and control device SIMOCODE-DP (Fig. 26) ■ ■ ■ ■

7

Fig. 24

Integrated full motor protection Extensive control functions Convenient diagnostics possibilities Autonomous operation of each feeder via an operator control block

AS-interface (Fig. 27) ■ Status messages via AS-I modules

8

(On/Off/Control)

9

10

4/16



Frame and enclosure The galvanized SIVACON cubicle frames are of solid wall design and ensure reliable cubicle-to-cubicle separation. The enclosure is made of powder-coated steel sheets (Fig. 28 and 29). A cubicle front features one or more doors, depending on requirements and cubicle type. These doors are of 2 mm thick, powder-coated sheet steel and are hinged on the right or left (attached to the frame). Spring-loaded door locks prevent the doors from flying open unintentionally, and also ensure safe pressure equalization in the event of an arcing fault.

1

Top busbar system

2

3

4

Degree of protection (against foreign bodies/water, and personnel safety) A distinction is made between ventilated and non-ventilated cubicles. Ventilated cubicles are provided with slits in the base space door and in the top plate and attain degree of protection in relation to the operating area of IP 20/21 or IP 40/41, respectively. Non-ventilated cubicles attain degree of protection IP 54. In relation to the cable compartment, degree of protection IP 00 or IP 40, is generally attained.

5 Rear busbar system

6 Fig. 28: Rear and top busbar system

Fig. 29: Device compartment can be separated from interconnected busbar

7

Cubicle dimensions and average weights

Height [mm]

Width [mm]

Depth [mm]

500 600 500 600 600 800 1000 1000

400

Rated current [A]

Approx. weight [kg]

up to 1600 up to 2000 up to 1600 up to 1600 up to 2500 up to 3200 up to 4000 up to 6300

285 390 325 335 440 540 700 1200

Circuit-breaker design 2200

8 600

1200

9

Withdrawable-unit design/plug-in design 2200

10

1000

400 600 1000

420 480 690

1000

400 600 1000

320 380 550

Fixed-mounted design 2200

Fig. 30: Cubicle dimensions and average weights


4/17


Form of internal separation 1

Form 1 In accordance with IEC 60439-1, (Fig. 32) Depending on requirements, the function compartments can be subdivided as per the following table:

Functional unit

1

2

3

4

4

4 4

Form 1 2a 2b 3a 3b 4a 4b

4

5

1 2 3 4

4

2

3

2

Terminal for external conductors Main busbar Busbar Incoming circuit Outgoing circuit

4 4

Circuitbreaker design Withdrawableunit design

Form 2a

Form 2b

1

2

1

2

2

4

Plug-in design – 3 NJ6 – In-line

3

4

2 4

4

4

3

4

4

4

4

4 4

6

7

Fixedmounted design – Modular – Compensation Fig. 31

4

4

4

Form 3a

Form 3b

1

2

1

2

2

4 3

4

2 4

4

4

3

4

4

4

4

4

8

4

4

4

4

9 Form 4a

Form 4b

1

2

10

1

2

2

4 3

4

4

4

2 4

4

3

4

4

4 4

4 4

4 4

Fig. 32: Forms of internal separation to IEC 60439-1

4/18



Installation details

Floor penetrations

Transport units

The cubicles feature floor penetrations for leading in cables for connection, or for an incoming supply from below (Fig. 35).

For transport purposes, individual cubicles of a switchboard are combined to form a transport unit, up to a maximum length of 2400 mm. The transport base is 200 mm longer than the transport unit and is 190 mm high. The transport base depth is:

Cubicle depth 400 mm 25

[mm]

Transport base depth [mm]

400

600 1000 1200

2

Diameter 14.1

323

Cubicle depth

1

400

215

3

75

38.5 Cubicle width - 100

900 1050 1460 1660

4

Cubicle width Fig. 33

Cubicle depth 600 mm If the busbar is at the top, the main busbars between two transport units are connected via lugs which are bolted to the busbar system. If the busbar is at the rear, the individual bars can be bolted together via connection elements, as the conductors of the right-hand transport unit are offset to the left and protrude beyond the cubicle edge. Mounting

25

Diameter 14.1

523 323

6

250 600 75

38.5

Cubicle depths 400 mm and 600 mm: ■ Wall- or ■ Floor-mounting Cubicle depths 1000 mm and 1200 mm: ■ Floor-mounting The following minimum clearances between the switchboard and any obstacles must be observed:

5

Cubicle width - 100

7

Cubicle width

Cubicle depth 1000 mm, 1200 mm 25

8

Diameter 14.1 75

Clearances

250

9 100 mm

75 mm

100 mm

1000 or 1200

Cubicle depth - 77

Switchboard

75

38.5 Fig. 34

10

250

Cubicle width - 100 Cubicle width

There must be a minimum clearance of 400 mm between the top and sides of the cubicle and any obstacles.

Free space for cables and bar penetrations Fig. 35: Floor penetrations


4/19


Operating and maintenance gangways All doors of a SIVACON switchboard can be fitted such that they close in the direction of an escape route or emergency exit. If they are fitted differently, care must be taken that when doors are open, there is a minimum gangway of 500 mm (Fig. 36). In general, the door width must be taken into account, i.e. a door must open through at least 90°. (In circuit-breaker and fixedmounted designs the maximum door width is 1000 mm.) If a lifting truck is used to install a circuitbreaker, the gangway widths must suit the dimensions of the lifting truck.

1

2

20001)

3

600

4

700

700

600 700

700

Dimensions of lifting truck [mm] 1)

Minimum gangway height under covers or enclosures

Height Width Depth

5

2000 680 920

Minimum gangway width [mm] Approx.

6

1500

Fig. 37

7 Min. gangway width Escape route 600 or 700 mm

Free min. width 500 mm1)

2)

8

9

10

1) Where

switchboard fronts face each other, narrowing of the gangway as a result of open doors (i.e. doors that do not close in the direction of the escape route) is reckoned with only on one side 2) Note door widths, i.e. it must be possible to open the door through at least 90° Dimensions in mm

Fig. 36: Reduced gangways in area of open doors

4/20

For further information please contact: Fax: ++ 49 - 3 41- 4 47 04 00 www.ad.siemens.de


Transformers

Contents

Page

Introduction ....................................... 5/2 Product Range .................................. 5/3 Electrical Design .............................. 5/4 Transformer Loss Evaluation ......... 5/6 Mechanical Design ......................... 5/8 Connection Systems ....................... 5/9 Accessories and Protective Devices ........................ 5/11 Technical Data Distribution Transformers ............ 5/13 Technical Data Power Transformers ...................... 5/18 On-load Tap Changers .................. 5/26 Cast-resin Dry-type Transformers, GEAFOL .................. 5/27 Technical Data GEAFOL Cast-resin Dry-type Transformers .................. 5/31 Special Transformers .................... 5/35

5 Ohne Namen-1

1

22.09.1999, 16:22 Uhr

Introduction

1

2

3

4

5

6

Transformers are one of the primary components for the transmission and distribution of electrical energy. Their design results mainly from the range of application, the construction, the rated power and the voltage level. The scope of transformer types starts with generator transformers and ends with distribution transformers. Transformers which are directly connected to the generator of the power station are called generator transformers. Their power range goes up to far above 1000 MVA. Their voltage range extends to approx. 1500 kV. The connection between the different highvoltage system levels is made via network transformers (network interconnecting transformers). Their power range exceeds 1000 MVA. The voltage range exceeds 1500 kV. Distribution transformers are within the range from 50 to 2500 kVA and max. 36 kV. In the last step, they distribute the electrical energy to the consumers by feeding from the high-voltage into the low-voltage distribution network. These are designed either as liquid-filled or as dry-type transformers. Transformers with a rated power up to 2.5 MVA and a voltage up to 36 kV are referred to as distribution transformers; all transformers of higher ratings are classified as power transformers.

7

In addition, there are various specialpurpose transformers such as converter transformers, which can be both in the range of power transformers and in the range of distribution transformers as far as rated power and rated voltage are concerned. As special elements for network stabilization, arc-suppression coils and compensating reactors are available. Arc-suppression coils compensate the capacitive current flowing through a ground fault and thus guarantee uninterrupted energy supply. Compensating reactors compensate the capacitive power of the cable networks and reduce overvoltages in case of load rejection; the economic efficiency and stablility of the power transmission are improved. The general overview of our manufacturing/delivery program is shown in the table ”Product Range“.

The transformers comply with the relevant VDE specifications, i.e. DIN VDE 0532 ”Transformers and reactors“ and the ”Technical conditions of supply for threephase transformers“ issued by VDEW and ZVEI. Therefore they also satisfy the requirements of IEC Publication 76, Parts 1 to 5 together with the standards and specifications (HD and EN) of the European Union (EU). Enquiries should be directed to the manufacturer where other standards and specifications are concerned. Only the US (ANSI/NEMA) and Canadian (CSA) standards differ from IEC by any substantial degree. A design according to these standards is also possible. Important additional standards ■ DIN 42 500, HD 428: oil-immersed

Rated power

Max. operating voltage

[MVA]

[kV]

Figs. on page

■

5/13– 5/17

2.5–3000 36–1500 Power transformers

5/18– 5/25

≤ 36

■ ■

0.05–2.5 ≤ 36 Oil distribution transformers

0.10–20 GEAFOLcast-resin transformers

8

Standards and specifications, general

5/27– 5/34

■ ■ ■ ■ ■

three-phase distribution transformers 50–2500 kVA DIN 42 504: oil-immersed three-phase transformers 2–10 MVA DIN 42 508: oil-immersed three-phase transformers 12.5–80 MVA DIN 42 523, HD 538: three-phase dry-type transformers 100–2500 kVA DIN 45 635 T30: noise level IEC 289: reactance coils and neutral grounding transformers IEC 551: measurement of noise level IEC 726: dry-type transformers RAL: coating/varnish

Fig. 1: Transformer types

9

10

5/2

Ohne Namen-1


2

22.09.1999, 16:23 Uhr

Product Range

Oil-immersed distribution transformers, TUMETIC, TUNORMA

50 to 2 500 kVA, highest voltage for equipment up to 36 kV, with copper or aluminum windings, hermetically sealed (TUMETIC®) or with conservator (TUNORMA®) of three- or single-phase design

1

2 Generator and power transformers

Above 2.5 MVA up to more than 1000 MVA, above 30 kV up to 1500 kV (system and system interconnecting transformers, with separate windings or auto-connected), with on-load tap changers or off-circuit tap changers, of three- or single-phase design

3

Cast-resin distribution and power transformers GEAFOL

100 kVA to more than 20 MVA, highest voltage for equipment up to 36 kV, of three- or single-phase design GEAFOL®-SL substations

Special transformers for industry, traction and HVDC transmission systems

Furnace and converter transformers Traction transformers mounted on rolling stock and appropriate on-load tap-changers Substation transformers for traction systems Transformers for train heating and point heating Transformers for HVDC transmission systems Transformers for audio frequencies in power supply systems Three-phase neutral electromagnetic couplers and grounding transformers Ignition transformers

4

5

6

7 Reactors

Accessories

Liquid-immersed shunt and current-limiting reactors up to the highest rated powers Reactors for HVDC transmission systems

8

Buchholz relays, oil testing equipment, oil flow indicators and other monitoring devices Fan control cabinets, control cabinets for parallel operation and automatic voltage control Sensors (PTC, Pt 100)

9

10 Service

Advisory services for transformer specifications Organization, coordination and supervision of transportation Supervision of assembly and commissioning Service/inspection troubleshooting services Training of customer personnel Investigation and assessment of oil problems

Fig. 2

5/3


Ohne Namen-1

3

22.09.1999, 16:23 Uhr

Electrical Design

Power ratings and type of cooling

1

2

3

All power ratings in this guide are the product of rated voltage (times phase-factor for three-phase transformers) and rated current of the line side winding (at center tap, if several taps are provided), expressed in kVA or MVA, as defined in IEC 76-1. If only one power rating and no cooling method are shown, natural oil-air cooling (ONAN or OA) is implied for oil-immersed transformers. If two ratings are shown, forced-air cooling (ONAF or FA) in one or two steps is applicable. For cast resin transformers, natural air cooling (AN) is standard. Forced air cooling (AF) is also applicable.

I

Dy1

5

6

7

8

9

1

ii

III

i

iii

II III

I

Dy5

ii

I

iii i

iii

ii

II III

5

II

ii

Yd5

Temperature rise

II

i 5

In accordance with IEC-76 the standard temperature rise for oil-immersed power and distribution transformers is: ■ 65 K average winding temperature (measured by the resistance method) ■ 60 K top oil temperature (measured by thermometer) The standard temperature rise for Siemens cast-resin transformers is ■ 100 K (insulation class F) at HV and LV winding. Whereby the standard ambient temperatures are defined as follows: ■ 40 °C maximum temperature, ■ 30 °C average on any one day, ■ 20 °C average in any one year, ■ –25 °C lowest temperature outdoors, ■ –5 °C lowest temperature indoors. Higher ambient temperatures require a corresponding reduction in temperature rise, and thus affect price or rated power as follows: ■ 1.5% surcharge for each 1 K above standard temperature conditions, or ■ 1.0% reduction of rated power for each 1 K above standard temperature conditions. These adjustment factors are applicable up to 15 K above standard temperature conditions.

10

11

Dy11

I

Yd11

The transformers are suitable for operation at altitudes up to 1000 meters above sea level. Site altitudes above 1000 m necessitate the use of special designs and an increase/or a reduction of the transformer ratings as follows (approximate values):

5/4

I 11

i

i

ii III

iii

ii

II

III

iii

II

Fig. 3: Most commonly used vector groups

■ 2% increase for every 500 m altitude (or

part there of) in excess of 1000 m, or ■ 2% reduction of rated power for each 500 m altitude (or part there of) in excess of 1000 m. Transformer losses and efficiencies Losses and efficiencies stated in this guide are average values for guidance only. They are applicable if no loss evaluation figure is stated in the inquiry (see following chapter) and they are subject to the tolerances stated in IEC 76-1, namely +10% of the total losses, or +15% of each component loss, provided that the tolerance for the total losses is not exceeded. If optimized and/or guaranteed losses without tolerances are required, this must be stated in the inquiry.

Altitude of installation

Ohne Namen-1

I

i

iii

III

4

Yd1

1

Connections and vector groups Distribution transformers The transformers listed in this guide are all three-phase transformers with one set of windings connected in star (wye) and the other one in delta, whereby the neutral of the star-connected winding is fully rated and brought to the outside.

The primary winding (HV) is normally connected in delta, the secondary winding (LV) in wye. The electrical offset of the windings in respect to each other is either 30, 150 or 330 degrees standard (Dy1, Dy5, Dy11). Other vector groups as well as single-phase transformers and autotransformers on request (Fig. 3). Power transformers Generator transformers and large power transformers are usually connected in Yd. For HV windings higher than 110 kV, the neutral has a reduced insulation level. For star/star-connected transformers and autotransformers normally a tertiary winding in delta, whose rating is a third of that of the transformer, has to be added. This stabilizes the phase-to phase voltages in the case of an unbalanced load and prevents the displacement of the neutral point. Single-phase transformers and autotransformers are used when the transportation possibilities are limited. They will be connected at site to three-phase transformer banks.


4

22.09.1999, 16:23 Uhr

Electrical Design

Insulation level Power-frequency withstand voltages and lightning-impulse withstand voltages are in accordance with IEC 76-3, Para. 5, Table II, as follows:

Highest voltage for equipment Um (r. m. s.)

[kV] ≤ 1.1

Rated lightningimpulse withstand voltage (peak)

Rated shortduration powerfrequency withstand voltage (r. m. s.)

List 1 [kV]

[kV] 3

List 2 [kV]

–

Conversion to 60 Hz – possibilities All ratings in the selection tables of this guide are based on 50 Hz operation. For 60 Hz operation, the following options apply: ■ 1. Rated power and impedance voltage are increased by 10%, all other parameters remain identical. ■ 2. Rated power increases by 20%, but no-load losses increase by 30% and noise level increases by 3 dB, all other parameters remain identical (this layout is not possible for cast-resin transformers). ■ 3. All technical data remain identical, price is reduced by 5%. ■ 4. Temperature rise is reduced by 10 K, load losses are reduced by 15%, all other parameters remain identical.

Transformer cell (indoor installation) The transformer cell must have the necessary electrical clearances when an open air connection is used. The ventilation system must be large enough to fulfill the recommendations for the maximum temperatures according to IEC. For larger power transformers either an oil/water cooling system has to be used or the oil/air cooler (radiator bank) has to be installed outside the transformer cell. In these cases a ventilation system has to be installed also to remove the heat caused by the convection of the transformer tank.

1

2

3

4

–

Overloading 3.6

10

20

40

7.2

20

40

60

12.0

28

60

75

17.5

38

75

95

24.0

50

95

125

36.0

70

145

170

52.0

95

250

72.5

140

325

123.0

185

450

230

550

275

650

325

750

360

850

395

950

Overloading of Siemens transformers is guided by the relevant IEC-354 ”Loading guide for oil-immersed transformers“ and the (similar) ANSI C57.92 ”Guide for loading mineral-oil-immersed power transformers“. Overloading of GEAFOL cast-resin transformers on request.

5

6

Routine and special tests

145.0

170.0

245.0

All transformers are subjected to the following routine tests in the factory: ■ Measurement of winding resistance ■ Measurement of voltage ratio and check of polarity or vector group ■ Measurement of impedance voltage ■ Measurement of load loss ■ Measurement of no-load loss and no-load current ■ Induced overvoltage withstand test ■ Seperate-source voltage withstand test ■ Partial discharge test (only GEAFOL cast-resin transformers). The following special tests are optional and must be specified in the inquiry: ■ Lightning-impulse voltage test (LI test), full-wave and chopped-wave (specify) ■ Partial discharge test ■ Heat-run test at natural or forced cooling (specify) ■ Noise level test ■ Short-circuit test. Test certificates are issued for all the above tests on request.

7

8

9

10

Higher test voltage withstand requirements must be stated in the inquiry and may result in a higher price.

Fig. 4: Insulation level

5/5


Ohne Namen-1

5

22.09.1999, 16:23 Uhr

Transformer Loss Evaluation

1

2

3

4

5

6

7

8

9

10

The sharply increased cost of electrical energy has made it almost mandatory for buyers of electrical machinery to carefully evaluate the inherent losses of these items. In case of distribution and power transformers, which operate continuously and most frequently in loaded condition, this is especially important. As an example, the added cost of loss-optimized transformers can in most cases be recovered via savings in energy use in less than three years. Low-loss transformers use more and better materials for their construction and thus initially cost more. By stipulating loss evaluation figures in the transformer inquiry, the manufacturer receives the necessary incentive to provide a loss-optimized transformer rather than the lowcost model. Detailed loss evaluation methods for transformers have been developed and are described accurately in the literature, taking the project-specific evaluation factors of a given customer into account. The following simplified method for a quick evaluation of different quoted transformer losses is given, making the following assumptions: ■ The transformers are operated continuously ■ The transformers operate at partial load, but this partial load is constant ■ Additional cost and inflation factors are not considered ■ Demand charges are based on 100% load. The total cost of owning and operating a transformer for one year is thus defined as follows: ■ A. Capital cost Cc taking into account the purchase price Cp, the interest rate p, and the depreciation period n ■ B. Cost of no-load loss CP0, based on the no-load loss P0, and energy cost Ce ■ C. Cost of load loss Cpk, based on the copper loss Pk, the equivalent annual load factor a, and energy cost Ce ■ D. Demand charges Cd, based on the amount set by the utility, and the total kW of connected load. These individual costs are calculated as follows:

A. Capital cost

Cc = Cp

Cp · r

amount year

100

= purchase price

p · qn = depreciation factor qn – 1 p q= + 1 = interest factor 100

r=

p n

= interest rate in % p.a. = depreciation period in years

B. Cost of no-load loss

CP0 = Ce · 8760 h/year · P0 Ce

= energy charges

P0

= no-load loss [kW]

amount year

amount kWh

C. Cost of load loss

CPk = Ce · 8760 h/year · α2 · Pk

amount year

constant operation load rated load

α

=

Pk

= copper loss [kW]

D. Cost resulting from demands charges

CD = Cd (P0 + Pk) Cd

amount year

= demand charges

amount kW · year

Fig. 5

5/6

Ohne Namen-1


6

22.09.1999, 16:23 Uhr

Transformer Loss Evaluation

To demonstrate the usefulness of such calculations, the following arbitrary examples are shown, using factors that can be considered typical in Germany, and neglecting the effects of inflation on the rate assumed:

1

2 Example: 1600 kVA distribution transformer

Depreciation period Interest rate Energy charge

n = 20 years Depreciation factor p = 12% p. a. r = 13.39 Ce = 0.25 DM/kWh

Demand charge

Cd = 350

Equivalent annual load factor

α

A. Low-cost transformer

P0 = 2.6 kW Pk = 20 kW Cp = DM 25 000

3

DM kW · yr

4

= 0.8

B. Loss-optimized transformer

no-load loss load loss purchase price

Cc = 25000 · 13.39 100

P0 = 1.7 kW Pk = 17 kW Cp = DM 28 000

5

no-load loss load loss purchase price

6

Cc = 28000 · 13.39 100

= DM 3348/year

= DM 3 749/year

CP0 = 0.25 · 8760 · 2.6 = DM 5694/year

CP0 = 0.25 · 8760 · 1.7 = DM 3 723/year

CPk = 0.25 · 8760 · 0.64 · 20 = DM 28 032/year

CPk = 0.25 · 8760 · 0.64 · 17 = DM 23 827/year

CD = 350 · (2.6 + 20) = DM 7910/year

CD = 350 · (1.7 + 17) = DM 6 545/year

Total cost of owning and operating this transformer is thus:

Total cost of owning and operating this transformer is thus:

7

8

9 DM 44 984.–/year

DM 37 844.–/year

10 The energy saving of the optimized distribution transformer of DM 7140 per year pays for the increased purchase price in less than one year.

Fig. 6

5/7


Ohne Namen-1

7

22.09.1999, 16:23 Uhr

Mechanical Design

1

General mechanical design for oil-immersed transformers: ■ Iron core made of grain-oriented

2

■

3

■ ■

4

■ ■

■

5

6

7

8

9

10

electrical sheet steel insulated on both sides, core-type. Windings consisting of copper section wire or copper strip. The insulation has a high disruptive strength and is temperature-resistant, thus guaranteeing a long service life. Designed to withstand short circuit for at least 2 seconds (IEC). Oil-filled tank designed as tank with strong corrugated walls or as radiator tank. Transformer base with plain or flanged wheels (skid base available). Cooling/insulation liquid: Mineral oil according to VDE 0370/IEC 296. Silicone oil or synthetic liquids are available. Standard coating for indoor installation. Coatings for outdoor installation and for special applications (e.g. aggressive atmosphere) are available.

Tank design and oil preservation system Sealed-tank distribution transformers, TUMETIC® In ratings up to 2500 kVA and 170 kV LI this is the standard sealed-tank distribution transformer without conservator and gas cushion. The TUMETIC transformer is always completely filled with oil; oil expansion is taken up by the flexible corrugated steel tank (variable volume tank design), whereby the maximum operating pressure remains at only a fraction of the usual. These transformers are always shipped completely filled with oil and sealed for their lifetime. Bushings can be exchanged from the outside without draining the oil below the top of the active part. The hermetically sealed system prevents oxygen, nitrogen, or humidity from contact with the insulating oil. This improves the aging properties of the oil to the extent that no maintenance is required on these transformers for their lifetime. Generally the TUMETIC transformer is lower than the TUNORMA transformer. This design has been in successful service since 1973. A special TUMETIC-Protection device has been developed for this transformer.

5/8

Ohne Namen-1

Distribution transformers with conservator, TUNORMA® This is the standard distribution transformer design in all ratings. The oil level in the tank and the top-mounted bushings is kept constant by a conservator vessel or expansion tank mounted at the highest point of the transformer. Oil-level changes due to thermal cycling affect the conservator only. The ambient air is prevented from direct contact with the insulating oil through oiltraps and dehydrating breathers. Tanks from 50 to approximately 4000 kVA are preferably of the corrugated steel design, whereby the sidewalls are formed on automatic machines into integral cooling pockets. Suitable spot welds and braces render the required mechanical stability. Tank bottom and cover are fabricated from rolled and welded steel plate. Conventional radiators are available. Power transformers Power transformers of all ratings are equipped with conservators. Both the open and closed system are available. With the closed system ”TUPROTECT®“ the oil does not come into contact with the surrounding air. The oil expansion is compensated with an air bag. (This design is also available for greater distribution transformers on request). The sealing bag consists of strong nylon braid with a special double lining of ozone and oil-resistant nitrile rubber. The interior of this bag is in contact with the ambient air through a dehydrating breather; the outside of this bag is in direct contact with the oil. All tanks, radiators and conservators (incl. conservator with airbag) are designed for vacuum filling of the oil. For transformers with on-load tap changers a seperate smaller conservator is necessary for the diverter switch compartment. This seperate conservator (without air bag) is normally an integrated part of the main conservator with its own magnetic oil level indicator. Power transformers up to 10 MVA are fitted with weld-on radiators and are shipped extensively assembled; shipping conditions permitting. Ratings above 10 MVA require detachable radiators with individual butterfly valves, and partial dismantling of components for shipment. All the usual fittings and accessories for oil treatment, shipping and installation of these transformers are provided as standard. For monitoring and protective devices, see the listing on page 5/11.

Fig. 7: Cross section of a TUMETIC three-phase distribution transformer

Fig. 8: 630 kVA, three-phase, TUNORMA 20 kV ± 2.5 %/0.4 kV distribution transformer

Fig. 9: Practically maintenancefree: transformer with the TUPROTECT air-sealing system built into the conservator


8

22.09.1999, 16:23 Uhr

Connection Systems

Distribution transformers 1

All Siemens transformers have top-mounted HV and LV bushings according to DIN in their standard version. Besides the open bushing arrangement for direct connection of bare or insulated wires, three basic insulated termination systems are available:

2

Fully enclosed terminal box for cables (Fig. 11) Available for either HV or LV side, or for both. Horizontally split design in degree of protection IP 44 or IP 54. (Totally enclosed and fully protected against contact with live parts, plus protection against drip, splash, or spray water.) Cable installation through split cable glands and removable plates facing diagonally downwards. Optional conduit hubs. Suitable for single-core or three-phase cables with solid dielectric insulation, with or without stress cones. Multiple cables per phase are terminated on auxiliary bus structures attached to the bushings. Removal of transformer by simply bending back the cables.

3

4 Fig. 11: Fully enclosed cable connection box

5

6

Insulated plug connectors (Fig. 12) For substation installations, suitable HV can be attached via insulated elbow connectors in LI ratings up to 170 kV.

7

Flange connection (Fig. 13) Air-insulated bus ducts, insulated busbars, or throat-connected switchgear cubicles are connected via standardized flanges on steel terminal enclosures. These can accommodate either HV, LV, or both bushings. Fiberglass-reinforced epoxy partitions are available between HV and LV bushings if flange/flange arrangements are chosen. The following combinations of connection systems are possible besides open bushing arrangements:

HV

LV

Cable box

Cable box

Cable box

Flange/throat

Flange

Cable box

Flange

Flange/throat

Elbow connector

Cable box

Elbow connector

Flange/throat

Fig. 10: Combination of connection systems

8 Fig. 12: Grounded metal-elbow plug connectors

9

10

Fig 13: Flange connection for switchgear and bus ducts

5/9


Ohne Namen-1

9

22.09.1999, 16:23 Uhr

Connection Systems

Power transformers 1

2

3

4

5

The most frequently used type of connection for transformers is the outdoor bushing. Depending on voltage, current, system conditions and transport requirements, the transformers will be supplied with bushings arranged vertically, horizontally or inclined. Up to about 110 kV it is usual to use oil-filled bushings according to DIN; condenser bushings are normally used for higher voltages. Limited space or other design considerations often make it necessary to connect cables directly to the transformer. For voltages up to 30 kV air-filled cable boxes are used. For higher voltages the boxes are oil-filled. They may be attached to the tank cover or to its walls (Fig. 14). The space-saving design of SF6-insulated switchgear is one of its major advantages. The substation transformer is connected directly to the SF6 switchgear. This eliminates the need for an intermediate link (cable, overhead line) between transformer and system (Fig. 15).

6 Fig. 14: Transformers with oil-filled HV cable boxes

7

8

9

10

Fig. 15: Direct SF6-connection of the transformer to the switchgear

5/10

Ohne Namen-1


10

22.09.1999, 16:23 Uhr

Accessories and Protective Devices Accessories not listed completely. Deviations are possible.

Double-float Buchholz relay (Fig. 16) For sudden pressure rise and gas detection in oil-immersed transformer tanks with conservator. Installed in the connecting pipe between tank and conservator and responding to internal arcing faults and slow decomposition of insulating materials. Additionally, backup function of oil alarm. The relay is actuated either by pressure waves or gas accumulation, or by loss of oil below the relay level. Seperate contacts are installed for alarm and tripping. In case of a gas accumulation alarm, gas samples can be drawn directly at the relay with a small chemical testing kit. Discoloring of two liquids indicates either arcing byproducts or insulation decomposition products in the oil. No change in color indicates an air bubble.

1

2

3

4

Fig. 16: Double-float Buchholz relay

Dial-type contact thermometer (Fig. 17) Indicates actual top-oil temperature via capillary tube. Sensor mounted in well in tank cover. Up to four separately adjustable alarm contacts and one maximum pointer are available. Installed to be readable from the ground. With the addition of a CT-fed thermal replica circuit, the simulated hot-spot winding temperature of one or more phases can be indicated on identical thermometers. These instruments can also be used to control forced cooling equipment.

5

6

7

8

Fig. 17: Dial-type contact thermometer

Magnetic oil-level indicator (Fig. 18) The float position inside of the conservator is transmitted magnetically through the tank wall to the indicator to preserve the tank sealing standard device without contacts; devices supplied with limit (position) switches for high- and low-level alarm are available. Readable from the ground.

9

10

Fig. 18: Magnetic oil-level indicator

5/11


Ohne Namen-1

11

22.09.1999, 16:23 Uhr

Accessories and Protective Devices

Protective device (Fig. 19) for hermetically sealed transformers (TUMETIC)

1

For use on hermetically sealed TUMETIC distribution transformers. Gives alarm upon loss of oil and gas accumulation. Mounted directly at the (permanently sealed) filler pipe of these transformers.

2 Pressure relief device (Fig. 20) Relieves abnormally high internal pressure shock waves. Easily visible operation pointer and alarm contact. Reseals positively after operation and continues to function without operator action.

3

Dehydrating breather (Fig. 21, 22) A dehydrating breather removes most of the moisture from the air which is drawn into the conservator as the transformer cools down. The absence of moisture in the air largely eliminates any reduction in the breakdown strength of the insulation and prevents any buildup of condensation in the conservator. Therefore, the dehydrating breather contributes to safe and reliable operation of the transformer.

4

5

6

Fig. 19: Protective device for hermetically sealed transformers (TUMETIC)

Fig. 20: Pressure relief device with alarm contact and automatic resetting

Bushing current transformer Up to three ring-type current transformers per phase can be installed in power transformers on the upper and lower voltage side. These multiratio CTs are supplied in all common accuracy and burden ratings for metering and protection. Their secondary terminals are brought out to shortcircuiting-type terminal blocks in watertight terminal boxes.

7

8

Additional accessories Besides the standard accessories and protective devices there are additional items available, especially for large power transformers. They will be offered and installed on request. Examples are: ■ Fiber-optic temperature measurements ■ Permanent gas-in-oil analysis ■ Permanent water-content measurement ■ Sudden pressure rise relay, etc.

9

10

Fig. 21: Dehydrating breather A DIN 42 567 up to 5 MVA

5/12

Ohne Namen-1

Fig. 22: Dehydrating breather L DIN 42 562 over 5 MVA


12

22.09.1999, 16:23 Uhr

Technical Data Distribution Transformers TUNORMA and TUMETIC

Oil-immersed TUMETIC and TUNORMA three-phase distribution transformers

12 11 10

3

1

8 2N 2U 2V 2W

■ ■ ■ ■ ■ ■

■

■

■ ■ ■

Standard: DIN 42500 Rated power: 50–2500 kVA Rated frequency: 50 Hz HV rating: up to 36 kV Taps on ± 2.5 % or ± 2 x 2.5 % HV side: LV rating: 400–720 V (special designs for up to 12 kV can be built) Connection: HV winding: delta LV winding: star (up to 100 kVA: zigzag) Impedance 4 % (only up to HV voltage at rated rating 24 kV and current: ≤ 630 kVA) or 6 % (with rated power ≥ 630 kVA or with HV rating > 24 kV) Cooling: ONAN Protection class: IP00 Final coating: RAL 7033 (other colours are available)

H1

1U 2U 1W

B1

2

7 9 E 2 3 6 7 8

6

8

2

Oil drain plug Thermometer pocket Adjustment for off-load tap changer Rating plate (relocatable) Grounding terminals

E

A1

9 10 11 12

Towing eye, 30 mm dia. Lashing lug Filler pipe Mounting facility for protective device

3

4

Fig. 24: TUMETIC distribution transformer (sealed tank)

5

4

1

5 10

3 8 2N 2U 2V 2W

H1

1U 2U 1W

B1

6

7

Um

LI

AC

[kV]

[kV]

[kV]

1.1

–

3

12

75

28

24

125

50

36

170

70

LI Lightning-impulse test voltage AC Power-frequency test voltage Fig. 23: Insulation level (IP00)

9 2 E 1 2 3 4 5

A1

E

Oil level indicator Oil drain plug Thermometer pocket Buchholz relay (optional extra) Dehydrating breather (optional extra)

6 7 8 9 10

13

7

Adjustment for off-load tap changer Rating plate (relocatable) Grounding terminals Towing eye, 30 mm dia. Lashing lug

Notes: Tank with strong corrugated walls shown in illustration is the preferred design. With HV ratings up to 24 kV and rated power up to 250 kVA (and with HV ratings > 24-36 kV and rated power up to 800 kVA), the conservator is fitted on the long side just above the LV bushings.

8

Fig. 25: TUNORMA distribution transformer (with conservator)

Losses The standard HD 428.1.S1 (= DIN 42500 Part 1) applies to three-phase oil-immersed distribution transformers 50 Hz, from 50 kVA to 2500 kVA, Um to 24 kV. For load losses (Pk), three different listings (A, B and C) were specified. There were also three listings (A’, B’ and C’) for no-load losses (P0) and corresponding sound levels. Due to the different requirements, pairs of values were proposed which, in the national standard, permit one or several combinations of losses. DIN 42500 specifies the combinations A-C’, C-C’ and B-A’ as being most suitable.

The combinations B-A’ (normal losses) and A-C’ (reduced losses) are approximately in line with previous standards. In addition there is the C-C’ combination. Transformers of this kind with additionally reduced losses are especially economical with energy (maximum efficiency > 99%). The higher costs of these transformers are counteracted by the energy savings which they make. Standard HD 428.3.S1 (= DIN 42500-3) specifies the losses for oil distribution transformers up to Um = 36 kV. For load losses the listings D and E, for no-load losses the listings D’ and E’ were specified. In order to find the most efficient transformer, please see part ”Transformer loss evaluation“.

5/13


Ohne Namen-1

6

8

22.09.1999, 16:23 Uhr

9

10


TUMETIC

TUNORMA

TUMETIC

TUNORMA

TUMETIC

TUNORMA

1350

42

55

340 350

860

980 660

660 1210 1085 520

..4744-3RB

A-C'

125

1100

34

47

400 430

825 1045 660

660 1210 1085 520

4

..4744-3TB

C-C'

125

875

34

47

420 440

835

985 660

660 1220 1095 520

4

..4767-3LB

B-A'

190

1350

42

55

370 380

760

860 660

660 1315 1235 520

4

..4767-3RB

A-C'

125

1100

34

47

430 460

860

860 660

660 1300 1220 520

4

..4767-3TB

C-C'

125

875

33

47

480 510

880 1100 685

660 1385 1265 520

36

6

..4780-3CB

E-D´

230

1450

x

52

500

12

4

..5044-3LB

B-A'

320

2150

45

59

500 500

4

..5044-3RB

A-C'

210

1750

35

49

570 570

980

980 660

660 1315 1145 520

4

..5044-3TB

C-C'

210

1475

35

49

600 620

1030

930 660

660 1320 1150 520

4

..5067-3LB

B-A'

320

2150

45

59

520 530

1020 1140 685

660 1360 1245 520

4

..5067-3RB

A-C'

210

1750

35

49

600 610

1030 1030 690

660 1400 1280 520

4

..5067-3TB

C-C'

210

1475

35

49

640 680

960 1060 695

660 1425 1305 520

36

6

..5080-3CB

E-D´

380

2350

x

56

660

12

4

..5244 -3LA

B-A'

460

3100

47

62

620 610

1140 1140 710

710 1350 1185 520

4

..5244-3RA

A-C'

300

2350

37

52

700 690

1130 1010 660

660 1390 1220 520

4

..5244-3TA

C-C'

300

2000

38

52

760 780

985 1085 660

660 1380 1215 520

4

..5267-3LA

B-A'

460

3100

47

62

660 640

1150 1150 695

660 1440 1320 520

4

..5267-3RA

A-C'

300

2350

37

52

730 730

1030

930 695

660 1540 1420 520

4

..5267-3TA

C-C'

300

2000

37

52

800 820

1120 1120 710

660 1475 1355 520

36

6

..5280-3CA

E-D´

520

3350

x

59

900

1120

12

4

..5344-3LA

B-A'

550

3600

48

63

720 710

1190 1190 680

680 1450 1285 520

4

..5344-3RA

A-C'

360

2760

38

53

840 830

1070 1120 660

660 1470 1300 520

4

..5344-3TA

C-C'

360

2350

38

53

900 920

1130 1130 660

680 1450 1285 520

4

..5367-3LA

B-A'

550

3600

48

63

800 780

1290 1290 820

800 1595 1425 520

4

..5367-3RA

A-C'

360

2760

38

53

890 910

1110 1230 755

680 1630 1460 520

4

..5367-3TA

C-C'

360

2350

38

53

950 980

1080 1180 705

690 1595 1430 520

6

..5380-3CA

E-D´

600

3800

x

61

..4744-3LB

4

4

24

6

24

10

TUMETIC

190

4

(200)

Dist. between wheel centers

B-A'

12

9

Height H1

Width B1

[kg]

50

8

Length A1

LWA [dB]

4JB… 4HB…

160

Dimensions

Total weight

LPA [dB]

U2 [%]

24

7

Sound power level

Pk 75* [W]

Um [kV]

100

CENELEC

Sound press. level 1m tolerance + 3 dB

P0 [W]

Sn [kVA]

3

5

Combi- No-load Load nation of losses losses losses acc.

Type

TUNORMA

Max. Imperated dance volt. voltage HV side

TUMETIC

2

Rated power

TUNORMA

1

24

36

Dimensions and weights are approximate values. Rated power figures in parentheses are not standardized.

1000

[mm]

x

x

x

x

1000

[mm]

x 710

1090 1020 660

1050

1250

x 780

x 800

x 800

[mm]

x 1530

E [mm]

x 520

660 1275 1110 520

x 1600

x 1700

x 1700

x 520

x 520

x 520

x: on request

* In case of short-circuits at 75 °C

Fig. 26: Selection table: oil-immersed distribution transformers 50 to 2500 kVA

5/14

Ohne Namen-1


14

22.09.1999, 16:23 Uhr


P0 [W]

Height H1


TUMETIC

TUNORMA

TUMETIC

LWA [dB]

Width B1 TUNORMA

LPA [dB]

Length A1 TUMETIC

Pk 75* [W]

CENELEC

Dimensions

Total weight

TUNORMA

Sound power level

TUNORMA

Sound press. level 1m tolerance + 3 dB

TUMETIC


Type

TUMETIC


TUNORMA

Rated power

Sn [kVA]

Um [kV]

U2 [%]

250

12

4

..5444-3LA B-A'

650

4200

50

65

830 820 1300 1300

810 810 1450 1285 520

4

..5444-3RA A-C'

425

3250

40

55

940 920 1260 1260

670 820 1480 1415 520

4

..5444-3TA C-C'

425

2750

40

55

1050 1070 1220 1220

690 700 1530 1310 520

4

..5467-3LA B-A'

650

4200

49

65

920 900 1340 1340

800 760 1620 1450 520

4

..5467-3RA A-C'

425

3250

39

55

1010 1010 1140 1190

760 680 1675 1510 520

4

..5467-3TA C-C'

425

2750

40

55

1120 1140 1220 1340

715 710 1640 1475 520

36

6

..5480-3CA E-E´

650

4250

x

62

1100

800

12

4

..5544-3LA B-A'

780

5000

50

66

980 960 1440 1330

820 820 1655 1385 670

4

..5544-3RA A-C'

510

3850

40

56

1120 1100 1400 1250

820 820 1690 1415 670

4

..5544-3TA C-C'

510

3250

40

56

1240 1260 1380 1260

820 820 1665 1390 670

4

..5567-3LA B-A'

780

5000

50

66

1050 1030 1450 1350

840 840 1655 1510 670

4

..5567-3RA A-C'

510

3850

40

56

1170 1150 1410 1270

820 820 1755 1610 670

4

..5567-3TA C-C'

510

3250

40

56

1250 1280 1395 1290

820 820 1675 1540 670

36

6

..5580-3CA E-E´

760

5400

x

64

1220

960

12

4

..5644-3LA B-A'

930

6000

52

68

1180 1160 1470 1390

930 930 1700 1425 670

4

..5644-3RA A-C'

610

4600

42

58

1320 1310 1400 1360

820 820 1700 1430 670

4

..5644-3TA C-C'

610

3850

42

58

1470 1470 1410 1390

820 820 1695 1420 670

4

..5667-3LA B-A'

930

6000

52

68

1240 1220 1570 1570

940 940 1655 1510 670

4

..5667-3RA A-C'

610

4600

42

58

1370 1350 1475 1400

820 820 1760 1615 670

4

..5667-3TA C-C'

610

3850

42

58

1490 1520 1440 1400

820 820 1765 1540 670

36

6

..5580-3CA E-E´

930

6200

x

65

1480

990

12

4

..5744-3LA B-A'

1100

7100

53

69

1410 1380 1500 1430

840 840 1710 1440 670

4

..5744-3RA A-C'

720

5450

42

59

1650 1620 1560 1550

890 890 1745 1470 670

4

..5744-3TA C-C'

720

4550

43

59

1700 1710 1500 1470

820 820 1745 1470 670

4

..5767-3LA B-A'

1100

7100

53

69

1460 1440 1470 1530

835 850 1755 1610 670

4

..5767-3RA A-C'

720

5450

42

59

1650 1620 1495 1420

835 820 1815 1665 670

4

..5767-3TA C-C'

720

4550

43

59

1860 1910 1535 1500

820 820 1860 1645 670

6

..5780-3CA E-E´

1050

7800

x

66

1680

24

(315)

24

400

24

(500)

24

36

4JB… 4HB…


[kg]

[mm]

x 1350

x 1420

x 1470

x 1510

[mm]

x

x

x

x 1030

[mm]

x 1680

x 1700

x 1830

x 1900

2

E [mm]

3

4

x 520

5

6

x 670

7

8

x 670

9

10

x 670

x: on request



5/15


Ohne Namen-1

15

22.09.1999, 16:23 Uhr

1


Um [kV]

U2 [%]

630

12

4

..5844-3LA B-A'

4


TUMETIC

TUNORMA

TUMETIC

TUNORMA

TUMETIC

TUNORMA

TUMETIC

Height H1

Width B1

E [mm]

LWA [dB]

1300

8400

53

70

1660 1660 1680 1480

880 880 1755 1585 670

..5844-3RA A-C'

860

6500

43

60

1850 1810 1495 1420

835 820 1785 1510 670

4

..5844-3TA C-C'

860

5400

43

60

2000 1990 1535 1380

820 820 1860 1520 670

6

..5844-3PA B-A'

1200

8700

53

70

1750 1760 1720 1560

890 890 1920 1685 670

6

..5844-3SA A-C'

800

6750

43

60

1950 1920 1665 1600

870 870 1740 1400 670

6

..5844-3UA C-C'

800

5600

43

60

2160 2130 1670 1560

830 830 1840 1500 670

4

..5867-3LA B-A'

1300

8400

53

70

1690 1650 1665 1640

860 860 1810 1595 670

4

..5867-3RA A-C'

860

6500

43

60

1940 1920 1685 1680

870 870 1910 1695 670

4

..5867-3TA C-C'

860

5400

43

60

2100 2130 1600 1490

820 820 1940 1725 670

6

..5867-3PA B-A'

1200

8700

53

70

1730 1720 1780 1580

880 880 1760 1610 670

6

..5867-3SA A-C'

800

6750

43

60

1970 1960 1645 1640

830 830 1810 1595 670

6

..5867-3UA C-C'

800

5600

43

60

2240 2210 1740 1670

880 880 1840 1625 670

36

6

..5880-3CA E-E´

1300

8800

x

67

1950

12

6

..5944-3PA B-A'

1450

10700

55

72

1990 1960 1780 1540 1000 1000 1905 1660 670

6

..5944-3SA A-C'

950

8500

45

62

2210 2290 1720 1830

900 960 1935 1630 670

6

..5944-3UA C-C'

950

7400

44

62

2520 2490 1760 1710

920 920 1975 1730 670

6

..5967-3PA B-A'

1450

10700

55

72

2000 1950 1720 1710 1000 1000 1885 1670 670

6

..5967-3SA A-C'

950

8500

45

62

2390 2340 1760 1710

960 960 1945 1730 670

6

..5967-3UA C-C'

950

7400

44

62

2590 2550 1770 1700

930 930 1985 1780 670

36

6

..5980-3CA E-E´

1520

11000

x

68

2400

12

6

..6044-3PA B-A'

1700

13000

55

73

2450 2640 1790 1630 1000 1000 2095 2070 820

6

..6044-3SA A-C'

1100

10500

45

63

2660 2610 1830 1830 1040 1040 2025 1770 820

6

..6044-3UA C-C'

1100

9500

45

63

2800 2750 1830 1830 1040 1040 2105 1840 820

6

..6067-3PA B-A'

1700

13000

55

73

2530 2720 1830 1670 1090 1010 2095 2120 820

6

..6067-3SA A-C'

1100

10500

45

63

2750 2690 1790 1740 1050 1050 2055 1840 820

6

..6067-3UA C-C'

1100

9500

45

63

2830 2810 1725 1770

6

..6080 -3CA E-E´

1700

13000

x

68

2850

5

6

7 24

8

24

10

Length A1

LPA [dB]

24

1000

Dimensions

Total weight

Pk 75* [W]

4

(800)

P0 [W]

Sound Sound press. power level level 1m tolerance + 3 dB

TUNORMA

CENELEC

Sn [kVA]

3

9


Type

TUMETIC

2


TUNORMA

1

Rated power

36

4JB… 4HB…


[kg]

[mm]

x 1740

x 1800

x 2120

[mm]

x 1080

x 1100

[mm]

x 1940

x 2030

x 670

x 670

990 990 2065 1850 820

x 1160

x 2220

x 820

x: on request



5/16

Ohne Namen-1


16

22.09.1999, 16:23 Uhr


Height H1


TUMETIC

TUNORMA

TUMETIC

TUNORMA

Width B1

TUMETIC

TUNORMA

TUMETIC

TUMETIC

Length A1

LPA [dB]

LWA [dB]

..6144-3PA B-A'

2100

16000

56

74

2900 3080 1930 1850 1260 1100 2110 2070 820

6

..6144-3SA A-C'

1300

13200

46

64

3100 3040 1810 1780

6

..6144-3UA C-C'

1300

11400

46

64

3340 3040 1755 1720 1015 1000 2235 1970 820

6

..6167-3PA B-A'

2100

16000

56

74

2950 3200 2020 1780 1260 1100 2110 2220 820

6

..6167-3SA A-C'

1300

13200

46

64

3190 3120 1840 1810 1060 1060 2115 1900 820

6

..6167-3UA C-C'

1300

11400

46

64

3390 3330 1810 1780 1015

36

6

..6180-3CA E-E´

2150

16400

x

70

3360

12

6

..6244-3PA B-A'

2600

20000

57

76

3450 3590 1970 1870 1220 1140 2315 2095 820

6

..6244-3SA A-C'

1700

17000

47

66

3640 3590 2030 1760 1080 1090 2315 2010 820

6

..6244-3UA C-C'

1700

14000

47

66

3930 3880 2020 1900 1110 1100 2395 2070 820

6

..6267-3PA B-A'

2600

20000

57

76

3470 3690 2070 1830 1280 1120 2335 2320 820

6

..6267-3SA A-C'

1700

17000

47

66

3670 3850 2030 2000 1230 1070 2265 2120 820

6

..6267-3UA C-C'

1700

14000

47

66

4010 3950 2000 1850 1030 1030 2305 2010 820

36

6

..6280-3CA E-E´

2600

19200

x

71

3930

12

6

..6344-3PA B-A'

2900

25300

58

78

4390 4450 2100 1890 1330 1330 2555 2540 1070

6

..6344-3SA A-C'

2050

21200

49

68

4270 4430 2080 1840 1330 1330 2455 2250 1070

6

..6344-3UA C-C'

2050

17500

49

68

4730 4710 2020 1730 1330 1330 2495 2170 1070

6

..6367-3PA B-A'

2900

25300

58

78

4480 4500 2020 1860 1330 1330 2655 2660 1070

6

..6367-3SA A-C'

2050

21200

49

68

4290 4490 2190 2030 1330 1330 2425 2280 1070

6

..6367-3UA C-C'

2050

17500

49

68

4910 4840 2110 1980 1330 1330 2475 2180 1070

36

6

..6380-3CA E-E´

3200

22000

x

75

5100

12

6

..6444-3PA B-A'

3500

29000

61

81

5200 5090 2115 2030 1345 1330 2685 2550 1070

6

..6444-3SA A-C'

2500

26500

51

71

5150 5110 2195 1950 1345 1330 2535 2450 1070

6

..6444-3UA C-C'

2500

22000

51

71

5790 5660 2190 2190 1330 1330 2565 2240 1070

6

..6467-3PA B-A'

3500

29000

61

81

5420 5220 2115 2030 1335 1330 2785 2675 1070

6

..6467-3SA A-C'

2500

26500

51

71

5260 5220 2195 2030 1335 1335 2585 2580 1070

6

..6467-3UA C-C'

2500

22000

51

71

5640 5470 2160 2080 1330 1330 2605 2305 1070

6

..6480-3CA E-E´

3800

29400

x

76

5900

U2 [%]

(1250)

12

6

24

24

24

2500

Dimensions

Total weight

Pk 75* [W]

Um [kV]

(2000)

CENELEC

Sound Sound press. power level level 1m tolerance + 3 dB

P0 [W]

Sn [kVA]

1600


Type

TUNORMA


TUNORMA

Rated power

24

36

4JB… 4HB…


[kg]

[mm]

x 2150

x 2170

x 2260

x 2320

[mm]

990

x 1250

x 1340

x 1380

x 1390

[mm]

2

E [mm]

990 2145 1880 820

3

4

990 2245 2030 820 x 2350

x 2480

x 2560

x 2790

x 820

5

6

x 820

7

8

x 1070

9

10

x 1070

x: on request



5/17


Ohne Namen-1

17

22.09.1999, 16:23 Uhr

1

Power Transformers – General

1

Oil-immersed three-phase power transformers with offand on-load tap changers

Rated power

HV range

Type of tap changer

Figure/ page

[MVA]

[kV]

3.15 to 10

25 to 123

off-load

Fig. 31, page 5/19

3.15 to 10

25 to 123

on-load

Fig. 33, page 5/20

10/16 to 20/31.5

up to 36

off-load

Fig. 35, page 5/21

10/16 to 20/31.5

up to 36

on-load

Fig. 38, page 5/22

10/16 to 63/100

72.5 to 145

on-load

Fig. 41, page 5/23

Cooling methods

2

3

4

5

6

Transformers up to 10 MVA are designed for ONAN cooling. By adding fans to these transformers, the rating can be increased by 25%. However, in general it is more economical to select higher ONAN ratings rather than to add fans. Transformers larger than 10 MVA are designed with ONAN/ONAF cooling. Explanation of cooling methods: ■ ONAN: Oil-natural, air-natural cooling ■ ONAF: Oil-natural, air-forced cooling (in one or two steps) The arrangement with the attached radiators, as shown in the illustrations, is the preferred design. However, other arrangements of the cooling equipment are also possible. Depending on transportation possibilities the bushings, radiators and expansion tank have be removed. If necessary, the oil has to be drained and shipped separately.

Note: Off-load tap changers are designed to be operated de-energized only.

Fig. 30: Types of power transformers

7

8

9

10

5/18

Ohne Namen-1


18

22.09.1999, 16:23 Uhr

Power Transformers – Selection Tables Technical Data, Dimensions and Weights

Oil-immersed three-phase power transformers with off-load tap changer 3 150–10 000 kVA, HV rating: up to 123 kV

1

2 ■ Taps on

HV side:

H

± 2 x 2.5 %

■ Rated frequency: 50 Hz ■ Impedance 6-10 %

3

voltage: ■ Connection:

HV winding: stardelta connection alternatively available up to 24 kV LV winding: star or delta

E

L

E W

4

Fig. 31

Rated power

HV rating

LV rating

No-load loss

Load loss Total at 75 °C weight

Oil weight

Dimensions L/W/H

E

[kVA] ONAN

[kV]

[kV]

[kW]

[kW]

[kg]

[mm]

[mm]

3150

6.1–36

3–24

4.6

28

7200

1600

2800/1850/2870

1070

4000

7.8–36

3–24

5.5

33

8400

1900

3200/2170/2940

1070

50–72.5

3–24

6.8

35

10800

3100

3100/2300/3630

1070

9.5–36

4–24

6.5

38

9800

2300

2550/2510/3020

1070

50–72.5

4–24

8.0

41

12200

3300

3150/2490/3730

1070

90–123

5–36

9.8

46

17500

6300

4560/2200/4540

1505 1505

5000

6300

8000

10000

[kg]

12.2–36

5–24

7.7

45

11700

2500

2550/2840/3200

50–72.5

5–24

9.3

48

13600

3700

3200/2690/3080

1505

90–123

5–36

11.0

53

18900

6600

4780/2600/4540

1505

12.2–36

5–24

9.4

54

14000

3300

2580/2770/3530

1505

50–72.5

5–24

11.0

56

15900

4200

3250/2850/4000

1505

90–123

5–36

12.5

62

21500

7300

4880/2630/4590

1505

15.2–36

6–24

11.0

63

16600

3900

2670/2900/3720

1505

50–72.5

6–24

12.5

65

18200

4700

4060/2750/4170

1505

90–123

5–36

14.0

72

25000

8600

4970/2900/4810

1505

5

6

7

8

9

10

Fig. 32

5/19


Ohne Namen-1

19

22.09.1999, 16:23 Uhr


1

Oil-immersed three-phase power transformers with on-load tap changer 3 150–10 000 kVA, HV rating: up to 123 kV H

2 ± 16 % in ± 8 steps HV side: of 2 % ■ Rated frequency: 50 Hz ■ Impedance 6–10 % voltage: ■ Connection: HV winding: star LV winding: star or delta ■ Taps on

3

4 HV rating

LV rating

No-load loss

Load loss at 75 °C

Total weight

Oil weight

Dimensions L/W/H

E

[kVA] ONAN

[kV]

[kV]

kW

[kW]

[kg]

[kg]

[mm]

[mm]

3150

10.9–36

3–24

4.8

29

9100

2300

3400/2300/2900

1070

4000

9.2–36

3–24

5.8

35

10300

2600

3500/2700/3000

1070

50–72.5

4–24

7.1

37

13700

4100

4150/2350/3600

1070

11.5–36

4–24

6.8

40

12300

3100

3600/2400/3200

1070

50–72.5

5–24

8.4

43

15200

4500

4200/2700/3700

1070

90–123

5–36

9.8

49

21800

8000

5300/2700/4650

1505

14.4–36

5–24

8.1

47

14000

3600

3700/2700/3300

1505

50–72.5

5–24

9.8

50

17000

5000

4300/2900/3850

1505

90–123

5–36

11.5

56

23000

8500

5600/2900/4650

1505

18.3–36

5–24

9.9

57

17000

4500

3850/2500/3500

1505

50–72.5

5–24

11.5

59

19700

6000

4600/2800/4050

1505

90–123

5–36

13.1

65

25500

9000

5650/2950/4650

1505

22.9–36

6–24

11.5

66

20000

5200

4400/2600/3650

1505

50–72.5

6–24

13.1

68

22500

6500

5200/2850/4100

1505

90–123

5–36

14.7

76

29500

10250

5750/2950/4700

1505

5000

9

10

L

Rated power

7

8

E W

Fig. 33

5

6

E

6300

8000

10000

Fig. 34

5/20

Ohne Namen-1


20

22.09.1999, 16:23 Uhr


Oil-immersed three-phase power transformers with off-load tap changer 10/16 to 20/31.5 MVA HV rating: up to 36 kV

1

H

2

Hs ■ Rated frequency: 50 Hz, tapping range ■ Connection of

± 2 x 2.5 % star

HV winding: ■ Connection of

star or delta LV winding: ■ Cooling method: ONAN/ONAF ■ LV range: 6 kV to 36 kV

3

L Ls

E W Ws

E

Fig. 35

4

Rated power at ONAF ONAN

No-load loss

Load loss at ONAN ONAF

Impedance voltage of ONAN ONAF

[MVA]

[MVA]

[kW]

[kW]

[kW]

[%]

[%]

10

16

12

31

80

6.3

10

12.5

20

14

37

95

6.3

10

16

25

16

45

110

6.4

10

20

31.5

19

52

130

6.4

10

5

6

7

Fig. 36

Rated power at ONAN ONAF [MVA]

[MVA]

10

16

12.5

Dimensions L x W x

H

Total weight

Oil weight

Shipping dimensions Ls x Ws

x Hs

Shipping weight incl. oil

[kg]

[kg]

[mm]

[kg]

3700 2350 3900

22

4200

3600 1550 2650

22000

20

3800 2350 4000

25

4500

3700 1600 2800

23000

16

25

3900 2400 4100

30

5000

3800 1600 2800

27000

20

31.5

4200 2450 4600

35

5700

3900 1650 3000

31500

[mm]

Fig. 37

5/21


Ohne Namen-1

21

22.09.1999, 16:23 Uhr

8

9

10


1

Oil-immersed three-phase power transformer with on-load tap changer 10/16 to 20/31.5 MVA, HV rating: up to 36 kV

H

2

Hs

■ Rated frequency: 50 Hz, tapping range ■ Connection of

3

± 16 % in ± 9 steps star

HV winding: ■ Connection of

star or delta LV winding: ■ Cooling method: ONAN/ONAF ■ LV range: 6 kV to 36 kV

Ls

Ws W

L

Fig. 38

4

Rated power at ONAN ONAF

No-load loss

Load loss at ONAN ONAF


[MVA]

[MVA]

[kW]

[kW]

[kW]

[%]

[%]

10

16

12

31

80

6.3

10

12.5

20

14

37

95

6.3

10

16

25

16

45

111

6.4

10

20

31.5

19

52

130

6.4

10

5

6

7

Fig. 39


8

9

10

[MVA]

[MVA]

10

16

12.5

Dimensions L x W x

H

Total weight [kg]

Oil weight

Shipping dimensions Ls x Ws

x Hs


[kg]

[mm]

[kg]

4800 2450 3900 27000

6200

4400 1550 2600

24000

20

4900 2500 4000 30000

6700

4500 1600 2650

27000

16

25

5050 2500 4100 34000

7000

4650 1650 2650

31000

20

31.5

5300 2550 4600 41 000

9000

5000 1700 3000

37000

[mm]

Fig. 40

5/22

Ohne Namen-1


22

22.09.1999, 16:24 Uhr


Oil-immersed three-phase power transformers with on-load tap changer 10/16 to 63/100 MVA, HV rating: from 72.5 to 145 kV ■ Rated frequency: 50 Hz, tapping range ■ Connection of

± 16 % in ± 9 steps star

HV winding: ■ Connection star or delta of LV winding: ■ Cooling method: ONAN/ONAF


No-load loss

Load loss at ONAN

ONAF


[MVA] [MVA]

[kW]

[kW]

[kW]

[%]

[%]

10

16

13

42

108

9.6

15.4

12.5

20

15

45

115

9.4

15.0

16

25

17

51

125

9.6

15.0

20

31.5

20

56

140

9.6

15.1

25

40

24

63

160

9.5

15.2

31.5

50

28

71

180

9.5

15.0

40

63

35

86

214

9.8

15.5

50

80

41

91

232

10.0

16.0

63

100

49

113

285

10.5

16.7

1

2

3

4

5

Fig. 41

Rated power at Dimensions ONAN ONAF L x W x [MVA]

[MVA]

H

[mm]

Total weight

Oil weight

Shipping dimensions Ls x Ws x Hs


[kg]

[kg]

[mm]

[kg]

10

16

6600 2650 4700

39000

12000

5200 1900

3000

35000

12.5

20

6700 2700 4800

43000

12500

5300 1950

3100

39000

16

25

6750 2750 5300

48000

13500

5400 2000

3000

43000

20

31.5

6800 2800 5400

54000

14000

5500 2000

3100

49000

25

40

6900 2900 5400

61000

14500

5700 2100

3150

56000

31.5

50

7050 2950 5500

70000

17000

5850 2150

3350

65000

40

63

7100 3000 5700

82000

18000

6100 2200

3450

75000

50

80

7400 3100 5800

97000

20500

6250 2300

3700

90000

63

100

7800 3250 6100

118000

25500

6800 2450

4000

109000

5/23


23

7

8

9

10

Fig. 42

Ohne Namen-1

6

22.09.1999, 16:24 Uhr

Power Transformers above 100 MVA

The power rating range above 100 MVA comprises mainly generator transformers and system-interconnecting transformers with off-load and/or on-load tap changers. Depending on the on-site requirements, they can be designed as transformers with separate windings or as autotransformers, threeor single-phase, for power ratings up to over 1000 MVA and voltages up to 1500 kV. We manufacture these units according to IEC 76, VDE 0532 or other national specifications. Offers for transformers larger than 100 MVA only on request.

1

2

3

4

5

6 Fig. 43: Coal-fired power station in Germany with two 850-MVA generator transformers: Low-noise design, extended setting range and continuous overload capacity up to 1100 MVA

7 7

8

9

10

1 2 3 4 5 6 7 8 9 10 11 12 13

12 Five-limb core LV winding HV winding Tapped winding Tap leads LV bushings HV bushings Clamping frame On-load tap changer Motor drive Schnabel-car-tank Conservator Water-cooling system 9 1

6

8

11

13

10 3 2

5 4

Fig. 44: View into an 850/1100-MVA generator transformer

5/24

Ohne Namen-1


24

22.09.1999, 16:24 Uhr

Power Transformers Monitoring System

Siemens Monitoring System: Efficient Condition Recording and Diagnosis for Power Transformers

1

2

Complete acquisition and evaluation of up to 45 measured variables, automatic trend analysis, diagnosis and early warning – the new Siemens Monitoring System makes use of all possible ways of monitoring power transformers: Round the clock, with precision sensors for voltage, temperature or quality of insulation, and with powerful software for measured data processing, display or documentation – with on-line communication over any distance. Maintenance and utilization of power transformers are made more efficient all-round. Because the comprehensive information provided on the condition of the equipment and auxiliaries ensures that maintenance is carried out just where it's needed, costly routine inspections are a thing of the past. And because the maintenance is always preventive, faults are reliably ruled out. All these advantages enhance availability – and thus ensure a long service life of your power transformers. This applies equally to new and old transformers. Equipping new transformers with the Siemens Monitoring System ensures that right from the start the user is in possession of all essential data–for quick, comprehensive analysis. And retrofitting on transformers already in service for considerable periods pays off as well. Particularly in the case of old transformers, constant monitoring significantly reduces the growing risk of failure. Offers for transformers larger 100 MVA only on request.

3

4

5

6

7

8

9 Fig. 45: An integrated solution – the complete Monitoring System housed in a cubicle of the transformer itself

10

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22.09.1999, 16:25 Uhr

On-load Tap Changers

1

2

3

4

5

6

7

8

9

10

The on-load tap changers installed in Siemens power transformers are manufactured by Maschinenfabrik Reinhausen (MR). MR is a supplier of technically advanced on-load tap changers for oil-immersed power transformers covering an application range from 100 A to 4,500 A and up to 420 kV. About 90,000 MR high-speed resistor-type tap changers are succesfully in service worldwide. The great variety of tap changer models is based on a modular system which is capable of meeting the individual customer’s specifications for the respective operating conditions of the transformer. Depending on the required application range selector, switches or diverter switches with tap selectors can be used, both available for neutral, delta or single-pole connection. Up to 107 operating positions can be achieved by the use of a multiple course tap selector. In addition to the well-known on-load tapchanger for installation in oil-immersed transformers, MR offers also a standardized gas-insulated tap changer for indoor installation which will be mounted on drytype transformers up to approx. 30 MVA and 36 kV, or SF6-type transformers up to 40 MVA and 123 kV. The main characteristics of MR products are: ■ Compact design ■ Optimum adaption and economic solutions offered by the great number of variants ■ High reliability ■ Long life ■ Reduced maintenance ■ Service friendliness The tap changers are mechanically driven – via the drive shafts and the bevel gear – by a motor drive attached to the transformer tank. It is controlled according to the step-by-step principle. Electrical and mechanical safety devices prevent overrunning of the end positions. Further safety measures, such as the automatic restart function, a safety circuit to prevent false phase sequence and running through positions, ensure the reliable operation of motor drives.

For operation under extremely onerous conditions an oil filter unit is available for filtering or filtering and drying of the switching oil. Voltage monitoring is effected by microprocessor-controlled operation control systems or voltage regulators which include a great variety of data input and output facilities. In combination with a parallel control unit, several transformers connected in parallel can be automatically controlled and monitored. Furthermore, Maschinenfabrik Reinhausen offers a worldwide technical service to maintain their high quality standard. Inspections at regular intervals with only small maintenance requirements guarantee the reliable operation expected with MR products.

Type VT Fig. 46: MR motor drive ED 100 S

Type V

Type H

Fig. 47: Gas-insulated on-load tap changer

Type M

Type G

Fig. 48: Selection of on-load tap changers from the MR product range

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Cast-resin Dry-type Transformers, GEAFOL

Standards and regulations GEAFOL® cast-resin dry-type transformers comply with IEC recommendation No. 726, CENELEC HD 464, HD 538 and DIN 42 523. Advantages and applications GEAFOL distribution and power transformers in ratings from 100 to more than 20 000 kVA and LI values up to 170 kV are full substitutes for oil-immersed transformers with comparable electrical and mechanical data. GEAFOL transformers are designed for indoor installation close to their point of use at the center of the major consumers.

They only make use of flame-retardent inorganic insulating materials which free these transformers from all restrictions that apply to oil-filled electrical equipment, such as oil-collecting pits, fire walls, fireextinguishing equipment, etc. GEAFOL transformers are installed wherever oil-filled units cannot be used: inside buildings, in tunnels, on ships, cranes and offshore platforms, in ground-water catchment areas, in food processing plants, etc. Often they are combined with their primary and secondary switchgear and distribution boards into compact substations that are installed directly at their point of use. As thyristor-converter transformers for variable speed drives they can be installed together with the converters at the drive

location. This reduces civil works, cable costs, transmission losses, and installation costs. GEAFOL transformers are fully LI-rated. They have similar noise levels to comparable oil-filled transformers. Taking the above indirect cost reductions into account, they are also frequently cost-competitive. By virtue of their design, GEAFOL transformers are completely maintenance-free for their lifetime. GEAFOL transformers have been in successful service since 1965. A lot of licenses have been granted to major manufactures throughout the world since.

1

2

3

4 Three-leg core

LV terminals Normal arrangement: Top, rear Special version: Bottom, available on request at extra charge

Made of grain-oriented, low-loss electrolaminations insulated on both sides

HV terminals

To insulate core and windings from mechanical vibrations, resulting in low noise emissions

Resilient spacers

Variable arrangements, for optimal station design. HV tapping links on lowvoltage side for adjustment to system conditions, reconnectable in de-energized state Permitting a 50% increase in the rated power

LV winding Temperature monitoring

Made of aluminum strip. Turns firmly glued together by means of insulating sheet wrapper material

By PTC thermistor detectors in the LV winding

Paint finish on steel parts Multiple coating, RAL 5009. On request: Two-component varnish or hot-dip galvanizing (for particularly aggressive environments)

Insulation: Mixture of epoxy resin and quartz powder Makes the transformer maintenance-free, moisture-proof, tropicalized, flame-resistant and selfextinguishing

Ambient class E2 Climatic category C2 (If the transformer is installed outdoors, degree of protection IP 23 must be assured)

Clamping frame and truck Rollers can be swung around for lengthways or sideways travel

Fire class F1

* on-load tap changers on request.

Fig. 49: GEAFOL cast-resin dry-type transformer

5/27


27

6

HV winding Consisting of vacuumpotted single foil-type aluminum coils. See enlarged detail in Fig. 50

Cross-flow fans

Ohne Namen-1

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22.09.1999, 16:25 Uhr

7

8

9

10


HV winding

1

2

3

4

5

6

7

8

9

10

The high-voltage windings are wound from aluminum foil, interleaved with highgrade polypropylene insulating foil. The assembled and connected individual coils are placed in a heated mold, and are potted in a vaccum furnace with a mixture of pure silica (quartz sand) and specially blended epoxy resins. The only connections to the outside are copper bushings, which are internally bonded to the aluminum winding connections. The external star or delta connections are made of insulated copper connectors to guarantee an optimal installation design. The resulting high-voltage windings are fire-resistant, moistureproof, corrosionproof, and show excellent aging properties under all indoor operating conditions. (For outdoor use, specially designed sheetmetal enclosures are available.) The foil windings combine a simple winding technique with a high degree of electrical safety. The insulation is subjected to less electrical stress than in other types of windings. In a conventional round-wire winding, the interturn voltage can add up to twice the interlayer voltage, while in a foil winding it never exeeds the voltage per turn because a layer consists of only one winding turn. Result: a high AC voltage and impulse-voltage withstand capacity. Why aluminum? The thermal expansion coefficients of aluminum and cast resin are so similar that thermal stresses resulting from load changes are kept to a minimum (see Fig. 50).

8 8

U

7

1

7 6 5

LV winding

4

The standard low-voltage winding with its considerably reduced dielectric stresses is wound from single aluminum sheets with interleaved cast-resin impregnated fiberglass fabric. The assembled coils are then oven-cured to form uniformly bonded solid cylinders that are impervious to moisture. Through the single-sheet winding design, excellent dynamic stability under short-circuit conditions is achieved. Connections are submerged-arc-welded to the aluminum sheets and are extended either as aluminum or copper busbars to the secondary terminals.

Round-wire winding

6 4

3

3

2

2

2

8

3

7

4

6 5

1

Strip winding

U

2 4 6 8

2

3

4

5

6

7

8

1

2

3

4

5

6

7

1 3 5 7

Fig. 50: High-voltage encapsulated winding design of GEAFOL cast-resin transformer and voltage stress of a conventional round-wire winding (above) and the foil winding (below)

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Fire safety GEAFOL transformers use only flameretardent and self-extinguishing materials in their construction. No additional substances, such as aluminum oxide trihydrate, which could negatively influence the mechanical stability of the cast-resin molding material, are used. Internal arcing from electrical faults and externally applied flames do not cause the transformers to burst or burn. After the source of ignition is removed, the transformer is self-extinguishing. This design has been approved by fire officials in many countries for installation in populated buildings and other structures. The environmental safety of the combustion residues has been proven in many tests. Categorization of cast-resin transformers Dry-type transformers have to be categorized under the sections listed below: ■ Environmental category ■ Climatic category ■ Fire category These categories have to be shown on the rating plate of each dry-type transformer.

The properties laid down in the standards for ratings within the approximate category relating to environment (humidity), climate and fire behavior have to be demonstrated by means of tests. These tests are described for the environmental category (code number E0, E1 and E2) and for the climatic category (code number C1, C2) in DIN VDE 0532 Part 6 (corresponding to HD 464). According to this standard, they are to be carried out on complete transformers. The tests of fire behavior (fire category code numbers F0 and F1) are limited to tests on a duplication of a complete transformer. It consists of a core leg, a low-voltage winding and a high-voltage winding. The specifications for fire category F2 are determined by agreement between the manufacturer and the customer. Siemens have carried out a lot of tests. The results for our GEAFOL transformers are something to be proud of: ■ Environmental category E2 ■ Climatic category C2 ■ Fire category F1 This good behavior is solely due to the GEAFOL cast-resin mix which has been used successfully for decades.

Insulation class and temperature rise The high-voltage winding and the lowvoltage winding utilize class F insulating materials with a mean temperature rise of 100 K (standard design).

1

Overload capability

2

GEAFOL transformers can be overloaded permanently up to 50% (with a corresponding increase in impedance voltage) if additional radial cooling fans are installed. (Dimensions increase by approximately 200 mm in length and width.) Short-time overloads are uncritical as long as the maximum winding temperatures are not exceeded for extended periods of time.

4

Temperature monitoring Each GEAFOL transformer is fitted with three temperature sensors installed in the LV winding, and a solid-state tripping device with relay output. The PTC thermistors used for sensing are selected for the applicable maximum hot-spot winding temperature. Additional sets of sensors with lower temperature points can be installed for them and for fan control purposes. Additional dial-type thermometers and Pt100 are available, too. For operating voltages of the LV winding of 3.6 kV and higher, special temperature measuring equipment can be provided. Auxiliary wiring is run in protective conduit and terminated in a central LV terminal box (optional). Each wire and terminal is identified, and a wiring diagram is permanently attached to the inside cover of this terminal box.

Indoor installation in electrical operating rooms or in various sheet-metal enclosures is the preferred method of installation. The transformers need only be protected against access to the terminals or the winding surfaces, against direct sunlight, and against water. Sufficient ventilation must be provided by the installation location or the enclosure. Otherwise forced-air cooling must be specified or provided by others.

Fig. 51: Flammability test of cast-resin transformer

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5

6

7

8

Installation and enclosures


3

9

10


1

2

3

4

5

6

7

Instead of the standard open terminals, insulated plug-type elbow connectors can be supplied for the high-voltage side with LI ratings up to 170 kV. Primary cables are usually fed to the transformer from trenches below, but can also be connected from above. Secondary connections can be made by multiple insulated cables, or by busbars, from either below or above. Secondary terminals are either aluminum or copper busbar stubs, drilled to specification. A variety of indoor and outdoor enclosures in different protection classes are available for the transformers alone, or for indoor compact substations in conjunction with high- and low-voltage switchgear cubicles. Recycling of GEAFOL transformers Of all the GEAFOL transformers manufactured since 1965, even the oldest units are not about to reach the end of their service life expectancy. In spite of this, a lot of experiences have been made over the years with the recycling of coils that have become unusable due to faulty manufacture or damage. These experiences show that all the metallic components, i.e. approx. 90% of all materials, can be fully recovered economically. The recycling method used by Siemens does not pollute the environment. In view of the value of the secondary raw materials, the procedure can be economical even considering the currently small amounts.

Fig. 52: GEAFOL transformer with plug-type cable connections

8

9

10

Fig. 53: Radial cooling fans on GEAFOL transformer for AF cooling

5/30

Ohne Namen-1

Fig. 54: GEAFOL transformer in protective housing to IP 20/40


30

22.09.1999, 16:26 Uhr

GEAFOL Cast-resin Selection Tables, Technical Data, Dimensions and Weights

■ ■ ■ ■ ■

■ ■ ■

■ ■ ■

Standard: DIN 42523 Rated power: 100–20000 kVA* Rated frequency: 50 Hz HV rating: up to 36 kV LV rating: up to 780 V; special designs for up to 12 kV are possible Tappings on ± 2.5 % or ± 2 x 2.5 % HV side: Connection: HV winding: delta LV winding: star Impedance 4–8 % voltage at rated current: Insulation class: HV/LV = F/F Temperature HV/LV = 100/100 K rise: Color of metal RAL 5009 (other parts: colors are available)

Um [kV]

LJ [kV]

AC [kV]

1.1

–

3

12

75

28

24

95**

50

36

145**

70

1

* power rating > 2.5 MVA upon request ** other levels upon request

2

Fig. 55: Insulation level

2U

2V

2N

2W

3 H1

4 E B1

E A1

5

Fig. 56: GEAFOL cast-resin transformer

Rated power

Rated Impevoltage dance voltage

Type

Sound power level

Total weight

Pk 75* [W]

Sound Load losses press. level 1m tolerance + 3 dB Pk 120** LPA [W] [dB]

LWA [dB]

GGES [kg]

A1 [mm]

B1 [mm]

No-load Load losses losses

Width

Height

Distance between wheel centers

6

Sn [kVA]

Um [kV]

U2 [%]

4GB…

100

12

4

.5044-3CA

440

1600

1900

45

59

630

1210

705

835

without wheels

4

.5044-3GA

320

1600

1900

37

51

760

1230

710

890

without wheels

6

.5044-3DA

360

2000

2300

45

59

590

1190

705

860

without wheels

6

.5044-3HA

300

2000

2300

37

51

660

1230

710

855

without wheels

4

.5064-3CA

600

1500

1750

45

59

750

1310

755

935

without wheels

4

.5064-3GA

400

1500

1750

37

51

830

1300

755

940

without wheels

6

.5064-3DA

420

1800

2050

45

59

660

1250

750

915

without wheels

6

.5064-3HA

330

1800

2050

37

51

770

1300

755

930

without wheels

4

.5244-3CA

610

2300

2600

47

62

770

1220

710

1040

520

4

.5244-3GA

440

2300

2600

39

54

920

1290

720

1050

520

6

.5244-3DA

500

2300

2700

47

62

750

1270

720

990

520

6

.5244-3HA

400

2300

2700

39

54

850

1300

725

985

520

4

.5264-3CA

800

2200

2500

47

62

910

1330

725

1090

520

4

.5264-3GA

580

2200

2500

39

54

940

1310

720

1095

520

6

.5264-3DA

600

2500

2900

47

62

820

1310

725

1075

520

6

.5264-3HA

480

2500

2900

39

54

900

1350

765

1060

520

24

160

12

24

P0 [W]

Dimensions Length

H1 [mm]

E [mm]

7

Dimensions and weights are approximate values and valid for 400 V on the secondary side, vector-group can be Dyn 5 or Dyn 11. * In case of short-circuits at 75 °C ** In case of short-circuits at 120 °C

Fig. 57: GEAFOL cast-resin transformers 50 to 2500 kVA

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22.09.1999, 16:26 Uhr

9

10

Rated power figures in parentheses are not standardized.


8


1

2

Rated power


Sn [kVA]

Um [kV]

U2 [%]

250

12

4

.5444-3CA

4

.5444-3GA

6 6

Sound power level

Total weight

Pk 75* [W]

LWA [dB]

GGES [kg]

820

3000

3500

50

65

600

3000

3400

42

57

.5444-3DA

700

2900

3300

50

.5444-3HA

570

2900

3300

4

.5464-3CA

1050

2900

4

.5464-3GA

800

2900

6

.5464-3DA

880

6

.5464-3HA

36

6

12

4

24

4

5 24

6

7

400

9 (500)

Dimensions Length

Width

Height


A1 [mm]

B1 [mm]

H1 [mm]

E [mm]

1040

1330

730

1110

520

1170

1330

730

1135

520

65

990

1350

740

1065

520

42

57

1120

1390

745

1090

520

3300

50

65

1190

1390

735

1120

520

3300

41

57

1230

1400

735

1150

520

3100

3600

50

65

990

1360

735

1140

520

650

3100

3600

41

57

1180

1430

745

1160

520

.5475-3DA

1300

3800

4370

50

65

1700

1900

900

1350

520

.5544-3CA

980

3300

3800

52

67

1160

1370

820

1125

670

4

.5544-3GA

720

3300

3800

43

59

1320

1380

820

1195

670

6

.5544-3DA

850

3400

3900

51

67

1150

1380

830

1140

670

6

.5544-3HA

680

3400

3900

43

59

1290

1410

830

1165

670

4

.5564-3CA

1250

3400

3900

51

67

1250

1410

820

1195

670

4

.5564-3GA

930

3400

3900

43

59

1400

1440

825

1205

670

6

.5564-3DA

1000

3600

4100

51

67

1190

1410

825

1185

670

4GB…

P0 [W]

6

.5564-3HA

780

3600

4100

43

59

1300

1460

830

1195

670

36

6

.5575-3DA

1450

4500

5170

51

67

1900

1950

920

1400

670

12

4

.5644-3CA

1150

4300

4900 52

68

1310

1380

820

1265

670

4

.5644-3GA

880

4300

4900 44

60

1430

1380

820

1290

670

6

.5644-3DA

1000

4300

4900 52

68

1250

1410

825

1195

670

6

.5644-3HA

820

4300

4900 44

60

1350

1430

830

1195

670

4

.5664-3CA

1450

3900

4500 52

68

1410

1440

825

1280

670

4

.5664-3GA

1100

3900

4500 44

60

1570

1460

830

1280

670

6

.5664-3DA

1200

4100

4700 52

68

1350

1480

835

1275

670

6

.5664-3HA

940

4100

4700 44

60

1460

1480

835

1280

670

36

6

.5675-3DA

1700

5100

5860 52

68

2100

2000

920

1440

670

12

4

.5744-3CA

1350

4900

5600 53

69

1520

1410

830

1320

670

4

.5744-3GA

1000

4900

5600 45

61

1740

1450

835

1345

670

6

.5744-3DA

1200

5600

6400 53

69

1470

1460

845

1275

670

6

.5744-3HA

980

5600

6400 45

61

1620

1490

845

1290

670

4

.5764-3CA

1700

4800

5500 53

69

1620

1500

835

1330

670

4

.5764-3GA

1270

4800

5500 44

61

1830

1540

840

1350

670

6

.5764-3DA

1400

5000

5700 53

69

1580

1540

850

1305

670

6

.5764-3HA

1100

5000

5700 45

61

1720

1560

850

1320

670

6

.5775-3DA

1900

6000

6900 53

69

2600

2050

940

1500

670

24

8



3

(315)

Type

10 24

36

Dimensions and weights are approximate values and valid for 400 V on the secondary side, vector-group can be Dyn 5 or Dyn 11.


* In case of short-circuits at 75 °C ** In case of short-circuits at 120 °C


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Rated power


Sound power level

Total weight

Sn [kVA]

Um [kV]

U2 [%]

4GB…

P0 [W]

LWA [dB]

630

12

4

.5844-3CA

1500

6400

7300

54

4

.5844-3GA

1150

6400

6

.5844-3DA

1370

6400

7300 7400

6

.5844-3HA

1150

6400

4

.5864-3CA

1950

4 6

.5864-3GA .5864-3DA

6 36

6

12

24

(800)

24

1000


Length

Width

Height


GGES [kg]

A1 [mm]

B1 [mm]

H1 [mm]

E [mm]

70

1830

1510

840

1345

670

45

62

2070

1470

835

1505

670

54

70

1770

1550

860

1295

670

7400

45

62

1990

1590

865

1310

670

6000

6900

53

70

1860

1550

845

1380

670

1500

6000

6900

45

62

2100

1600

850

1400

670

1650

6400

7300

53

70

1810

1580

855

1345

670

.5864-3HA

1250

6400

7300

45

62

2050

1620

860

1370

670

.5875-3DA

2200

7000

8000

53

70

2900

2070

940

1650

670

4

.5944-3CA

1850

7800

9000

55

72

2080

1570

850

1560

670

4

.5944-3GA

1450

7800

9000

47

64

2430

1590

855

1640

670

6

.5944-3DA

1700

7600

8700

55

72

2060

1560

865

1490

670

6

.5944-3HA

1350

7600

8700

47

64

2330

1600

870

1530

670

4

.5964-3CA

2100

7500

8600

55

72

2150

1610

845

1580

670

4

.5964-3GA

1600

7500

8600

47

64

2550

1650

855

1620

670

6

.5964-3DA

1900

7900

9100

55

71

2110

1610

860

1590

670

6

.5964-3HA

1450

7900

9100

47

64

2390

1630

865

1595

670

Pk 75* [W]


Dimensions

36

6

.5975-3DA

2600

8200

9400

55

72

3300

2140

950

1850

670

12

4

.6044-3CA

2200

8900 10200

55

73

2480

1590

990

1775

820

4

.6044-3GA

1650

8900 10200

47

65

2850

1620

990

1795

820

6

.6044-3DA

2000

8500

9700

56

73

2420

1620

990

1560

820

6

.6044-3HA

1500

8500

9700

47

65

2750

1660

990

1560

820

4

.6064-3CA

2400

8700 10000

55

73

2570

1660

990

1730

820

4

..6064-3GA

1850

8700 10000

47

65

3060

1680

990

1815

820

6

.6064-3DA

2300

9200 10500

55

73

2510

1680

990

1620

820

24

(1250)

Type

6

.6064-3HA

1750

9600 11000

47

65

2910

1730

990

1645

820

36

6

.6075-3DA

3000

9500 10900

55

73

3900

2200

1050

1900

820

12

6

.6144-3DA

2400

9600 11000

57

75

2900

1780

990

1605

820

6

.6144-3HA

1850

10500 12000

49

67

3370

1790

990

1705

820

6

.6164-3DA

2700

10000 11500

57

75

3020

1820

990

1635

820

6

.6164-3HA

2100

10500 12000

49

67

3490

1850

990

1675

820

6

.6175-3DA

3500

11000 12600

57

75

4500

2300

1060

2000

520

24 36


1

2

3

4

5

6

7

8

9

10


* In case of short-circuits at 75 °C ** In case of short-circuits at 120 °C


5/33


Ohne Namen-1

33

22.09.1999, 16:26 Uhr


1

2

Total weight

LWA [dB]

58

11400 13000

3100 2400

.6275-3DA

6


Sound Load losses press. level 1m tolerance + 3 dB

Length

Height


GGES [kg]

A1 [mm]

B1 [mm]

H1 [mm]

E [mm]

76

3550

1840

995

2025

1070

50

68

4170

1880

1005

2065

1070

11800 13500

58

76

3640

1880

995

2035

1070

12300 14000

49

68

4080

1900

1005

2035

1070

4300

12700 14600

58

76

5600

2500

1100

2400

1070

.6344-3DA

3600

14000 16000

59

78

4380

1950

1280

2150

1070

6

.6344-3HA

2650

14500 16500

51

70

5140

1990

1280

2205

1070

6

.6364-3DA

4000

14500 16500

59

78

4410

2020

1280

2160

1070

6

.6364-3HA

3000

14900 17000

51

70

4920

2040

1280

2180

1070

36

6

.6375-3DA

5100

15400 17700

59

78

6300

2500

1280

2400

1070

12

6

.6444-3DA

4300

17600 20000

62

81

5130

2110

1280

2150

1070

6

.6444-3HA

3000

18400 21000

51

71

6230

2170

1280

2205

1070

6

.6464-3DA

5000

17600 20000

61

81

5280

2170

1280

2160

1070

6

.6464-3HA

3600

18000 20500

51

71

6220

2220

1280

2180

1070

6

.6475-3DA

6400

18700 21500

61

81

7900

2700

1280

2400

1070

Sn [kVA]

Um [kV]

U2 [%]

4GB…

P0 [W]

Pk 75* Pk 120** LPA [W] [W] [dB]

1600

12

6

.6244-3DA

2800

11000 12500

6

.6244-3HA

2100

6

.6264-3DA

6

.6264-3HA

36

6

12

24

(2000)

4 24

2500

24

6

36


7

Dimensions Width

ImpeRated voltage dance voltage

3

5

Sound power level

Type

Rated power


* In case of short-circuits at 75 °C ** In case of short-circuits at 120 °C Rated power >2500 kVA to 20 MVA on request.


8

9

10

5/34

Ohne Namen-1


34

22.09.1999, 16:26 Uhr

Special Transformers

GEAFOL cast-resin transformers with oil-free tap-changers The voltage-regulating cast-resin transformers connected on the load side of the medium-voltage power supply system feed the plant-side distribution transformers. The tap-changer-controlled transformers used in these medium-voltage systems need to have appropriately high ratings. Siemens offers suitable transformers in its GEAFOL design which has proved successful over many years and is available in ratings of up to 20 MVA. With forced cooling it is even possible to increase the power ratings still further by 40%. The range of rated voltage extends to 36 kV and the maximum impulse voltage is 200 kV. The main applications of this type of transformer are in modern industrial plants, hospitals, office and appartment blocks and shopping centers.

Linking single-pole tap-changer modules together in threes by means of insulating shafts produces a triple-pole tap-changer in either star or delta connection for regulating the output voltage of GEAFOL transformers. In its nine operating positions, this type of tap-changer has a rated through-current of 500 A and a rated voltage of 900 V per step. This allows voltage fluctuations of up to 8100 V to be kept under control. However, the maximum control range utilizes only 20% of the rated voltage.

1

2

3

4

5

6

7

8

9

10

Fig. 61: 16/22-MVA GEAFOL cast-resin transformer with oil-free on-load tap changer

5/35


Ohne Namen-1

35

22.09.1999, 16:26 Uhr

Special Transformers

1

2

3

4

5

6

Transformers for thyristor converters These are special oil-immersed or castresin power transformers that are designed for the special demands of thyristor converter or diode rectifier operation. The effects of such conversion equipment on transformers and additional construction requirements are as follows: ■ Increased load by harmonic currents ■ Balancing of phase currents in multiple winding systems (e.g. 12-pulse systems) ■ Overload factor up to 2.5 ■ Types for 12-pulse systems, if required. Siemens supplies oil-filled converter transformers of all ratings and configurations known today, and dry-type cast-resin converter transformers up to more than 20 MVA and 200 kV LI. To define and quote for such transformers, it is necessary to know considerable details on the converter to be supplied and on the line feeding it. These transformers are almost exclusively inquired together with the respective drive or rectifier system and are always custom-engineered for the given application.

Neutral grounding transformers 7

8

9

10

When a neutral grounding reactor or ground-fault neutralizer is required in a three-phase system and no suitable neutral is available, a neutral must be provided by using a neutral grounding transformer. Neutral grounding transformers are available for continuous operation or short-time operation. The zero impedance is normally low. The standard vector groups are zigzag or wye/delta. Some other vector groups are also possible. Neutral grounding transformers can be built by Siemens in all common power ratings. Normally, the neutral grounding transformers are built in oil-immersed design, however, they can also be built in cast-resin design.

5/36

Ohne Namen-1

Fig. 62: Dry-type converter transformer GEAFOL

For further information please contact: Distribution transformers: Fax: ++49-7021-508548 Power transformers: Fax: ++49-911-4342147


36

22.09.1999, 16:27 Uhr

Protection and Substation Control Contents

Page

Local and Remote Control Introduction ................................. 6/71 SINAUT LSA Overview ...................................... 6/74 SINAUT LSA Substation automation distributed structure .................. 6/78 SINAUT LSA Substation automation centralized structure (Enhanced RTU) .......................... 6/91 SINAUT LSA Compact remote terminal units .............................. 6/93 SICAM Overview ........................ 6/96 SICAM RTU Remote terminal units (RTUs) ................................. 6/97 SICAM SAS Substation automation ............ 6/108 SICAM PCC Substation automation ............ 6/118

Contents

Device dimensions .................. 6/125

Page

General overview ........................ 6/2

Power Quality

Application hints ......................... 6/4

Introduction ............................... 6/131

Power System Protection

Measuring and recording ...... 6/132

Introduction ................................... 6/8

Compensation systems Introduction ............................... 6/146

Relay selection guide ................ 6/22

Passive compensation systems ...................................... 6/147

Relay portraits ............................ 6/25 Typical protection schemes ..... 6/42

Active compensation systems ...................................... 6/154

Protection coordination ............ 6/62

6

Protection and Substation Control General Overview

General overview 1

2

3

Three trends have emerged in the sphere of substation secondary equipment: intelligent electronic devices (IEDs), open communication and operation with a PC. Numerical relays and cumputerized substation control are now state-of-the-art. The multitude of conventional, individual devices prevalent in the past as well as comprehensive parallel wiring are being replaced by a small number of multifunctional devices with serial connections.

System control centers IEC 60870-5-101 SICAM WinCC

SICAM plusTools

GPS

Monitoring and control PROFIBUS

Engineering, Parameterizing

Automation

Wire RS485

IEC 60 870-5-103 SIPROTEC-IEDs: – Relays O.F. – Bay control units – Transducers – etc.

One design for all applications

4

5

6

7

In this respect, Siemens offers a uniform, universal technology for the entire functional scope of secondary equipment, both in the construction and connection of the devices and in their operation and communication. This results in uniformity of design, coordinated interfaces and the same operating concept being established throughout, whether in power system and generator protection, in measurement and recording systems, in substation control and protection or in telecontrol. All devices are highly compact and immune to interference, and are therefore also suitable for direct installation in switchgear cells. Furthermore, all devices and systems are largely self-monitoring, which means that previously costly maintenance can be reduced considerably.

Fig. 1: The digital substation control system SICAM implements all of the control, measurement and automation functions of a substation. Protection relays are connected serially

“Complete technology from one partner“

8

9

10

The Protection and Substation Control Systems Division of the Siemens Power Transmission and Distribution Group supplies devices and systems for: ■ Power System Protection ■ Substation Control ■ Remote Control (RTUs) ■ Measurement and Recording ■ Monitoring and Conditioning of Power Quality This covers all of the measurement, control, automation and protection functions for substations*. Furthermore, our activities cover: ■ Consulting ■ Planning ■ Design ■ Commissioning and Service This uniform technology ”all from one source“ saves the user time and money in the planning, assembly and operation of his substations. *An exception is revenue metering. Meters are separate products of our Metering Division.

6/2

Fig. 2a: Protection and control in HV GIS switchgear

Fig. 2b: Protection and control in bay dedicated kiosks of an EHV switchyard

Rationalization of operation

by means of SCADA-like operation control and high-performance, uniformly operable PC tools

Savings in terms of space and costs

by means of integration of many functions into one unit and compact equipment design

Simplified planning and operational reliability

by means of uniform design, coordinated interfaces and universally identical EMC

Efficient parameterization and operation

by means of PC tools with uniform operator interface

High levels of reliability and availability

by means of type-tested system technology, complete self-monitoring and the use of proven technology – 20 years of practical experience with digital protection, more than 150,000 devices in operation (1999) – 15 years of practical experience with substation automation (SINAUT LSA and SICAM), over 1500 substations in operation (1999)

Fig. 3: For the user, “complete technology from one source” has many advantages



1

Protection and substation automation

Substation automation SICAM/SINAUT LSA

SINAUT LSA

SICAM SAS

Substation automation systems, centralized and decentralized

Substation automation systems, LAN-based (Profibus)

Protection SIPROTEC

Power quality SIMEAS/SIPCON

Feeder protection overcurrent/overload relays

SIMEAS R

7SJ5 and 7SJ6

Energy automation based on PC and LAN (Profibus)

SICAM RTU Enhanced RTU 6MD2010

SINAUT LSA

3

4

Power quality recorders

7SA5

SICAM PCC

Fault recorders (Oscillostores)

SIMEAS Q, M, N

Line protection distance relays Remote terminal units

2

Line protection pilot protection relays

SIMEAS T

7SD5

Measuring transducers

Transformer protection

SIPCON

7UT5

Power conditioners

5

6

Compact unit

6MB552

Generator/motor protection

Minicompact unit

7UM5

6MB553

7 Busbar protection 7SS5 and 7VH8

8

Fig. 4: Siemens Protection and Substation Control comprises these systems and product ranges

System Protection Siemens offers a complete spectrum of multifunctional, numerical relays for all applications in the field of network and machine protection. Uniform design and electromagnetic-interference-free construction in metal housings with conventional connection terminals in accordance with public utility requirements assure simple system design and usage just as with conventional relays. Numerical measurement techniques ensure precise operation and necessitate less maintenance thanks to their continuous self-monitoring capability.

The integration of additional protection and other functions, such as real-time operational measurements, event and fault recording, all in one unit economizes on space, design and wiring costs. Setting and programming of the devices can be performed through the integral, plaintext, menu-guided operator display or by using the comfortable PC program DIGSI for Windows*. Open serial interfaces, IEC 870-5-103-compliant, allow free communication with higher level control systems, including those from other manufacturers. Connection to a Profibus substation LAN is optionally possible.

Thus the on-line measurements and fault data registered in the protective relays can be used for local and remote control or can be transmitted via telephone modem connections to the workplace of the service engineer. Siemens supplies individual devices as well as complete protection systems in factory finished cubicles. For complex applications, for example, in the field of extrahigh-voltage transmission, type and design test facilities are available together with an extensive and comprehensive network model using the most modern simulation and evaluation techniques.

* Windows is a registered product of Microsoft


6/3

9

10


1

2

3

4

5

6

7

8

9

10

Substation control

Switchgear interlocking

Advantages for the user

The digital substation control systems SICAM and SINAUT LSA provide all control, measurement and automation functions (e.g. transformer tap changing) required by a switching station. They operate with distributed intelligence. Communication between feeder-located devices and central unit is made via interferencefree fiber optic connections. Devices are extremely compact and can be built directly into medium and high-voltage switchgear. To input data, set and program the system, the unique PC programs SICAM PlusTools and LSA-TOOLS are available. Parameters and values are input at the central unit and downloaded to the field devices, thus ensuring error-free and consistent data transfer. The operator interface is menu-guided, with SCADA comparable functions, that is, with a level of convenience which was previously only available in a network control center. Optional telecontrol functions can be added to allow coupling of the system to one or more network control centers. In contrast to conventional controls, digital technology saves enormously on space and wiring. SICAM and LSA systems are subjected to full factory tests and are delivered in fully functional condition.

The digital interlocking system 8TK is used for important substations in particular with multiple busbar arrangements. It prevents false switching and provides an additional local bay control function which allows failsafe switching, even when the substation control system is not available. Therefore the safety of operating personnel and equipment is considerabely enhanced. The 8TK system can be used as a standalone interlocked control, or as back-up system together with the digital 6MB substation control.

The concept of ”Complete technology from one partner“ offers the user many advantages: ■ High-level security for his systems and operational rationalization possibilities – powerful system solutions with the most modern technology – compliance with international standards ■ Integration in the overall system SIPROTEC-SICAM-SIMATIC ■ Space and cost savings – integration of many functions into one unit and compact equipment packaging ■ Simple planning and secure operation – unified design, matched interfaces and EMI security throughout ■ Rationalized programming and handling – menu-guided PC Tools and unified keypads and displays ■ Fast, flexible mounting, reduced wiring ■ Simple, fast commissioning ■ Effective spare part stocking, high flexibility ■ High-level operational security and availability – continuous self-monitoring and proven technology: – 20 years digital relay experience (more than 150,000 units in operation) – 10 years of SINAUT LSA and SICAM substation control (more than 1500 systems in operation) ■ Rapid problem solving – comprehensive advice and fast response from local sales and workshop facilities worldwide.

Remote control Siemens remote control equipment 6MB55* and 6MD2010 fulfills all the classic functions of remote measurement and control. Furthermore, because of the powerful microprocessors with 32-bit technology, they provide comprehensive data preprocessing, automation functions and bulk storage of operational and fault information. In the classic case, connections to the switchgear are made through coupling relays and transducers. This method allows an economically favorable solution when modernizing or renewing the secondary systems in older installations. Alternatively, especially for new installations, direct connection is also possible. Digital protection devices can be connected by serial links through fiber-optic conductors. In addition, the functions ”operating and monitoring“ can be provided by the connection of a PC, thus raising the telecontrol unit to the level of a central station control system. Using the facility of nodal functions, it is also possible to build regional control points so that several substations can be controlled from one location.

6/4

Power Quality (Measurement, recording and power compensation) The SIMEAS product range offers equipment for the superversion of power supply quality (harmonic content, distortion factor, peak loads, power factor, etc.), fault recorders (Oscillostore), data logging printers and measurement transducers. Stored data can be transmitted manually or automatically to PC evaluation systems where it can be analyzed by intelligent programs. Expert systems are also applied here. This leads to rapid fault analysis and valuable indicators for the improvement of network reliability. For local bulk data storage and transmission, the central processor DAKON can be installed at substation level. Data transmission circuits for analog telephone or digital ISDN networks are incorporated as standard. Connection to local or wide-area networks (LAN, WAN) is equally possible. We also have the SIMEAS T series of compact and powerful measurement transducers with analog and digital outputs. The SIPCON Power Conditioner solves numerous system problems. It compensates (for example) unbalanced loads or system voltage dips and suppresses system harmonics. It performs these functions so that sensitive loads are assured of suitable voltage quality at all times. In addition, the system ist also capable of eliminating the perturbation produced by irregular loads. The use of SIPCON can enable energy suppliers worldwide to provide the end consumer with distinctive quality of supply.

Application hints All named devices and systems for protection, metering and control are designed to be used in the harsh environment of electrical substations, power plants and the various industrial application areas. When the devices were developed, special emphasis was placed on EMI. The devices are in accordance with IEC 60 255 standards. Detailed information is contained in the device manuals. Reliable operation of the devices is not affected by the usual interference from the switchgear, even when the device is mounted directly in a low-voltage compartment of a medium-voltage cubicle.


Protection and Substation Control Application Hints

It must, however, be ensured that the coils of auxiliary relays located on the same panel, or in the same cubicle, are fitted with suitable spike quenching elements (e.g. free-wheeling diodes). When used in conjunction with switchgear for 100 kV or above, all external connection cables should be fitted with a screen grounded at both ends and capable of carrying currents. That means that the cross section of the screen should be at least 4 mm2 for a single cable and 2.5 mm2 for multiple cables in one cable duct. All equipment proposed in this guide is built-up either in closed housings (type 7XP20) or cubicles with protection degree IP 51 according to IEC 60 529: ■ Protected against access to dangerous parts with a wire ■ Sealed against dust ■ Protected against dripping water

Electromagnetic compatibility

All Siemens protection and control products recommended in this guide comply with the EMC Directive 99/336/EEC of the Council of the European Community and further relevant IEC 255 standards on electromagnetic compatibility. All products carry the CE mark.

Vibration and shock during operation ■ Standards:

IEC 60 255-21 and IEC 60068-2 ■ Vibration – sinusoidal IEC 60 255-21-1, class 1 – 10 Hz to 60 Hz: ± 0.035 mm amplitude; IEC 600 68-2-6 – 60 Hz to 150 Hz: 0.5 g acceleration sweep rate 10 octaves/min 20 cycles in 3 orthogonal axes

3

■ Standards:

■

■

■ Permissible temperature during

Mechanical stress

2

EMC tests; immunity (type tests)

Climatic conditions: service –5 °C to +55 °C permissible temperature during storage –25 °C to +55 °C permissible temperature during transport –25 °C to +70 °C Storage and transport with standard works packaging ■ Permissible humidity Mean value per year ≤ 75% relative humidity; on 30 days per year 95% relative humidity; Condensation not permissible We recommend that units be installed such that they are not subjected to direct sunlight, nor to large temperature fluctuations which may give rise to condensation.

1

EC Conformity declaration (CE mark):

■

Fig. 5: Installation of the numerical protection in the door of the low-voltage section of medium-voltage cell ■

Vibration and shock during transport ■ Standards:

IEC 60255-21and IEC 60068-2 ■ Vibration

– sinusoidal IEC 60255-21-1, class 2 – 5 Hz to 8 Hz: ± 7.5 mm amplitude; IEC 60068-2-6 – 8 Hz to 150 Hz: 2 g acceleration sweep rate 1 octave/min 20 cycles in 3 orthogonal axes ■ Shock IEC 60255 -21-2, class 1 IEC 60068 -2-27

■

■

■

Insulation tests ■ Standards:

IEC 60255-5 – High-voltage test (routine test) 2 kV (rms), 50 Hz – Impulse voltage test (type test) all circuits, class III 5 kV (peak); 1.2/50 µs; 0.5 J; 3 positive and 3 negative shots at intervals of 5 s


■

IEC 60255-22 (product standard) EN 50082-2 (generic standard) High frequency IEC 60255-22-1 class III – 2.5 kV (peak); 1 MHz; τ = 15 µs; 400 shots/s; duration 2 s Electrostatic discharge IEC 60255-22-2 class III and EN 61 000-4-2 class III – 4 kV contact discharge; 8 kV air discharge; both polarities; 150 pF; Ri = 330 Ohm Radio-frequency electromagnetic field, nonmodulated; IEC 60255-22-3 (report) class III – 10 V/m; 27 MHz to 500 MHz Radio-frequency electromagnetic field, amplitude-modulated; ENV 50140, class III – 10 V/m; 80 MHz to 1000 MHz, 80%; 1 kHz; AM Radio-frequency electromagnetic field, pulse-modulated; ENV 50140/ENV 50 204, class III – 10 V/m; 900 MHz; repetition frequency 200 Hz; duty cycle 50% Fast transients IEC 60255-22-4 and EN 61000-4-4, class III – 2 kV; 5/50 ns; 5 kHz; burst length 15 ms; repetition rate 300 ms; both polarities; Ri = 50 Ohm; duration 1 min Conducted disturbances induced by radio-frequency fields HF, amplitude-modulated ENV 50141, class III – 10 V; 150 kHz to 80 MHz; 80%; 1kHz; AM Power-frequency magnetic field EN 61000-4-8, class IV – 30 A/m continuous; 300 A/m for 3 s; 50 Hz

6/5

4

5

6

7

8

9

10


1

EMC tests; emission (type tests)

Cores for revenue metering

■ Standard:

In this case, class 0.2 M is normally required.

EN 50081-2 (generic standard) ■ Interference field strength CISPR 11,

2

3

4

EN 55011, class A – 30 MHz to 1000 MHz ■ Conducted interference voltage, aux. voltage CISPR 22, EN 55022, class B – 150 kHz to 30 MHz Instrument transformers Instrument transformers must comply with the applicable IEC recommendations IEC 60044, formerly IEC 60185 (c.t.) and 186 (p.t.), ANSI/IEEE C57.13 or other comparable standards. Potential transformers

5

6

Potential transformers (p.t.) in single- or double-pole design for all primary voltages have single or dual secondary windings of 100, 110 or 120 V/ 3, with output ratings between 10 and 300 VA, and accuracies of 0.2, 0.5 or 1% to suit the particular application. Primary BIL values are selected to match those of the associated switchgear. Current transformers

7

8

9

Current transformers (c.t.) are usually of the single-ratio type with wound or bartype primaries of adequate thermal rating. Single, dual or triple secondary windings of 1 or 5 A are standard. 1 A rating however should be preferred, particularly in HV and EHV stations, to reduce the burden of the connecting leads. Output power (rated burden in VA), accuracy and saturation characteristics (accuracy limiting factor) of the cores and secondary windings must meet the particular application. The c.t. classification code of IEC is used in the following: Measuring cores

10

They are normally specified with 0.5% or 1.0% accuracy (class 0.5 M or 1.0 M), and an accuracy limiting factor of 5 or 10. The required output power (rated burden) must be higher than the actually connected burden. Typical values are 5, 10, 15 VA. Higher values are normally not necessary when only electronic meters and recorders are connected. A typical specification could be: 0.5 M 10, 15 VA.

Protection cores: The size of the protection core depends mainly on the maximum short-circuit current and the total burden (internal c.t. burden, plus burden of connecting leads, plus relay burden). Further, an overdimensioning factor has to be considered to cover the influence of the d.c. component in the short-circuit current. In general, an accuracy of 1% (class 5 P) is specified. The accuracy limiting factor KALF should normally be designed so that at least the maximum short-circuit current can be transmitted without saturation (d.c. component not considered). This results, as a rule, in rated accuracy limiting factors of 10 or 20 dependent on the rated burden of the c.t. in relation to the connected burden. A typical specification for protection cores for distribution feeders is 5P10, 15 VA or 5P20, 10 VA. The requirements for protective current transformers for transient performance are specified in IEC 60044-6. The recommended calculation procedure for saturation-free design, however, leads to very high c.t. dimensions. In many practical cases, the c.t.s cannot be designed to avoid saturation under all circumstances because of cost and space reasons, particularly with metal-enclosed switchgear. The Siemens relays are therefore designed to tolerate c.t. saturation to a large extent. The numerical relays proposed in this guide are particularly stable in this case due to their integral saturation detection function.

RBC + Ri KALF > RBN + Ri

K*ALF

Iscc.max. IN

Iscc.max. = Maximum short-circuit current IN = Rated primary c.t. current KOF = Overdimensioning factor Fig. 6: C.t. dimensioning formulae

6/6

C.t. design according to BS 3938 In this case the c.t. is defined by the kneepoint voltage UKN and the internal secondary resistance Ri. The design values according to IEC 60 185 can be approximately transferred into the BS standard definition by the following formula:

UKN =

(RNC + Ri) • I2N • KALF 1.3

I2N = Nominal secondary current Example: IEC 185 : 600/1, 15 VA, 5P10, Ri = 4 Ohm (15 + 4) • 1 • 10 BS : UKN = = 146 V 1.3 Ri = 4 Ohm Fig. 7: BS c.t. definition

C.t. design according to ANSI/IEEE C 57.13 Class C of this standard defines the c.t. by its secondary terminal voltage at 20 times nominal current, for which the ratio error shall not exceed 10%. Standard classes are C100, C200, C400 and C800 for 5 A nominal secondary current. This terminal voltage can be approximately calculated from the IEC data as follows:

Vs.t. max = 20 x 5 A x RBN •

KALF : Rated c.t. accuracy limiting factor K*ALF : Effective c.t. accuracy limiting factor RBN : Rated burden resistance RBC : Connected burden Ri : Internal c.t. burden (resistance of the c.t. secondary winding) with: K*ALF > KOF

The required c.t. accuracy-limiting factor KALF can be determined by calculation, as shown in Fig. 6. The overdimensioning factor KOF depends on the type of relay and the primary d.c. time constant. For the normal case, with short-circuit time constants lower than 100 ms, the necessary value for K*ALF can be taken from the table in Fig. 9. The recommended values are based on extensive type tests.

KALF 20

with:

RBN = PBN and INsec = 5 A , we get INsec2 Vs.t. max =

PBN • KALF 5

Example: IEC 185 : 600/5, 25 VA, 5P20, 25 • 20 = ANSI C57.13: Vs.t. max = 5 = 100, i.e. class C100 Fig. 8: ANSI c.t. definition



Relay type o/c protection 7SJ511, 512, 551, 7SJ60, 61, 62, 63

Example: Stability-verification of the numerical busbar protection 7SS50

Minimum K*ALF

=

IHigh set point

1

Given case: , at least 20

IN

2 Transformer differential protection 7UT51

> – 50 for each side

Line differential (fiber-optic) protection 7SD511/512

=

Iscc. max. (external fault) IN

[K*ALF . IN](line-end 2)

3

Line differential (pilot wire) protection 7SD502/503/600

=

Numerical busbar protection (low impedance type) 7SS5

I = 1 scc. max. (outflowing current for ext. fault) IN 2

Distance protection 7SA511, 7SA513, 7SA522

= a

Iscc. max. (external fault) IN

600/1 5 P 10, 15 VA, Ri = 4 Ohm

[K*ALF . IN](line-end 1) and 1 < <3

l = 50 m 7SS5 A = 6 mm2 I scc.max. = 30 kA

K* and 3 < ALF (line-end 1) < 4 4 K*ALF (line-end 2) 3

IN

a=2

IN

4 Iscc.max.

TN < 50 ms:

Iscc. max. (close-in fault)

TN < 100 ms:

3

= 30,000 = 50 600

5

According to Fig. 9:

K*ALF >

1 2

6

50 = 25

a = 3 for 7SA511 a = 2 for 7SA513 and 7SA522

and

= 10

Iscc. max. (line-end fault)

=

15 VA = 15 Ohm; 1 A2

RRelay =

1.5 VA = 1.5 Ohm 1 A2

RBN

7

IN

8

Fig. 9: Required effective accuracy limiting factor K*ALF

Relay burden

Burden of the connection leads

The c.t. burdens of the numerical relays of Siemens are below 0.1 VA and can therefore be neglected for a practical estimation. Exceptions are the busbar protection 7SS50 (1.5 VA) and the pilot wire relays 7SD502, 7SD600 (4 VA) and 7SD503 (3 VA + 9 VA per 100 Ohm pilot wire resistance). Intermediate c.t.s are normally no longer applicable as the ratio adaption for busbar and transformer protection is numerically performed in the relay. Analog static relays in gereral also have burdens below about 1 VA. Mechanical relays, however, have a much higher burden, up to the order of 10 VA. This has to be considered when older relays are connected to the same c.t. circuit. In any case, the relevant relay manuals should always be consulted for the actual burden values.

The resistance of the current loop from the c.t. to the relay has to be considered:

Rl =

l

Rl

RBC

= Rl + RRelay = = 0.3 + 1.5

2 ρ l Ohm A

= single conductor length from the c.t. to the relay in m.

2 0.0179 50 = 0.3 Ohm 6

=

KALF

>

1.8 + 4 15 + 4

9

= 1.8 Ohm

10

25 = 7.6

Result: Specific resistance: Ohm mm2 ρ = 0.0179 (copper wires) m A = conductor cross section in mm2 Fig. 10


The rated KALF-factor (10) is higher than the calculated value (7.6). Therefore, the stability criterium is fulfilled. Fig. 11

6/7

Power System Protection Introduction

1

2

3

4

5

6

7

Introduction

SIPROTEC 3

Siemens is one of the world’s leading suppliers of protective equipment for power systems. Thousands of our relays ensure first-class performance in transmission and distribution networks on all voltage levels, all over the world, in countries of tropical heat or arctic frost. For many years, Siemens has also significantly influenced the development of protection technology. ■ In 1976, the first minicomputer (process computer)-based protection system was commissioned: A total of 10 systems for 110/20 kV substations were supplied and are still operating satisfactorily today. ■ Since 1985, we have been the first to manufacture a range of fully numerical relays with standardized communication interfaces. Today, Siemens offers a complete program of protective relays for all applications including numerical busbar protection. To date (1999), more than 150,000 numerical protection relays from Siemens are providing successful service, as standalone devices in traditional systems or as components of coordinated protection and substation control. Meanwhile, the innovative SIPROTEC 4 series has been launched, incorporating the many years of operational experience with thousands of relays, together with users’ requirements (power authority recommendations).

Fig. 12: Numerical relay ranges of Siemens

8

9

10

6/8

SIPROTEC 4

State of the art Mechanical and solid-state (static) relays have been almost completely phased out of our production because numerical relays are now preferred by the users due to their decisive advantages: ■ Compact design and lower cost due to integration of many functions into one relay ■ High availability even with less maintenance due to integral self-monitoring ■ No drift (aging) of measuring characteristics due to fully numerical processing ■ High measuring accuracy due to digital filtering and optimized measuring algorithms ■ Many integrated add-on functions, for example, for load-monitoring and event/fault recording ■ Local operation keypad and display designed to modern ergonomic criteria ■ Easy and secure read-out of information via serial interfaces with a PC, locally or remotely ■ Possibility to communicate with higherlevel control systems using standardized protocols (open communication)



1

52

21

67N

FL

79

25

SM

ER

FR

BM

2

85

3

Serial link to station – or personal computer to remote line end

21 67N FL 79 25 85 SM ER FR BM

Distance protection Directional ground-fault protection Distance-to-fault locator Autoreclosure Synchro-check Carrier interface (teleprotection) Self-monitoring Event recording Fault recording Breaker monitor

kA, kV, Hz, MW, MVAr, Load monitor MVA,

01.10.93

4

Fault report Fault record

5

Relay monitor Breaker monitor Supervisory control

6

Fig. 13: Numerical relays, increased information availability

Modern protection management All the functions, for example, of a line protection scheme can be incorporated in one unit: ■ Distance protection with associated add-on and monitoring functions ■ Universal teleprotection interface ■ Autoreclose and synchronism check Protection-related information can be called up on-line or off-line, such as: ■ Distance to fault ■ Fault currents and voltages ■ Relay operation data (fault detector pickup, operating times etc.) ■ Set values ■ Line load data (kV, A, MW, kVAr) To fulfill vital protection redundancy requirements, only those functions which are interdependent and directly associated with each other are integrated in the same unit. For back-up protection, one or more additional units have to be provided.

All relays can stand fully alone. Thus, the traditional protection concept of separate main and alternate protection as well as the external connection to the switchyard remain unchanged. ”One feeder, one relay“ concept Analog protection schemes have been engineered and assembled from individual relays. Interwiring between these relays and scheme testing has been carried out manually in the workshop. Data sharing now allows for the integration of several protection and protection related tasks into one single numerical relay. Only a few external devices may be required for completion of the total scheme. This has significantly lowered the costs of engineering, assembly, panel wiring, testing and commissioning. Scheme failure probability has also been lowered. Engineering has moved from schematic diagrams towards a parameter definition procedure. The documentation is provided by the relay itself. Free allocation of LED operation indicators and output contacts provides more application design flexibility.


7

Measuring included For many applications, the protective-current transformer accuracy is sufficient for operational measuring. The additional measuring c.t. was more for protection of measuring instruments under system fault conditions. Due to the low thermal withstand ability of the measuring instruments, they could not be connected to the protection c.t.. Consequently, additional measuring c.t.s and measuring instruments are now only necessary where high accuracy is required, e.g. for revenue metering.

8

9

10

6/9


On-line remote data exchange

1

2

3

A powerful serial data link provides for interrogation of digitized measured values and other information stored in the protection units, for printout and further processing at the substation or system control level. In the opposite direction, settings may be altered or test routines initiated from a remote control center. For greater distances, especially in outdoor switchyards, fiber-optic cables are preferably used. This technique has the advantage that it is totally unaffected by electromagnetic interference.

Recording

Personal computer DIGSI

Assigning

Protection

Laptop

DIGSI

Off-line dialog with numerical relays

4

5

6

7

8

9

10

A simple built-in operator panel which requires no special software knowledge or codeword tables is used for parameter input and readout. This allows operator dialog with the protection relay. Answers appear largely in plaintext on the display of the operator panel. Dialog is divided into three main phases: ■ Input, alternation and readout of settings ■ Testing the functions of the protection device and ■ Readout of relay operation data for the three last system faults and the autoreclose counter.

Recording and confirmation

Fig. 14: PC-aided setting procedure

Substation level

6/10

Coordinated protection & control

Modem (option)

Modern system protection management A more versatile notebook PC may be used for upgraded protection management. The MS Windows-compatible relay operation program DIGSI is available for entering and readout of setpoints and archiving of protection data. The relays may be set in 2 steps. First, all relay settings are prepared in the office with the aid of a local PC and stored on a floppy or the hard disk. At site, the settings can then be downloaded from a PC into the relay. The relay confirms the settings and thus provides an unquestionable record. Vice versa, after a system fault, the relay memory can be uploaded to a PC, and comprehensive fault analysis can then take place in the engineer’s office. Alternatively, the total relay dialog can be guided from any remote location through a modem-telephone connection (Fig. 15).

to remote control

System level

ERTU

RTU

Data concentrator

Bay level 52 Relay

Control

Fig. 15: Communication options



Relay data management Analog-distribution-type relays have some 20–30 setpoints. If we consider a power system with about 500 relays, then the number adds up to 10,000 settings. This requires considerable expenditure in setting the relays and filing retrieval setpoints. A personal computer-aided man-machine dialog and archiving program, e.g. DIGSI, assists the relay engineer in data filing and retrieval. The program files all settings systematically in substation-feeder-relay order. Corrective rather than preventive maintenance Numerical relays monitor their own hardware and software. Exhaustive self-monitoring and failure diagnostic routines are not restricted to the protective relay itself, but are methodically carried through from current transformer circuits to tripping relay coils. Equipment failures and faults in the c.t. circuits are immediately reported and the protective relay blocked. Thus, the service personnel are now able to correct the failure upon occurrence, resulting in a significantly upgraded availability of the protection system.

Setpoints

200 setpoints

20 setpoints

1200 flags p. a.

10 000 setpoints 1 system approx. 500 relays

300 faults p. a. approx. 6,000 km OHL (fault rate: 5 p. a. and 100 km)

2

system

3

1 sub

4 flags

4

1 bay

bay OH-Line

5

Fig. 16: System-wide setting and relay operation library

6 1000 1000

Adaptive relaying Numerical relays now offer secure, convenient and comprehensive matching to changing conditions. Matching may be initiated either by the relay’s own intelligence or from the outside world via contacts or serial telegrams. Modern numerical relays contain a number of parameter sets that can be pretested during commissioning of the scheme (Fig. 17). One set is normally operative. Transfer to the other sets can be controlled via binary inputs or serial data link. There are a number of applications for which multiple setting groups can upgrade the scheme performance, e.g. a) for use as a voltage-dependent control of o/c relay pickup values to overcome alternator fault current decrement to below normal load current when the AVR is not in automatic operation. b) for maintaining short operation times with lower fault currents, e.g. automatic change of settings if one supply transformer is taken out of service. c) for “switch-onto-fault” protection to provide shorter time settings when energizing a circuit after maintenance. The normal settings can be restored automatically after a time delay.

1

Relay operations

1000

Parameter

1100 ParameterLine data

D

C

1100 Line data O/C Phase settings 1200 Parameter

1000 1100

Line data O/C Phase settings 1200 1500 O/C EarthFault settings 2800 Recording O/C PhaseO/C settings 1500 settings 2800 Earth Fault Recording 3900 Breaker Fall O/C Ground settings 2800 Fault Recording 3900 Breaker Fall

1200 1500 2800 3900

7

B

1100 Line data O/C Phase settings 1200 Parameter 1500 O/C Earth settings

A

8

Fault recording 3900 Breaker Fall

9

Breaker fail

10 Fig. 17: Alternate parameter groups

d) for autoreclose programs, i.e. instantaneous operation for first trip and delayed operation after unsuccessful reclosure. e) for cold load pick-up problems where high starting currents may cause relay operation. f) for ”ring open“ or ”ring closed“ operation.


6/11

Power System Protection Relay Design and Operation

Mode of operation

1

2

3

4

5

6

7

8

9

10

Numerical protection relays operate on the basis of numerical measuring principles. The analog measured values of current and voltage are decoupled galvanically from the plant secondary circuits via input transducers (Fig. 18). After analog filtering, the sampling and the analog-to-digital conversion take place. The sampling rate is, depending on the different protection principles, between 12 and 20 samples per period. With certain devices (e.g. generator protection) a continuous adjustment of the sampling rate takes place depending on the actual system frequency. The protection principle is based on a cyclic calculation algorithm, utilizing the sampled current and voltage analog measured values. The fault detections determined by this process must be established in several sequential calculations before protection reactions can follow. A trip command is transferred to the command relay by the processor, utilizing a dual channel control. The numerical protection concept offers a variety of advantages, especially with regard to higher security, reliability and user friendliness, such as: ■ High measurement accuracy: The high ultilization of adaptive algorithms produce accurate results even during problematic conditions ■ Good long-term stability: Due to the digital mode of operation, drift phenomena at components due to ageing do not lead to changes in accuracy of measurement or time delays ■ Security against over and underfunction With this concept, the danger of an undetected error in the device causing protection failure in the event of a network fault is clearly reduced when compared to conventional protection technology. Cyclical and preventive maintenance services have therefore become largely obsolete. The integrated self-monitoring system (Fig. 19) encompasses the following areas: – Analog inputs – Microprocessor system – Command relays.

PC interface LSA interface

Meas. inputs

Input filter

Current inputs (100 x /N, 1 s)

Amplifier

Input/ output ports

V.24 FO Serial Interfaces

Binary inputs

Alarm relay

Command relay Voltage inputs (140 V continuous)

100 V/1 A, 5 A analog

A/D converter

Processor system

0001 0101 0011

10 V analog

Memory: RAM EEPROM EPROM

digital

Input/ output units

LED displays

Input/output contacts

Fig. 18: Block diagram of numerical protection

Plausibility check of input quantities e.g. iL1 + iL2 + iL3 = iE uL1 + uL2 + uL3 = uE

Check of analog-to-digital conversion by comparison with converted reference quantities

A D

Microprocessor system

Hardware and software monitoring of the microprocessor system incl. memory, e.g. by watchdog and cyclic memory checks

Relay

Monitoring of the tripping relays operated via dual channels Tripping check or test reclosure by local or remote operation (not automatic)

Fig. 19: Self-monitoring system

6/12



Implemented Functions SIOPROTEC relays are available with a variety of protective functions. See relay charts (page 6/20 and following). The high processing power of modern numerical devices allow further integration of non-protective add-on functions.

1

2

The question as to whether separate or combined relays should be used for protection and control cannot be uniformly answered. In transmission type substations, separation into independent hardware units is still preferred, whereas on the distribution level a trend towards higher function integration can be observed. Here, combined feeder relays for protection, monitoring and control are on the march (Fig. 20).

3

4

Most of the relays of this guide are standalone protection relays. The exception in the SIPROTEC 3 series is the distribution feeder relay 7SJ531 that also integrates control functions. Per feeder, only one relay package ist needed in this case leading to a considerable reduction in space und wiring.

5

With the new SIPROTEC 4 series (types 7SJ61, 62 and 63), Siemens supports both stand-alone and combined solutions on the basis of a single hardware and software platform. The user can decide within wide limits on the configuration of the control and protection functions in the feeder, without compromising the reliability of the protection functions (Fig. 21).

Fig. 20: Switchgear with numerical relay (7SJ62) and traditional control

Switchgear with combined protection and control relay (7SJ63)

The following solutions are available within one relay family: ■ Separate control and protection relays ■ Protection relays including remote control of the feeder breaker via the serial communication link

■ Combined feeder relays for protection,

monitoring and control Mixed use of the different relay types is readily possible on account of the uniform operation and communication procedures.

7

7SJ61/ 62/63

Busbar

7SJ62/63

52 Local/Remote control Commands/Feedback indications Motor control (only 7SJ63) HMI

50

51

Trip circuit supervision

PLC logic

Vf (option) Fault locator

Lockout

74TC

6

&

86

59

Rotating field monitoring

27

47 Fault recording

Communications module RS23/485 fiber optic IEC 60 870-5-103 PROFIBUS FMS

50N 51N 46

810/U

21FL

8

Directional (option)

Metering values I2 limit values Metered power values pulses

49

Auto reclosing

Inrush restrain

79M

60N 51N

Calculated

10

Motor protection (option) Starting time

50BF Breaker failure protection

37

48

14 Locked rotor

9

V, Watts, Vars f.p.f.

66/86 Start inhibit

67

67N

Directional groundfault detection (option)

67

64

Fig. 21: SIPROTEC 4 relays 7SJ61/62/63, implemented function


6/13


1

2

3

4

5

6

Integration of relays in the substation automation Basically, Siemens numerical relays are all equipped with an interface to IEC 60870-5-103 for open communication with substation control systems either from Siemens (SINAUT LSA or SICAM, see page 6/71 ff) or of any other supplier. The relays of the newer SIPROTEC 4 series, however, are even more flexible and equipped with communication options. SIPROTEC 4 relays may also be connected to the SINAUT LSA system or to a system of another supplier via IEC 60870-5-103. But, SICAM 4 relays were originally designed as components of the new SICAM substation automation system, and their common use offers the most technical and cost benefits. SIPROTEC 4 protection and SICAM station control, which is based on SIMATIC, are of uniform design, and communication is based on the Profibus standard. SIPROTEC 4 relays can in this case be connected to the Profibus substation LAN of the SICAM system via one serial interface. Through a second serial interface, e.g. IEC 60 870-5-103, the relay can separately communicate with a remote PC via a modem-telephone line (Fig. 22).

DIGSI 4

DIGSI 4 Telephone connection

SICAM SAS

PROFIBUS FMS Modem

IEC 60870-5-103 DIGSI 4

IEC 60870-5-103

Fig. 22: SIPROTEC 4 relays, communication options

1

1 2

2

3

3

4

4 5

6 7

6

Local relay operation

7

8

9

10

All operator actions can be executed and information displayed on an integrated user interface. Many advantages are already to be found on the clear and user-friendly front panel: ■ Positioning and grouping of the keys supports the natural operating process (ergonomic design) ■ Large non-reflective back-lit display ■ Programmable (freely assignable) LEDs for important messages ■ Arrows arrangement of the keys for easy navigation in the function tree ■ Operator-friendly input of the setting values via the numeric keys or with a PC by using the operating program DIGSI 4 ■ Command input protected by key lock (6MD63/7SJ63 only) or password ■ Four programmable keys for frequently used functions >at the press of a button<

6/14

1 Large illuminated display 2 Cursor keys 3 LED with reset key

7

4 Control (7SJ61/62

6 Freely programmable

uses function keys) 5 Key switches

7 Numerical keypad

Fig. 23: Front view of the protection relay 7SJ62

function keys

Fig. 24: Front view of the combined protection, monitoring and control relay 7SJ63



DIGSI 4 the PC program for operating SIPROTEC 4 relays For the user, DIGSI is synonymous with convenient, user-friendly parameterizing and operation of digital protection relays. DIGSI 4 is a logical innovation for operation of protection and bay control units of the SIPROTEC 4 family. The PC operating program DIGSI 4 is the human-machine interface between the user and the SIPROTEC 4 units. It features modern, intuitive operating procedures. With DIGSI 4, the SIPROTEC 4 units ca be configured and queried. ■ The interface provides you only with what is really necessary, irrespective of which unit you are currently configuring. ■ Contextual menus for every situation provide you with made-to-measure functionality – searching through menu hierarchies is a thing of the past. ■ Explorer – operation on the MS Windows 95® Standard – shows the options in logically structured form. ■ Even with marshalling, you have the overall picture – a matrix shows you at a glance, for example, which LEDs are linked to which protection control function(s). It just takes a click with the mouse to establish these links by a fingertip. ■ Thus, you can also use the PC to link up with the relay via star coupler or channel switch, as well via the PROFIBUS® of a substation control system. The integrated administrating system ensures clear addressing of the feeders and relays of a substation. ■ Access authorization by means of passwords protects the individual functions, such as for example parameterizing, commissioning and control, from unauthorized access. ■ When configuring the operator environment and interfaces, we have attached importance to continuity with the SICAM automation system. This means that you can readily use DIGSI on the station control level in conjunction with SICAM. Thus, the way is open to the SIMATIC automation world.

1

2

3 Fig. 25: Substation manager for managing of substation and device data

4

5

6

7

8 Fig. 26: Function range

9

10

Fig. 27: Range of operational measured values


6/15


DIGSI 4 matrix

1

2

The DIGSI 4 matrix allows the user to see the overall view of the relay configuration at a glance. For example, you can display all the LEDs that are linked to binary inputs or show external signals that are connected to the relay. And with one click of the button, connections can be switched (Fig. 28). Display editor

3

4

A display editor is available to design the display on SIPROTEC 4 units. The predefined symbol sets can be expanded to suit the user. The drawing of a one-line diagram is extremely simple. Load monitoring values (analog values) can be placed where required (Fig. 29).

Fig. 28: DIGSI 4 allocation matrix

Commissioning

5

6

7

Special attention has been paid to commissioning. All binary inputs and outputs can be read and set directly. This can simplify the wire checking process significantly for the user. CFC: Planning instead of programming logic With the help of the graphical CFC (Continuous Function Chart)Tool, you can configure interlocks and switching sequences simply by drawing the logic sequences; no special knowledge of software is required. Logical elements such as AND, OR and time elements are available (Fig. 30) . Hardware and software platform

8

■ Pentium 133 MHz or above, with at

least 32 Mbytes RAM

Fig. 29: Display Editor

■ DIGSI requires about 200 Mbytes hard-

disk space ■ Additional hard-disk space per installed

9

protection device 2 Mbytes ■ One free serial interface to the protec-

tion device (COM 1 to COM 4) ■ One CD ROM drive (required for in-

stallation)

10

■ WINDOWS 95/98 or NT 4

Fig. 30: CFC logic with module library

6/16



Operation of SIPROTEC 3 Relays Most of the Siemens numerical relays belong to the series SIPROTEC 3. (Only the distribution protection relays 7SJ61/62, the combined protection and control relay 7SJ63 and the line protection 7SA522 are presently available in the version SIPROTEC 4). Both relay series are widely compatible and can be used together in protection and control systems. SIPROTEC 3 relays however are not applicable with PROFIBUS but only with the IEC 60870-5-103 communication standard. The operation of SIPROTEC 3 and 4 relays is very similar. Some novel features of the PC operating program DIGSI 4 like the CFC function and the graphical setting matrix are however not contained in DIGSI 3. Operation of SIPROTEC 3 relays via integral key pad and LCD display: Each parameter can be accessed and altered via the integrated operator panel or a PC connected to the front side serial communication interface. The setting values can be accessed directly via 4-digit addresses or by paging through the menu. The display appears on an alphanumeric LCD display with 2 lines with 16 characters per line. Also the rear side IEC 60870-5-103 compatible serial interface can be used for the relay dialog with a PC, when not occupied for the connection to a substation automation system. This rear side interface is in particular used for remote relay communication with a PC (see page 6/19). Most relays allow for the storage of several setting groups (in general 4) which can be activated via binary relay input, serial interface or operator panel. Binary inputs, alarm contact outputs, indicating LEDs and command output relays can be freely assigned to the internal relay functions.

1

2

3

4 Fig. 31: Operation of the protection relays using PC and DIGSI 3 software program

5

6

7

8

Fig. 32: Parameterization using DIGSI 3

DIGSI 3 the PC program for operating SIPROTEC 3 relays For setting of SIPROTEC 3 relays, the DIGSI 3 version is applicable. (Figs. 31 and 32). It is a WINDOWS-based program that allows comfortable user-guided relay setting, load monitoring and readout of stored fault reports, including oscillographic fault records. It is also a valuable tool for commissioning as it allows an online overview display of all measuring values. DIGSI comes with the program DIGRA for graphic display and evaluation of oscillographic fault records (see next page). For remote relay communication, the program WINDIMOD is offered (option). The DIGSI 3 program requires the following hardware and software platform:


■ PC 386 SX or above, with at least

4 Mbytes Ram ■ 10 Mbytes hard-disc space for DIGSI 3 ■ 2 to 3 Mbytes additional hard-disc space

9

per installed protection device ■ One free serial interface to the protec-

tion device (COM 1 to COM 4) ■ One floppy disc drive 3.5", high density

with 1.44 Mbytes or CD ROM drive for program installation ■ WINDOWS version 3.1 or higher These requirements relate to the case when DIGSI 3 is used as stand-alone version. When used together with DIGSI 4, the requirements for DIGSI 4 apply. In this case DIGSI 3 and DIGSI 4 run under the common DIGSI 4 substation manager.

6/17

10


Fault analysis

1

2

3

4

5

6

7

8

9

The evaluation of faults is simplified by numerical protection technology. In the event of a fault in the network, all events as well as the analog traces of the measured voltages and currents are recorded. The following types of memory are available: ■ 1 operational event memory Alarms that are not directly assigned to a fault in the network (e.g. monitoring alarms, alternation of a set value, blocking of the automatic reclose function). ■ 5 fault-event histories Alarms that occurred during the last 3 faults on the network (e.g. type of fault detection, trip commands, fault location, autoreclose commands). A reclose cycle with one or more reclosures is treated as one fault history. Each new fault in the network overrides the oldest fault history. ■ A memory for the fault recordings for voltage and current. Up to 8 fault recordings are stored. The fault recording memory is organized as a ring buffer, i.e. a new fault entry overrides the oldest fault record. ■ 1 earth-fault event memory (optional for isolated or resonant grounded networks) Event record of the sensitive earth fault detector (e.g. faulted phase, real component of residual current). The time tag attached to the fault-record events is a relative time from fault detection with a resolution of 1 ms. In the case of devices with integrated battery back-up clock, the operational events as well as the fault detection are assigned the internal clock time and date stamp. The memory for operational events and fault record events is protected against failure of auxiliary supply with battery back-up supply. The integrated operator interface or a PC supported by the programming tool DIGSI is used to retrieve fault reports as well as for the input of settings and marshalling.

10

6/18

Fig. 33: Display and evaluation of a fault record using DIGSI

Evaluation of the fault recording

Data security, data interfaces

Readout of the fault record from the protection device by DIGSI is done by faultproof scanning procedures in accordance with the standard recommendation for transmission of fault records. A fault record can also be read out repeatedly. In addition to analog values, such as voltage and current, binary tracks can also be transferred and presented. DIGSI is supplied together with the DIGRA (Digsi Graphic) program, which provides the customer with full graphical operating and evaluation functionality like that of the digital fault recorders (Oscillostores) from Siemens (see Fig. 33). Real-time presentation of analog disturbance records, overlaying and zooming of curves and visualization of binary tracks (e.g. trip command, reclose command, etc.) are also part of the extensive graphical functionality, as are setting of measurement cursors, spectrum analysis and fault resistance derivation.

DIGSI is a closed system as far as protection parameter security is concerned. The security of the stored data of the operating PC is ensured by checksums. This means that it is only possible to change data with DIGSI, which subsequently calculates a checksum for the changed data and stores it with the data. Changes in the data and thus in safety-related protection data are reliably detected. DIGSI is, however, also an open system. The data export function supports export of parameterization and marshalling data in standard ASCII format. This permits simple access to these data by other programs, such as test programs, without endangering the security of data within the DIGSI program system. With the import and export of fault records in IEEE standard format COMTRADE (ANSI), a high-performance data interface is produced which supports import and export of fault records into the DIGSI partner program DIGRA. This enables the export of fault records from Siemens protection units to customer-specific programs via the COMTRADE format.



Remote relay interrogation The numerical relay range of Siemens can also be operated from a remotely located PC via modem-telephone connection. Up to 254 relays can be addressed via one modem connection if the star coupler 7XV53 is used as a communication node (Fig. 34). The relays are connected to the star coupler via optical fiber links. Every protection device which belongs to a DIGSI substation structure has a unique address. The attached relays are always listening, but only the addressed one answers the operator command which comes from the central PC. If the relay located in a station is to be operated from a remote office, then a device file is opened in DIGSI and protection dialog is chosen via modem. After password input, DIGSI establishes a connection to the protection device after receiving a call-back from the system. In this way secure and timesaving remote setting and readout of data are possible. Diagnostics and control of test routines are also possible without the need to visit the substation.

Office

1 Analog ISDN DIGSI PC, remotely located

2

Substation Star coupler DIGSI PC,centrally located in the substation (option)

3

7XV53

Modem, optionally with call-back function

4

Signal converter opt.

5

RS485 Bus

RS485

6 7SJ60

Housing and terminal system The protection devices and the corresponding supplementary devices are available mainly in 7XP20 housings (Figs. 35 to 42). The dimension drawings are to be found on 6/36 and the following pages. Installing of the modules in a cubicle without the housing is not permissible. The width of the housing conforms to the 19" system with the divisions 1/6, 1/3, 1/2 or 1/1 of a 19" rack. The termination module is located at the rear of devices for panel flush mounting or cubicle mounting. For electrical connection, screwed terminals of the SIPROTEC 3 relay series and also parallel crimp contacts are provided. For field wiring, the use of the screwed terminals is recommended; snap-in connection requires special tools. To withdraw crimp contact terminations of the SIPROTEC 3 relay series the following tool is recommended: Extraction tool No. 135900 (from Weidmüller, Paderbornstrasse 157, D-32760 Detmold).

Modem

7RW60

7SD60

7**5

7**6

Fig. 34: Remote relay communication

The heavy-duty current plug connectors provide automatic shorting of the c.t. circuits whenever the modules are withdrawn. This does not release from the care to be taken when c.t. secondary circuits are concerned. In the housing version for surface mounting, the terminations are wired up on terminal strips on the top and bottom of the device. For this purpose two-tier terminal blocks are used to attain the required number of terminals (Fig. 36 right). According to IEC 60529 the degree of protection is indicated by the identifying IP, followed by a number for the degree of protection. The first digit indicates the protection against accidental contact and ingress of solid foreign bodies, the second digit indicates the protection against water. 7XP20 housings are protected against access to dangerous parts by wire, dust and dripping water (IP 51).


7 For mounting of devices into cubicles, the 8MC cubicle system is recommended. It is described in Siemens Catalog NV21. The standard cubicle has the following dimensions: 2200 mm x 900 mm x 600 mm (HxWxD). These cubicles are provided with a 44 U high mounting rack (standard height unit U = 44.45 mm). It can swivel as much as 180° in a swing frame. The rack provides for a mounting width of 19", allowing, for example, 2 devices with a width of 1/2 x 19" to be mounted. The devices in the 7XP20 housing are secured to rails by screws. Module racks are not required (see Fig. 65b on page 6/33).

6/19

8

9

10


SIPROTEC 3 Relay Series 1

2

3

4

SIPROTEC 3 relays come in 1/6 to 1/1 of 19" wide cases with a standard height of 243 mm. Their size is compatible with SIPROTEC 4 relays. Therefore, exchange is always possible. Versions for flush and surface mounting are available.

Terminations: 1/1 of 19" width

Flush-mounted version: Each termination may be made via screw terminal or crimp contact. The termination modules used each contain: 4 termination points for measured voltages, binary inputs or relay outputs (max. 1.5 mm2) or

5

2 termination points for measured currents (screw termination max. 4 mm2, crimp contact max. 2.5 mm2) 2 FSMA plugs for the fiber optic termination of the serial communication link

6 Surface mounted version:

7

8

Screw terminals (max. wire cross section 7 mm2) for all wired terminations at the top and bottom of the housing

1/3

1/2 of 19" width

Fig. 35a/b: Numerical protection relays of the SIPROTEC 3 series in 7XP20 standard housing

2 FMS plugs for fiber optic termination of the serial communication link at the bottom of the housing Fig. 35c

9

10

Fig. 36: SIPROTEC 3 relays left: Connection method for panel flush mounting including fiber-optic interfaces;

6/20

Fig. 36 Right: Connection method for panel surface mounting



SIPROTEC 4 Relay Series SIPROTEC 4 relays come in 1/6 to 1/1 of 19" wide cases with a standard height of 243 mm. Their size is compatible with SIPROTEC 3 relays. Therefore, compatible exchange is always possible. All wires (cables) are connected at the rear side of the relay via ring tongue terminals. A special relay version with loose cableconnected operator panel (Fig. 42) is also available. It allows for example installation of the relay itself in the low-voltage compartment and of the operator panel separately in the door of the switchgear. In this version voltage terminals are of the plug-in type. Current terminals are again screw-type.

1

2

3 Fig. 38: 1/6 of 19"

Fig. 39: 1/3 of 19"

4

Terminations:

5

Standard relay version with screw terminals: Current terminals: Connection Wmax = 12mm ring cable lugs d1 = 5mm d1

Wire size Direct connection Wire size

W

2.7 – 4 mm2 (AWG 13–11) Solid conductor, flexible lead, connector sleeve

6

7 Fig. 40: 1/2 of 19"

Fig. 41: SIPROTEC 4 relay case versions

2.7 – 4 mm2 (AWG 13–11)

Voltage terminals:

8

Connection Wmax = 10mm ring cable lugs d1 = 4 mm Wire size 1.0 – 2.6 mm2 (AWG 17–13) Direct Solid conductor, flexible connection lead, connector sleeve Wire size

9

0.5 – 2.5 mm2 (AWG 20–13)

Special relay version (Fig. 42) with plug-in terminals: Current terminals:

10

Screw type as above

Voltage terminals: 2-pin or 3-pin connectors Wire size Fig. 37

0.5 – 1.0mm2 0.75 – 1.5mm2 1.0 – 2.5mm2 Fig. 42: SIPROTEC 4 combined protection, control and monitoring relay 7SJ63 with separate operator panel


6/21

Power System Protection Relay Selection Guide

Overcurrent

Motor protection

Differential

7SD511 7SD512

7SJ511 7SJ512 7SJ531 7SJ60 7SJ61 7SJ62 7SJ63

7SJ551

7VH80 7UT512 7UT513 7SS50/52 7VH83

7UM511 7UM512 7UM515 7UM516

–

– –

–

–

–

–

– ■ –

–

–

–

■

–

–

– –

–

–

–

– –

Distance protection, phase

■ ■ ■

– –

–

–

–

–

– –

–

–

–

–

–

–

–

– –

–

–

–

– ■

21N

Distance protection, ground

■ ■ ■

– –

–

–

–

–

– –

–

–

–

–

–

–

–

– –

–

–

–

– –

24

Overfluxing

– –

– –

–

–

–

–

– –

–

–

–

–

–

–

–

– –

–

–

– ■ –

25

Synchronism check

■ ■ ■ – –

–

–

–

–

– –

–

–

–

–

–

– –

–

–

–

– –

27

Undervoltage

–

–

–

– –

–

–

–

–

– ■ –

– ■ ■

■

– –

–

–

–

■ ■ ■ –

27/59/ U/f protection 81

–

–

–

– –

–

–

–

–

– –

–

–

–

–

–

– –

–

–

–

– – ■ –

32

Directional power

–

– –

– –

–

–

–

–

– –

–

– –

–

–

–

–

–

–

–

■ –

32F

Forward power

–

– –

– –

–

–

–

–

– –

–

– –

–

–

–

–

–

–

–

■ ■ – ■

32R

Reverse power

–

– –

– –

–

–

–

–

– –

–

– –

–

–

–

–

–

–

–

■ ■ – ■

37

Undercurrent or underpower

–

– –

– –

–

–

–

–

– ■ – ■ ■ ■

■

–

–

–

–

–

– ■ – –

40

Field failure

–

– –

– –

–

–

–

–

– –

–

–

–

–

–

–

–

■ –

46

Load unbalance, negative phase sequence overcurrent

–

– –

– –

–

–

–

–

– ■ ■ ■ ■ ■

■

–

–

–

–

–

■ ■ – ■

47

Phase sequence voltage

■ ■ ■ – –

–

–

–

–

– –

– ■ ■

–

–

–

–

–

–

– –

– –

48

Incomplete sequence, locked rotor, failure to accelerate

– –

–

– –

–

–

–

–

– ■ ■ ■ ■ ■

■

–

–

–

–

–

– –

– –

49

Thermal overload

■ –

–

– ■ ■ ■ ■

■ ■ ■ ■ ■ ■ ■

■

– ■ ■ –

–

■ –

–

–

49R

Rotor thermal protection

–

–

–

– –

–

–

–

–

– ■ ■ ■ ■ ■

■

–

–

– –

–

– –

–

–

49S

Stator thermal protection

–

–

–

– –

–

–

–

–

– ■ ■ ■ ■ ■

■

–

–

– –

–

■ –

–

–

50

Instantaneous overcurrent

–

–

–

– –

–

–

–

■ ■ ■ ■ ■ ■ ■

■

– ■ ■ –

–

■ –

–

–

50N

Instantaneous ground fault overcurrent

–

–

–

– –

–

–

–

■ ■ ■ ■ ■ ■ ■

■

–

– –

–

– –

–

–

51G

Ground overcurrent relay

–

– –

–

–

–

–

–

– ■ ■ ■ ■ ■

■

– ■ – –

–

– ■ ■ –

3

Type Protection functions

5

6

7

8

9

10

7SA511 7SA513 7SA522

Distance

2

4

Generator protection

Fiber-optic current comparison 7SD503

Pilot wire differential

Relay Selection Guide

7SD600 7SD502

1

ANSI Description No.* 14

Zero speed and underspeed dev. – –

21

–

–

–

– –

–

– –

– ■

– –

* ANSI/IEEE C 37.2: IEEE Standard Electrical Power System Device Function Numbers

Fig. 43a

6/22



Generator protection

2

3

7UM511 7UM512 7UM515 7UM516

7VH80 7UT512 7UT513 7SS50/52 7VH83

Differential

Motor protection 7SJ551

7SJ511 7SJ512 7SJ55 7SJ531 7SJ60 7SJ61 7SJ62 7SJ63

Overcurrent

Fiber-optic current comparison 7SD512

7SD511

7SD503

Protection functions

7SD600 7SD502

Type

7SA511 7SA513 7SA522

Distance

Pilot wire differential

1

ANSI Description No.* 51GN Stator ground-fault overcurrent

4 – – ■ –

– –

–

– –

–

–

–

–

■

–

–

– –

–

■ ■ ■ –

–

– ■ ■

–

– –

51

Overcurrent with time delay

– –

■

■ ■ ■ – ■ ■ ■ ■ ■

■

–

■ ■ –

–

■ ■ – ■

51N

Ground-fault overcurrent with time delay

■ ■ ■ – –

–

■

■ ■ – – ■ ■ ■ ■ ■

■

–

–

– –

–

■ ■ – –

59

Overvoltage

– ■ ■ – –

–

–

–

–

– ■ – – ■ ■

■

–

–

– –

–

■ ■ ■ –

59N

Residual voltage ground-fault protection

–

– –

–

–

–

– ■ – ■ – – ■ ■

–

–

–

– –

–

■ – ■ ■

64R

Rotor ground fault

– –

–

– –

–

–

–

– – –

– –

– – –

–

–

– – –

–

■ ■ ■ –

67

Directional overcurrent

– –

–

– –

–

–

–

– ■ – ■ –

– ■ ■

–

–

– – –

–

– –

– –

67N

Directional ground-fault overcurrent

■ ■ –

– –

–

–

–

– ■ – ■ –

– ■ ■

■

–

– – –

–

– –

– –

67G

Stator ground-fault, directional overcurrent

–

– –

–

–

–

– –

–

– –

– –

–

–

–

–

– –

–

– ■ – –

68/78 Out-of-step protection

■ ■ ■ – –

–

–

–

– –

–

– –

– –

–

–

–

–

– –

–

– –

– ■

79

Autoreclose

■ ■ ■ – –

–

–

■

– ■ ■ ■ ■ ■ ■ ■

–

–

–

– –

–

– –

– –

81

Frequency relay

–

– –

–

–

–

– –

–

– –

– ■ ■

–

–

–

– –

–

■ ■ ■ –

85

Carrier interface

■ ■ ■ – –

–

–

–

– –

–

– –

–

– –

–

–

–

– –

–

– –

– –

86

Lockout relay, start inhibit

–

– –

– –

–

–

–

– –

– ■ – ■ ■ ■

■

–

–

– –

–

– –

– –

87G

Differential protection, generator –

– –

– –

–

–

–

– –

–

– –

–

– –

–

– ■ ■ –

–

– –

– –

87T

Differential protection, transf.

–

– –

– –

–

–

–

– –

–

– –

–

– –

–

– ■ ■ –

–

– –

– –

87B

Differential protection, bus-bar

–

– –

– –

–

–

–

– – –

– –

– –

–

–

– –

– ■ ■

– –

– –

87M

Differential protection, motor

–

– –

– –

–

–

–

– – –

– –

– –

–

–

– ■ ■ – ■

– –

– –

87L

Differential protection, line

–

– – ■ ■ ■

■ ■

– – –

– –

– –

–

–

– –

– –

–

– –

– –

87N

Restricted earth-fault protection

–

– –

– –

–

–

–

– – –

– –

– –

–

–

■ – ■ –

–

– –

– –

92

Voltage and power directional rel. –

– –

– –

–

–

–

– – –

– –

– –

–

–

– –

– –

–

– –

– –

– ■ ■ – –

–

–

–

■ ■ – ■ – ■ ■ ■

–

– –

– ■ –

– –

– –

50BF Breaker failure

– –

–

5

6

7 – –

– –

8

9

10


Fig. 43b


6/23


Synchronizing 7VE51

7SV512

7SV600

7RW600

24

Overfluxing

–

–

–

–

■

25

Synchronism check

■

–

–

–

–

Synchronizing

–

■

–

–

–

3

Type Protection functions

4

ANSI Description No.*

5 27

6

7

Breaker failure

2

Voltage, Frequency

Autoreclose + Synchronism check

Relay Selection Guide

7VK512

1

Undervoltage

–

–

–

–

■

27/59/ U/f protection 81

–

–

–

–

■

50BF

Breaker failure

–

–

■

■

–

59

Overvoltage

–

–

–

–

■

79

Autoreclose

■

–

–

–

–

81

Frequency relay

–

–

–

–

■

8

9

10


Fig. 43c

6/24


Power System Protection Relay Portraits

Relay portraits 1

Siemens manufactures a complete series of numerical relays for all kinds of protection application. The series is briefly portrayed on the following pages.

2

7SJ600 Universal overcurrent and overload protection

3

■ Phase-segregated measurement and

indication (Input 3 ph, IE calculated) ■ All instantaneous, i.d.m.t. and d.t.

■ ■ ■ ■ ■

characteristics can be set individually for phase and ground faults Selectable setting groups Integral autoreclose function (option) Thermal overload, unbalanced load and locked rotor protection Suitable for busbar protection with reverse interlocking With load monitoring, event and fault memory

7SJ602* Universal overcurrent and overload protection Functions as 7SJ600, however additionally: ■ Fourth current input transformer for connection to an independent ground current source (e.g. core-balance CT) ■ Optical data interface as alternative to the wired RS485 version (located at the relay bottom) ■ Serial PC interface at the relay front

4 * only with 7SJ512 50

50N

49

48

50

50N

BF

51

51N

46

79

51

51N

67

Fig. 44: 7SJ600/7SJ602

67N *

79

*

5

*

6

Fig. 45: 7SJ511/512

7SJ511 Universal overcurrent protection

7

■ Phase-segregated measurement and ■ ■ ■ ■ ■

indication (3 ph and E) I.d.m.t and d.t. characteristics can be set individually for phase and ground faults Suitable for busbar protection with reverse interlocking With integral breaker failure protection With load monitoring, event and fault memory Inrush stabilization

8

9

7SJ512 Digital overcurrent-time protection with additional functions

*) Commencement of delivery planned for end of 1999

10

Same features as 7SJ511, plus: ■ Autoreclose ■ Sensitive directional ground-fault protection for isolated, resonant or high-resistance grounded networks ■ Directional module when used as directional overcurrent relay (optional) ■ Selectable setting groups ■ Inrush stabilization


6/25


7SJ61

1

Universal overcurrent and overload protection with control functions ■ Phase-segregated measurement and

indication (input 3 ph and E)

2

3

■ All instantaneous, i.d.m.t. and d.t. char-

■ ■ ■ ■ ■

4

■ ■ ■

acteristics can be set individually for phase and ground faults Selectable setting groups Inrush stabilization Integral autoreclose function (option) Thermal overload, unbalanced load and locked rotor protection Suitable for busbar protection with reserve interlocking With load monitoring, event and fault memory With integral breaker failure protection With trip circuit supervision

7SJ61 56

50N

51

51N

50BF

79

86

27

49R

51N

37

50

59

48

51

46

50G

86

49

51G

Control functions:

5

6

■ ■ ■ ■

Measured-value acquisition (current) Limit values of current Control of 1 C.B. Switchgear interlocking isolator/C.B.

8

67

76N

27

59

FL

46

49

47

81o/u

Fig. 46: 7SJ61/7SJ62

Fig. 47: 7SJ551

■ Sensitive directional ground-fault protec-

■ ■ ■ ■ ■

tion for isolated, resonant or highresistance grounded networks Directional overcurrent protection Selectable setting groups Over and undervoltage protection Over and underfrequency protection Distance to fault locator (option)

Control functions:

9

7SJ62 additionally:

7SJ62 Digital overcurrent and overload protection with additional functions Features as 7SJ61, plus:

7

74TC

■ ■ ■ ■

Measured-value acquisition (voltage) P, Q, cos ϕ and meter-reading calculation Measured-value recording Limit values of I, V, P, Q, f, cos ϕ

10

6/26

7SJ551 Universal motor protection and overcurrent relay ■ Thermal overload pretection

– separate thermal replica for stator and rotor based on true RMS current measurement – up to 2 heating time constants for the stator thermal replica – separate cooling time constants for stator and rotor thermal replica – ambient temperature biasing of thermal replica ■ Connection of up to 8 RTD sensors ground elements ■ Real-Time Clock: last 3 events are stored with real-time stamps of alarm and trip data



Combined feeder protection and control relay 7SJ63

1

Line protection ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■

Nondirectional time overcurrent Directional time overcurrent IEC/ANSI and user definable TOC curves Overload protection Sensitive directional ground fault Negative sequence overcurrent Under/Overvoltage Under/Overfrequency Breaker failure Autoreclosure Fault locator

2

■ ■ ■ ■ ■ ■ ■ ■

Control up to 5 C.B. Switchgear interlocking isolator/C.B. Key-operated switching authority Feeder control diagram Status indication of feeder devices at graphic display Measured-value acquisition Signal and command indications P, Q, cos ϕ and meter-reading calculation Measured-value recording Event logging Switching statistics Switchgear interlocking 2 measuring transducer inputs

I/O Capability

7SJ631

7SJ632/3 7SJ635/6

Binary inputs

11

24/20

37/33

Contact outputs

8+Life

11+Life

14+Life

Motor control outputs

0

Control of switching devices

3

Cases Fig. 48

46

79

50BF

51

51N

49

49LR

81u/o

67

67N

59

27

14

37

48

66/86

21FL

33

74TC

86

4

Thermal overload Locked rotor Start inhibit Undercurrent

Control functions ■ ■ ■ ■ ■

50N

3

Motor protection ■ ■ ■ ■

50

4(2)

5

8(4)

5

1/2 of 19" 1/1 of 19" 1/1 of 19"

5 Fig. 49: 7SJ63

Combined feeder protection and control relay 7SJ531

6

Line protection ■ ■ ■ ■ ■ ■ ■ ■ ■ ■

Nondirectional time overcurrent Directional time overcurrent IEC/ANSI and user-definable TOC curves Overload protection Sensitive directional ground fault Negative sequence overcurrent Under/Overvoltage Breaker failure Autoreclosure Fault locator

7

8

Motor protection ■ ■ ■ ■

Thermal overload Locked rotor Start inhibit Undercurrent

9 50

50N

79

49

59

51

51N

67N

49LR

27

64

BF

46

37

5

Control functions Measured-value acquisition Signal and command indications P, Q, cos ϕ and meter-reading calculation Measured-value recording Event logging Switching statistics Feeder control diagram with load indication ■ Switchgear interlocking ■ ■ ■ ■ ■ ■ ■


10

Fig. 50: 7SJ531

6/27


7SA511

1

2

3

4

5

Line protection with distance-to-fault locator Universal distance relay for all networks, with many additional functions, including ■ Universal carrier interface (PUTT, POTT, Blocking, Unblocking) ■ Power swing blocking or tripping ■ Selectable setting groups ■ Sensitive directional ground-fault determining for isolated and compensated networks ■ High-resistance ground-fault protection for grounded networks ■ Single and three-pole autoreclose ■ Synchrocheck ■ Thermal overload protection for cables ■ Free marshalling of optocoupler inputs and relay outputs ■ Line load monitoring, event and fault recording ■ Selectable setting groups

21

25

67N

68

49

21

67N

78

21N

85

51N

78

79

21N

85

49

47 7SA510

Fig. 51: 7SA511

Fig. 52: 7SA510

Line protection with distance-to-fault locator

6

7

8

9

(Reduced version of 7SA511) Universal distance protection, suitable for all networks, with additional functions, including ■ Universal carrier interface (PUTT, POTT, Blocking, Unblocking) ■ Power swing blocking and/or tripping ■ Selectable setting groups ■ Sensitive directional ground-fault determining for isolated and compensated networks ■ High-resistance ground-fault protection for grounded networks ■ Thermal overload protection for cables ■ Free marshalling of optocoupler inputs and relay outputs ■ Line load monitoring, event and fault recording ■ Three-pole autoreclose

10

6/28



7SA522

1

Full scheme distance protection with add-on functions ■ Quadrilateral or MHO characteristic ■ Sub-cycle operating time ■ Universal teleprotection interface (PUTT,

2

POTT, Blocking, Unblocking) ■ Weak infeed protection ■ Power swing blocking/tripping ■ High-resistance ground-fault protection

■ ■ ■ ■ ■ ■ ■ ■ ■ ■

(time delayed or as directional comparison scheme) Overvoltage protection Switch-onto-fault protection Stub bus O/C protection Single and three-pole multi-shot autoreclosure*) Synchro-check*) Breaker failure protection*) Trip circuit supervision Fault locator w./w.o. parallel line compensation Oscillographic fault recording Voltage phase sequence

3

21

21N

FL

50N 51N

67N

68

79

85

85N

59

25

50BF

79

*

4

5

Fig. 53: 7SA522

7SA513

6

Transmission line protection with distance-to-fault locator ■ Full scheme distance protection, with

■ ■ ■ ■ ■

■ ■ ■ ■ ■ ■ ■

■ ■ ■ ■

operating times less than one cycle (20 ms at 50 Hz), with a package of extra functions which cover all the demands of extra-high-voltage applications Suitable for series-compensated lines Universal carrier interface (permissive and blocking procedures programmable) Power swing blocking or tripping Parallel line compensation Load compensation that ensures high accuracy even for high-resistance faults and double-end infeed High-resistance ground fault protection Backup ground-fault protection Overvoltage protection Single and three-pole autoreclose Synchrocheck option Breaker failure protection Free marshalling of a comprehensive range of optocoupler inputs and relay outputs Selectable setting groups Line load monitoring, event and fault recording High-performance measurement using digital signal processors Flash EPROM memories

7

8

9

21

25

50N 51N

67N

50 BF

79

21N

59

85

85N

68

78

FL

10 Fig. 54: 7SA513

*) available with Version 4.1 (Commencement of delivery planned for Oct. 1999)


6/29


7SD511

1

Current-comparison protection for overhead lines and cables ■ With phase-segregated measurement ■ For serial data transmission

2

3 ■

4

■ ■

5

■

(19.2 kbits/sec) – with integrated optical transmitter/ receiver for direct fiber-optic link up to approx. 15 km distance – or with the additional digital signal transmission device 7VR5012 up to 150 km fiber-optic length – or through a 64 kbit/s channel of available multipurpose PCM devices, via fiber-optic or microwave link Integral overload and breaker failure protection Emergency operation as overcurrent backup protection on failure of data link Automatic measurement and correction of signal transmission time, i.e. channelswapping is permissible Line load monitoring, event and fault recording

87L

51

49

BF

50

87L

51

50

49

BF

79

7SD512

6

Current-comparison protection for overhead lines and cables

Fig. 56: 7SD512

Fig. 55: 7SD511

with functions as 7SD511, but additionally with autoreclose function for single and three-pole fast and delayed autoreclosure.

7 7SD502 ■ Pilot-wire differential protection for lines

and cables (2 pilot wires)

8

■ Up to about 25 km telephone-type pilot

wire length ■ With integrated overcurrent back-up and

overload protection ■ Also applicable to 3-terminal lines

(2 devices at each end)

9 7SD503 ■ Pilot-wire differential protection for lines

and cables (3 pilot wires)

10

■ Up to about 15 km pilot wire length ■ With integrated overcurrent back-up and

overload protection ■ Also applicable to 3-terminal lines (2 devices at each end)

87L

50

49

51

Fig. 57: 7SD502/503

6/30



7SD600

1

Pilot wire differential protection for lines and cables (2 pilot wires) ■ Up to about 10 km telephone-type pilot

wire length ■ Connection to an external current sum-

2

mation transformer ■ Pilot wire supervision (option) ■ Remote trip command ■ External current summation transformer

4AM4930 to be ordered separately

3

4

5 87 L

6

Fig. 58: 7SD600

7UT512 Differential protection for machines and power transformers

7

with additional functions, such as: ■ Numerical matching to transformer ratio and connection group (no matching transformers necessary) ■ Thermal overload protection ■ Backup overcurrent protection ■ Measured-value indication for commissioning (no separate instruments necessary) ■ Load monitor, event and fault recording

8

9

7UT513 Differential protection for three-winding transformers with the same functions as 7UT512, plus: ■ Sensitive restricted ground-fault protection ■ Sensitive d.t. or i.d.m.t. ground-faulto/c-protection

10 87T

49

50/51

87T

50G

49

50/51

*

87 * REF

* 87REF or 50G

Fig. 59: 7UT512


Fig. 60: 7UT513

6/31


1

2

Central unit Optic fibers 1

2

3

48

3 Bay units

4

87 BB

BF

Fig. 61: 7SS50

5

Fig. 62: 7SS52

7SS50 Numerical busbar and breaker failure protection

6

7

■ With absolutely secure 2-out-of-2 meas-

■ ■ ■ ■ ■

8

■

■ ■

9

urement and additional check zone, each processed on separate microprocessor hardware Mixed current measurement With fast operating time (< 15 ms) Extreme stability against c.t. saturation Completely self-monitoring, including c.t. circuits, isolator positions and run time With integrated circuit-breaker failure protection With commissioning-friendly aids (indication of all feeder, operating and stabilizing currents) With event and fault recording Designed for single and multiple busbars, up to 8 busbar sections and 32 bays

7SS52

10

Distributed numerical busbar and breaker failure protection ■ With absolutely secure 2-out-of-2 meas-

■ ■ ■ ■ ■

urement and additional check zone, each processed on separate microprocessor hardware Phase-segregated measurement With fast operating time (< 15 ms) Extreme stability against c.t. saturation Completely self-monitoring, including c.t. circuits, isolator positions and run time With integrated 2-stage circuit-breaker failure protection

6/32

87

Fig. 64: 7VH80

87 ■ Inrush stabilized through filtering ■ Fast operation: 15 ms (l > 5 x setting) ■ Optionally, external voltage limiters

Fig. 63: 7VH83

(varistor)

■ With commissioning-friendly aids (indica-

tion of all feeder, operating and stabilizing currents) ■ With event and fault recording ■ Designed for single and multiple busbars, up to 12 busbar sections and 48 bays 7VH80 High impedance differential relay ■ Single-phase type ■ Robust solid-state design

7VH83 High impedance differential relay ■ ■ ■ ■ ■ ■ ■

Three-phase type Robust solid-state design Integral buswire supervision Integral c.t. shorting relay Inrush stabilized through filtering Fast operation: 21 ms (l > 5 x setting) Optionally, external voltage limiters (varistors)



7UM511/12/15/16

1

Multifunctional devices for machine protection ■ With 10 protection functions on average,

with flexible combination to form complete protection systems, from the smallest to the largest motor generator units (see Fig. 66) ■ With improved measurement methods based on Fourier filters and the evaluation of symmetrical components (fully numeric, frequency compensated) ■ With load monitoring, event and fault recording See also separate reference list for machine protection. Order No. E50001-U321-A39-X-7600

2

7SJ511

3 7UT513

7VE51

4

7VE51

7UM512

Paralleling device for synchronization of generators and networks ■ Absolutely secure against spurious switching due to duplicate measurement with different procedures ■ With numerical measurand filtering that ensures exact synchronization even in networks suffering transients ■ With synchrocheck option ■ Available in two versions: 7VE511 without, 7VE512 with voltage and frequency balancing

5 7UM511

G

6

7UT512

7SJ511

51

7UT513

87T

7VE51

25

Fig. 65b: Numerical protection of a generating unit (example). Cubicle design.

46

7UM511 81u

32

59

9 40

49

10

87G

Fig. 65a: Numerical protection of a generating unit (example). Single-line diagram.


8

Synchronizing

7UM512 59N 64R

7UT512

7

6/33


2

3

4

Function

51

Overcurrent

■

■

IE>, t

■2)

I>>, t

■

><,

7UM516

7UM512

I>, t(+U<)

Relay ANSI No.*

7UM515

7UM511

1

Fig. 66

Numerical generator protection Protection functions

■

51, 37

Overcurrent/Undercurrent

I

49

Thermal overload

I2t

■

46

Load unbalance

I2ln>, t

■

■

■

(I2lln)2

■

■

■

U>, t

■

■

■

U>>, t

■

■

■

U>, t

■

87

Differential protection

t

t

∆lG> ∆lT> ∆lg>

59

Overvoltage

5 27

Undervoltage

■

t = f(U<)

6 59GN

7

53GN

U< with frequency evaluation

U(f)<, t

Direct voltage

U=><, t

Stator

UE >,t

ground fault protection <90%

UE + lE>,t

Stator

RE <,t

■ ■ ■6)

■

■

■

■ ■

ground fault protection 100%

81o

8

81u 3Z 40

9 64R

10

UW >,t

Overfrequency

f>

■3)

■4)

■3)

f<

■3)

■4)

■3)

■7)

Underfrequency Reverse power

(–P)>, t

■

Forward power1)

(+P)>, t

■

Underexcitation (field failure)

ϑ>, t

■

protection

ϑ1 + Ue>, t

■

Rotor

RE<, t(fN)

ground fault protection

RE<, t(1Hz)

IE>, t(fN)

24

■

Interturn fault protection

■ ■

■7) ■ ■

■2)

Overexcitation

U/f >, t

■ ■

protection

(U/f)2 t

21

Impedance protection

Z<, t

■

78

Out-of-step protection

ϑ(Z) >, n

■

87N

Restricted ground fault prot.

∆lE

Trip control inputs

t, trip

Trip circuit monitoring

4

4

4

4

2

2

2

2


6/34

1) for special applications 2) IE> sensitive stage, suitable for rotor or stator earth fault protection 3) altogether 4 frequency stages, to be used as either f> or f< 4) altogether 4 frequency stages, to be used as either f> or f< 5) tank protection 6) evaluation of displacement voltage 7) 1 stage



7VK512

7RW600

Autoreclose and check-synchronism relay

Voltage and Frequency Relay

Highly flexible autoreclose relay with or without check-synchronism function. Available functions include: ■ Single or/and three-pole auto-reclosure ■ Up to 10 autoreclose shots ■ Independently settable dead times and reclaim time ■ Sequential fault recognition ■ Check-synchronism or dead line/dead bus charging ■ Selectable setting groups ■ Event and fault recording (voltage inputs)

■ Intelligent protection and monitoring

7SV512 Breaker failure protection relay ■ Variable and failsafe breaker failure pro-

■ ■ ■ ■ ■ ■

tection (2-out-of-4 current check, 2-channel logic and trip circuits) Phase selective for single and three-pole autoreclosure Reset time < 10 ms (sinusoidal current) < 20 ms worst case “No current“ condition control using the breaker auxiliary contacts Integral end fault protection Selectable setting groups Event and fault recording

1

device ■ Two separate voltage measuring inputs ■ Applicable as two independent single-

■ ■ ■ ■ ■

■ ■ ■

phase units or one multiphase unit (positive sequence voltage) High-set and low-set voltage supervision U>>, U>, U< 4-step frequency supervision f>< 4-step rate of change of frequency supervision df/dt> All voltage, frequency and df/dt steps with separate definite time delay setting Overfluxing (overexcitation) protection U/f (t) as thermal model, U/f >> (DT delay) Voltage and frequency indication Fault recording (momentary or RMS values) RS485 serial interface for connection of a PC or coordination with control systems

2

3

4

59

27

59N

81

5

24

6

Fig. 67: 7RW600

7

7SV600 Breaker failure protection relay ■ Phase selective for single and three-pole

autoreclosure

8

■ Reset time < 10 ms (Sinusoidal current) ■ ■ ■ ■

< 20 ms worst case “No current“ condition control using the breaker auxiliary contacts Selectable setting groups Event and fault recording Lockout of trip command

9

10 50 BF

Fig. 68: 7SV600


6/35

Power System Protection Relay Dimensions

1

Case 7XP20 for relays 7SJ600, 7RW600, 7SD600, 7SV600 Back view

Panel cutout

Side view

70

7.3

2

71+2

56.5±0.3

ø5 or M4 244

266

255±0.3

245+1

3 ø6 75

4

37

29.5

172

Fig. 69

Case 7XP2030-2 for relays 7SD511, 7SJ511/12, 7SJ531, 7UT512, 7VE51, 7SV512, 7SK512

5

145

6

Panel cutout

Side view

Front view 30

172

29.5

7.3 13.2

244

245

266

or M4

255.8

ø6

1.5

7 231.5

150

5.4

ø5

10 Optical fibre interface

131.5 105

146

Fig. 70

8 Case 7XP2040-2 for relays 7SA511, 7UT513, 7SD512, 7UM5**, 7VE512, 7SD502/503 Front view

9 220

Side view Optical fiber interface 30 172

Panel cutout 29.5

7.3 13.6

10

206.5 180

5.4

ø5 266 245 1,5

10

225

231.5

or M4 ø6

221

255.8

All dimensions in mm.

Fig. 71

6/36



Case 7XP2020-2 for relay 7VH83 Front view 75

1 Side view 172 30

Back view 70

29.5

7.3 13.2

Panel cutout 56.3 30 5.4

2

ø5 244

or M4

266

245

255.8

3

ø6 71

4

Fig. 72

Case 7XP2010-2 for relay 7VH80, 7TR93 Front view 75

Back view

Side view 30

172

70

29.5

111.0

7.3 20.5

112

133

5

Panel cutout 56.3 30 5.4

ø5 or M4

122.5

6

ø6 71 Fig. 73

7

Case for relay 7SJ551 Front view 105

30

8

Back view

Side view 172

29.5

100 86.4

9

244

266

255.9

10

115 All dimensions in mm. Fig. 74


6/37


1

Case 7XP2060-2 for relay 7SA513 Panel cutout

Side view

Front view 450

30

172

29.5

445

2

7.3

431.5

13.2

405

5.4

ø 5 or M4 266

3

266 1.5

10

245

255.8

ø6 446

Optical fiber interface

4 Fig. 75

5

Case for 7SJ61, 62 29.5 1.16

Side view

Rear view 1

150/5.90 145/5.70

146/5.74

Panel cutout

172/6.77

34 1.33 Mounting plate

ø5 or M4/ 0.2 diameter

6 255.8/10.07 245/9.64

7

244/9.61

266/10.47 2 0.07

8

ø6/0.24 diameter

FO SUB-D Connector

105/4.13 131.5/5.17

RS232-port

Fig. 76a

Case for 7SJ631/632/633

9

29.5 1.16

Side view

Rear view 1

225/8.85 220/8.66

Panel cutout

221/8.70

172/6.77 Mounting plate

ø5 or M4/ 0.2 diameter

10

255.8/10.07 245/9.65

2 0.07

RS232-port

Fig. 76b

6/38

244/9.61

266/10.47 FO

ø6/0.24 diameter

SUB-D Connector 180/7.08 206.5/8.12




Case for 7SJ631/632/633 Special version with detached operator panel

Detached operator panel

Side view

Rear view

Side view

225/8.85 220/8.66 202.5/7.97

1

29.5 27.1 1.16 1.06

29 30 1.14 1.18

2

Mounting plate

266/10.47

266/10.47

3

312/12.28 244/9.61 FO

4

2 0.07

RS232port Mounting plate

Connection cable 68 poles to basic unit length 2.5 m/8 ft., 2.4 in

Fig. 77: 7SJ63, 1/2 surface mounting case (only with detached panel, see Fig. 42, page 6/21)

Case for 7SJ635/636: Special version with detached operator panel

6 Rear view

Side view

7

450/17.71 202.5/7.97

5

445/17.51

29 30 1.14 1.18

8

266/10.47

312/12.28 244/9.61

9

FO SUB-D Connector

10 Mounting plate

Fig. 78: 7SJ63, 1/1 surface mounting case (only with detached panel, see Fig. 42, page 6/21)



6/39


1

7XR9672 Core-balance current transformer (zero sequence c.t.) M6 14 K

2 L

120

3

96 104

55

102

k l 14.5 x 6.5 200

4

K 120

2

Fig. 79

5

7XR9600 Core-balance current transformer (zero sequence c.t.) 94

6 12

7

Diam. 149

80

81 Diam. 6.4 143

8

54

170 Fig. 80

9

10

6/40



4AM4930 Current summation transformer for relay 7SD600

1 121

110

92

2

G H I K L M Y

90

62

3

75

4 64

64

A B C D E F Z

5 63.5

100 63.5

110

6 G H I K L M Y

7 Fig. 81

8

9

10


6/41

Power System Protection Typical Protection Schemes

1

2

Application group

Cables and overhead lines

Circuit number

Circuit equipment protected

Page

1

Radial feeder circuit

6/43

2

Ring main circuit

6/43

3

Distribution feeder with reclosers

6/44

4

Parallel feeder circuit

6/44

5

Cable or short overhead line with infeed from both ends

6/45

6

Overhead lines or longer cables with infeed from both ends

6/45

7

Subtransmission line

6/46

8

Transmission line with reactor

6/48

9

Transmission line or cable (with wide band communication)

6/49

10

Transmission line, breaker-and-a-half terminal

6/49

11

Small transformer infeed

6/51

12

Large or important transformer infeed

6/51

13

Dual infeed with single transformer

6/52

14

Parallel incoming transformer feeder

6/52

15

Parallel incoming transformer feeder with bus tie

6/53

16

Three-winding transformer

6/53

17

Autotransformer

6/54

18

Large autotransformer bank

6/54

19

Small and medium-sized motors

6/55

20

Large HV motors

6/55

21

Smallest generator < 500 kW

6/56

22

Small generator, around 1 MW

6/56

23

Large generator > 1 MW

6/57

24

Large generator >1 MW feeding into a network with isolated neutral

6/57

25

Generator-transformer unit

6/59

26

Busbar protection by o/c relays with reverse interlocking

6/60

27

High-impedance differential busbar protection

6/61

28

Low-impedance differential busbar protection

6/61

3

4

5

Transformers

6

7 Motors

8

Generators

9

10

Busbars

Fig. 82

6/42



1. Radial feeder circuit

Infeed

Notes:

1 Transformer protection, see Fig. 94

1) Autoreclosure 79 only with O.H. lines. 2) Negative sequence o/c protection 46 as sensitive backup protection against unsymmetrical faults.

A

2

General hints: – The relay at the far end (D) gets the shortest operating time. Relays further upstream have to be time-graded against the next downstream relay in steps of about 0.3 seconds. – Inverse-time curves can be selected according to the following criteria: – Definite time: source impedance large compared to the line impedance, i.e. small current variation between near and far end faults – Inverse time: Longer lines, where the fault current is much less at the end of the line than at the local end. – Very or extremely inverse time: Lines where the line impedance is large compared to the source impedance (high difference for close-in and remote faults) or lines, where coordination with fuses or reclosers is necessary. Steeper characteristics provide also higher stability on service restoration (cold load pick-up and transformer in rush currents)

Further feeders

51

51N

46 2)

ARC

7SJ60

79 1)

3

I>, t IE>, t I2>, t

C

51

51N

7SJ60

46

4 Load I>, t IE>, t I2>, t

D

51

Load

51N

7SJ60

46

5

Load

6

Fig. 83

Infeed Transformer protection, see Fig. 97

2. Ring main circuit

52

General hints: – Operating time of overcurrent relays to be coordinated with downstream fuses of load transformers. (Preferably very inverse time characteristic with about 0.2 s grading-time delay – Thermal overload protection for the cables (option) – Negative sequence o/c protection 46 as sensitive protection against unsymmetrical faults (option)

I>, t IE>, t I2>, t

B

52

7SJ60 52

7SJ60

I>, t IE>, t I2>, t 51

7

51N

46

ϑ> 49

52

I>, t IE>, t I2>, t 51

51N

46

8

ϑ> 49

9

10

Fig. 84


6/43


3. Distribution feeder with reclosers

Infeed

1

General hints:

2 52

I>>, I>, t 50/ 51

3

52

IE>>, I2>, t IE>, t 50N/ 51N

7SJ60

46 79

Autoreclose

Further feeders

Recloser

4 Sectionalizers

5

6

Fuses

– The feeder relay operating characteristics, delay times and autoreclosure cycles must be carefully coordinated with downstream reclosers, sectionalizers and fuses. The instantaneous zone 50/50N is normally set to reach out to the first main feeder sectionalizing point. It has to ensure fast clearing of close-in faults and prevent blowing of fuses in this area (“fuse saving”). Fast autoreclosure is initiated in this case. Further time delayed tripping and reclosure steps (normally 2 or 3) have to be graded against the recloser. – The o/c relay should automatically switch over to less sensitive characteristics after longer breaker interruption times to enable overriding of subsequent cold load pick-up and transformer inrush currents.

Fig. 85

4. Parallel feeder circuit General hints:

Infeed

7

52 52

I>, t IE>, t 51

8

51N

ϑ>

I2>, t

49

46

52

7SJ60 O H line or cable 2

O H line or cable 1

9

67

67N

51

51N

Protection same as line or cable 1

– This circuit is preferably used for the interruption-free supply of important consumers without significant backfeed. – The directional o/c protection 67/67N trips instantaneously for faults on the protected line. This allows the saving of one time-grading interval for the o/crelays at the infeed. – The o/c relay functions 51/51N have each to be time-graded against the relays located upstream.

7SJ62

52

10

52 52 52

52

Load

Load

Fig. 86

6/44



5. Cables or short overhead lines with infeed from both ends

Infeed

Notes:

1

52 52

1) Autoreclosure only with overhead lines 2) Overload protection only with cables 3) Differential protection options: – Type 7SD511/12 with direct fiber-optic connection up to about 20 km or via a 64 kbit/s channel of a general purpose PCM connection (optical fiber, microwave) – Type 7SD600 with 2-wire pilot cables up to about 10 km – Type 7SD502 with 2-wire pilot cables up to about 20 km – Type 7SD503 with 3-wire pilot cables up to about 10 km. 4) Functions 49 and 79 only with relays 7SD5**. 7SD600 is a cost-effective solution where only the function 87L is required (external current summation transformer 4AM4930 to be ordered separately)

52

7SJ60

79

1)

52

2

2) 51N/ 51N Line or cable

49

87L

7SJ60

7SD600 or 7SD5**

4) Same protection for parallel line, if applicable

3)

51N/ 51N

7SD600 or 7SD5**

49

87L

3

4)

2) 79

52

52

1)

4

52 52

52

52

Load

Backfeed

52

5

Fig. 87

6. Overhead lines or longer cables with infeed from both ends

6

Infeed

Notes:

52

1) Teleprotection logic 85 for transfer trip or blocking schemes. Signal transmission via pilot wire, power-line carrier, microwave or optical fiber (to be provided separately). The teleprotection supplement is only necessary if fast fault clearance on 100% line length is required, i.e. second zone tripping (about 0.3 s delay) cannot be accepted for far end faults. 2) Directional ground-fault protection 67N with inverse-time delay against highresistance faults 3) Single or multishot autoreclosure 79 only with overhead lines 4) Reduced version 7SA510 may be used where no, or only 3-pole autoreclosure is required.

52

7 52

52 21/ 21N

67N

2)

7SA511

3) 85 Line or cable

4)

79

1) 85

79

21/ 21N

67N

8

Same protection for parallel line, if applicable

9

3)

7SA511

2)

4)

52

10

52 52

52

52

Load

Backfeed

52

52

Fig. 88


6/45


7. Subtransmission line

1

Note: 1) Connection to open delta winding if available. Relays 7SA511 and 7SJ512 can, however, also be set to calculate the zero-sequence voltage internally.

2

General hints:

1)

3 25

79

21 21N

67 67N

67N

51 51N

4 68 78

BF

5 85

6

7SA511

7SJ62

S CH R

To remote line end

– Distance teleprotection is proposed as main, and time graded directional O/C as backup protection. – The 67N function of 7SA511 provides additional high-resistance ground fault protection. It can be used in a directional comparison scheme in parallel with the 21/21N-function, but only in POTT mode. If the distance protection scheme operates in PUTT mode, 67N is only available as time-delayed function. – Recommended schemes: PUTT on medium and long lines with phase shift carrier or other secure communication channel. POTT on short lines. BLOCKING with On/Off carrier (all line lengths).

Signal transmission equipment

Fig. 89

7

8

9

10

6/46



Application criteria for frequently used teleprotection schemes

Permissive underreaching transferred tripping (PUTT) Preferred application

Signal transmission:

Line configuration:

Secure and dependable channel: ■ Frequency shift power line carrier (phase-tophase HF coupling to the protected line, better HF coupling to a parallel running line to avoid sending through the fault) ■ Microwave, in particular digital (PCM) ■ Fiber optic cables

Normally used with medium and long lines (7SA511/513 relays allow use also with short lines due to their independent X and R setting of all distance zones).

Advantages:

■ Simple method ■ Tripping of underrea-

ching zone does not depend on the channel (release signal from the remote line end not necessary). ■ No distance zone or time coordination between line ends necessary, i.e. this mode can easily be used with different relay types.

Drawbacks:

Permissive overreaching transferred tripping (POTT)

■ Short lines in particu-

lar when high fault resistance coverage is required ■ Multi-terminal and tapped lines with intermediate infeed effects

Blocking

Unblocking

1

■ Dependable chan-

Applicable only with ■ Frequency shift power line carrier

2

nel (only with external faults) ■ Amplitude modulated ON/OFF power line carrier (same frequency can be used at all terminals) All kinds of line (Preferred US practice)

3 EHV lines

4

5 ■ No distance zone

overreaching problems, when applied with CCVTs on short lines ■ Applicable to extreme short lines below the minimum zone setting limit ■ No problems with the impact of parallel line coupling.

■ Parallel, teed and

■ Distance zone and

tapped lines may cause underreach problems. Careful consideration of zerosequence coupling and intermediate infeed effects is necessary. ■ Not applicable with weak infeed terminals.

time coordination with remote line end relays necessary ■ Tripping depends on receipt of remote end signal (additional independent underreaching zone of 7SA511/ 513 relays avoids this problem). ■ Weak infeed supplement necessary

6 same as for POTT

same as for POTT

7

same as for POTT Except that a weak infeed supplement is not necessary No continuous online supervision of the channel possible!

Same as for POTT, however, loss of remote end signal does not completely block the protection scheme. Tripping is in this case released with a short time delay of about 20 ms (unblocking logic).

8

9

10

Fig. 90


6/47


8. Transmission line with reactor

1

2

Note: 1) 51G only applicable with grounded reactor neutral. 2) If phase CTs at the low-voltage reactor side are not available, the high-voltage phase CTs and the CT in the neutral can be connected to a restricted ground fault protection using one 7VH80 high-impedance relay.

3

General hints:

4

– Distance relays are proposed as main 1 and main 2 protection. Duplicated 7SA513 is recommended for long (>100 km) and heavily loaded lines or series-compensated lines and in all cases where extreme short operating times are required due to system stability problems. 7SA513 as main 1 and 7SA511 as main 2 can be used in the normal case.

5

– Operating time of the 7SA513 relay is in the range of 15 to 25 ms dependent on the particular fault condition, while the operating time of the 7SA511 is 25 to 35 ms respectively. These tripping times are valid for faults in the underreaching distance zone (80 to 85% of the line length). Remote end faults must be cleared by the superimposed teleprotection scheme. Its overall operating time depends on the signal transmission time of the channel (typically 15 to 20 ms for frequency shift audio-tone PLC or Microwave channels, and lower than 10 ms for ON/OFF PLC or digital PCM signalling via optical fibres). Teleprotection schemes based on 7SA513 and 7SA511 have therefore operating times in the order of 40 ms and 50 ms each. With state-of-the-art twocycle circuit breakers, fault clearing times well below 100 ms (4 to 5 cycles) can normally be achived. – Dissimilar carrier schemes are recommended for main 1 and main 2 protection, for example PUTT, and POTT or Blocking/Unblocking

– Both 7SA513 and 7SA511 can practise selective single-pole and/or three-pole tripping and autoreclosure. The ground current directional comparison protection 67N of the 7SA513 relay uses phase selectors based on symmetrical components. Thus, single pole autoreclosure can also be practised with high-resistance faults. The 67N function of the 7SA511 relay should be used as time delayed directional O/C backup in this case. – The 67N functions are provided as highimpendance fault protection. 67N of the 7SA513 relay is normally used with an additional channel as separate carrier scheme. Use of a common channel with distance protection is only possible in the POTT mode. The 67N function in the 7SA511 is blocked when function 21/ 21N picks up. It can therefore only be used in parallel with the distance directional comparison scheme POTT using one common channel. Alternatively, it can be used as time-delayed backup protection.

6 CC 52L TC1

7

50 50N

CVT

8

Reactor 21 21N

25

21 21N

79

67N

79

67N

68 79

BF

68 79

85

25

9

59

85

10

7SJ600

52R

TC2

7SA513

87R

51 51N

BF

7VH83 2)

51G

7SA522 or 7SA511

7SJ600

BF BF, 59 Trip 52L

S Direct Trip R Channel S Channel 2 R

To remote line end

S Channel 3 R Fig. 91

6/48



9. Transmission line or cable (with wide band communication)

CC

Note: 1) Overvoltage protection only with 7SA513

1

52L TC1

TC2

General hints: – Digital PCM coded communication (with n x 64 kBit/s channels) between line ends is now getting more and more frequently available, either directly by optical or microwave point-to-point links, or via a general purpose digital communication network. In both cases, the unit-type current comparison protection 7SD511/12 can be applied. It provides absolute phase andzone selectivity by phase-segregated measurement, and is not affected by power swing or parallel line zero-sequence coupling effects. It is further a current-only protection that does not need VT connection. For this reason, the adverse effects of CVT transients are not applicable. This makes it in particular suitable for double and multicircuit lines where complex fault situations can occur. Pilot wire protection can only be applied to short lines or cables due to the inherent limitation of the applied measuring principle. The 7SD511/12 can be applied to lines up to about 20 km in direct relay-to-relay connection via dedicated optical fiber cores (see also application 5), and also to much longer distances up to about 100 km by using separate PCM devices for optical fiber or microwave transmission. The 7SD511/512 then uses only a small part (64 kBit/s) of the total transmission capacity being in the order of Mbits/s. – The unit protection 7SD511 can be combined with the distance relay 7SA513 or 7SA511 to form a redundant protection system with dissimilar measuring principles complementing each other. This provides the highest degree of availability. Also, separate signal transmission ways should be used for main 1 and main 2 protection, e.g. optical fiber or micro-wave, and power line carrier (PLC). 1. The criteria for selection of 7SA513 or 7SA511 are the same as discussed in application 8. The current comparison protection has a typical operating time of 25 ms for faults on 100% line length including signalling time.

2 1) 79

97L

25

59

21 21N

3 BF

79

68 79

67N

85

BF

4

7SA522 or 7SA511

7SD512

S Channel 1 R optial fiber

FO Wire

X.21

S R

PCM

To remote line end

Direct connection with dedicated fibers up to about 20 km

5

6

Fig. 92

10. Transmission line, breaker-and-a-half terminal

7

Notes: 1) When the line is switched off and the line isolator is open, high through-faultcurrents in the diameter may cause maloperation of the distance relay due to unequal CT errors (saturation). Normal practice is therefore to block the distance protection (21/21N) and the directional ground fault protection (67N) under this condition via an auxiliary contact of the line isolator. Instead, a standby overcurrent function (50/50N, 51/51N) is released to protect the remaining stub between the breakers (“stub“protection). 2) Overvoltage protection only with 7SA513

8

9

10

General hints: – The protection functions of one diameter of a breaker-and-a-half arrangement are shown. – The currents of two CTs have each to be summed up to get the relevant line current as input for main 1 and 2 line protection.


6/49


1

2

3

– The location of the CTs on both sides of the circuit-breakers is typical for substations with dead-tank breakers. Live-tank breakers may have CTs only on one side to reduce cost. A Fault between circuit breakers and CT (end fault) may then still be fed from one side even when the breaker has opened. Consequently, final fault clearing by cascaded tripping has to be accepted in this case. The 7SV512 relay provides the necessary end fault protection function and trips the breakers of the remaining infeeding circuits.

– For the selection of the main 1 and main 2 line protection schemes, the comments of application examples 8 and 9 apply. – Autoreclosure (79) and synchrocheck function (25) are each assigned directly to the circuit breakers and controlled by main 1 and 2 line protection in parallel. In case of a line fault, both adjacent breakers have to be tripped by the line protection. The sequence of automatic reclosure of both breakers or, alternatively, the automatic reclosure of only

one breaker and the manual closure of the other breaker, may be made selectable by a control switch. – A coordinated scheme of control circuits is necessary to ensure selective tripping, interlocking and reclosing of the two breakers of one line (or transformer feeder). – The voltages for synchrochecking have to be selected according to the breaker and isolator positions by a voltage replica circuit.

87 7SS5. or BB1 7VH83

4

5

7VK512

UBB1

BB1

BF

7SV512 or 7SV600

85 21 21N

79 52

UBB1 UL1 or UL2 or UBB2

6

67N

1) 1) 2) 50 51 59 50N 51N

7SA522 or 7SA511

25

UL1 Line 1

7VK512

7

87L 7SD511/12

79 52

8

UL1 or UBB1 UL2 or UBB2

25 BF

7SV512 or 7SV600 Line 2

9

7VK512

UL2

79

10

UL2 or UL1 or UBB1 UBB2

UBB2

Main 1

52

Main 2

25

Protection of Line 2 (or transformer, if applicable)

BF

7SV512 or 7SV600

BB2

87 7SS5. or BB2 7VH83

Fig. 93

6/50



11. Small transformer infeed

HV infeed

General hints: – Ground-faults on the secondary side are detected by current relay 51G which, however, has to be time-graded against downstream feeder protection relays. The restricted ground-fault relay 87N can optionally be provided to achieve fast clearance of ground faults in the transformer secondary winding. Relay 7VH80 is of the high-impedance type and requires class X CTs with equal transformation ratio. – Primary breaker and relay may be replaced by fuses.

52

1 I>>

I>, t

IE>

ϑ> I2>, t

50

51

50N

49

63

7SJ60

46

2

Optional resistor or reactor

RN

3

I>> 87N 51G 52

7VH80

7SJ60

IE>

4

Distribution bus 52 Fuse

o/crelay

5

Load

Load Fig. 94

6

12. Large or important transformer infeed HV infeed

Notes:

High voltage, e.g. 115 kV 52

1) Three winding transformer relay type 7UT513 may be replaced by twowinding type 7UT512 plus high-impedance-type restricted ground-fault relay 7VH80. However, class X CT cores would additionally be necessary in this case. (See small transformer protection) 2) 51G may additionally be provided, in particular for the protection of the neutral resistance, if provided. 3) Relays 7UT512/513 provide numerical ratio and vector group adaption. Matching transformers as used with traditional relays are therefore no longer applicable.

I>>

I>, t

IE>

ϑ>

I2>, t

50

51

51N

49

46

7

7SJ60 or 7SJ61

2) 51G

7SJ60

8

63 1) 87N

52

I>, t

IE>, t

51

51N

87T

7UT513

9

10

7SJ60 Load bus, e.g. 13.8 kV

52

52

Load

Load

Fig. 95


6/51


13. Dual-infeed with single transformer

1

Protection line 2 21/21N or 87L + 51 + optionally 67/67N 52

Protection line 1 same as line 2 52

Notes: 1) Line CTs are to be connected to separate stabilizing inputs of the differential relay 87T in order to assure stability in case of line through-fault currents. 2) Relay 7UT513 provides numerical ratio and vector group adaption. Matching transformers, as used with traditional relays, are therefore no longer applicable.

7SJ60 or 7SJ61

2

I>>

I>, t

IE>, t

50

51

51N

46

49

I2>

ϑ>

3 63

4

87N

7SJ60

5

87T

7UT513

51G

I>>

IE>

51

51N

7SJ60

52 52

52

Load bus

52

Load

6 Fig. 96

7

7SJ60 or 7SJ61

HV infeed 1 52

I>>

I>, t

50

51

HV infeed 2

IE>, t ϑ> 51N

49

Note:

52

I2>, t 46

8 Protection 63

9

51G

IE>, t

51

7SJ60

10

I> 67

51N

1) The directional functions 67 and 67N do not apply for cases where the transformers are equipped with transformer differential relays 87T.

same as infeed 1

7SJ62

I>, t IE>, t

14. Parallel incoming transformer feeders

IE> 67N

1) 52

52 Load bus 52

52 Load

52 Load

Load

Fig. 97

6/52



15. Parallel incoming transformer feeders with bus tie

7SJ60

Infeed 1

Note: 1) Overcurrent relays 51, 51N each connected as a partial differential scheme. This provides simple and fast busbar protection and saves one time-grading step.

I>>

I>, t

50

51

IE>, t ϑ> 51N

I2>, t

49

46

63

51G

7SJ60

7SJ60

I>, t IE>, t

IE>, t I>, t

51N

51N

2

Protection same as infeed 1

63

51

1

Infeed 2

3

51

7SJ60

4

16. Three-winding transformer

52

52

Notes: 1) The zero-sequence current must be blocked from entering the differential relay by a delta winding in the CT connection on the transformer sides with grounded winding neutral. This is to avoid false operation with external ground faults (numerical relays provide this function by calculation). About 30% sensitivity, however, is then lost in case of internal faults. Optionally, the zero-sequence current can be regained by introducing the winding neutral current in the differential relay (87T). Relay type 7UT513 provides two current inputs for this purpose. By using this feature, the ground fault sensitivity can be upgraded again to its original value. 2) Restricted ground fault protection (87T) is optional. It provides back-up protection for ground faults and increased ground fault sensitivity (about 10%IN, compared to about 20 to 30%IN of the transformer differential relay). Separate class X CT-cores with equal transmission ratio are additionally required for this protection.

52 52

5 Load

Load

Fig. 98

6 HV Infeed 52

51G 7SJ60

I>>

I>, t

ϑ>

I2>, t

50

51

49

46

7

7SJ60 or 7SJ61

8

51G 7SJ60

63

87T 7UT513

1) 87N 7VH80

87N 7VH80

I>,t

General hint: – In this example, the transformer feeds two different distribution networks with cogeneration. Restraining differential relay inputs are therefore provided at each transformer side. If both distribution networks only consume load and no through-feed is possible from one MV network to the other, parallel connection of the CTs of the two MV transformer windings is admissible allowing the use of a two-winding differential relay (7UT512).

52

51

IE>, t 51N

9

I>,t

IE>, t

51

51N

7SJ60

10

7SJ60

M.V.

M.V. 52

52

52

52

Load

Backfeed

Load

Backfeed

Fig. 99


6/53


17. Autotransformer

7SJ60 or 7SJ61

1

50 BF

51N

Notes:

52 50 51

46

1) 87N high-impedance protection requires special class X current transformer cores with equal transmission ratio. 2) The 7SJ60 relay can alternatively be connected in series with the 7UT513 relay to save this CT core.

87N 7VH80

2) 1)

2 7UT513

87T

General hint:

49 63

3 52

52 1)

50 51

51

4

46 59N

50 BF

7RW60

7SJ60

50 BF

1)

– Two different protection schemes are provided: 87T is chosen as low-impedance threewinding version (7UT513). 87N is a single-phase high-impedance relay (7VH80) connected as restricted ground fault protection. (In this example, it is assumed that the phaseends of the transformer winding are not accessible on the neutral side, i.e. there exists a CT only in the neutral grounding connection.)

51N

5

7SJ60

6

Fig. 100

18. Large autotransformer bank

21

21N

7SV600

7

68 78

7SA513

50 BF

50 BF 52

EHV

General hints:

7SV600

52

8

HV 50 BF 7SV600

87

7VH83 TH 52

9

7SA511 7UT513

87 TL

49

21 63

10

21N 52

68 78

– The transformer bank is connected in a 11/2 breaker arrangement. Duplicated differential protection is proposed: Main 1: Low-impedance differential protection 87TL (7UT513) connected to the transformer bushing CTs. Main 2: High-impedance overall differential protection 87TH (7VH83). Separate class X cores and equal CT ratios are required for this type of protection. – Back-up protection is provided by distance relays (7SA513 and 7SA511), each “looking“ with an instantaneous first zone about 80% into the transformer and with a time-delayed zone beyond the transformer. – The tertiary winding is assumed to feed a small station supply network with isolated neutral.

51 52

59N

50 BF

51G

7RW60

7SJ60

7SJ60

50 BF 7SV600

Fig. 101

6/54



19. Small and medium-sized motors < about 1 MW a) With effective or low-resistance grounded infeed (IE ≥ IN Motor)

52

General hint: – Applicable to low-voltage motors and high-voltage motors with low-resistance grounded infeed (IE ≥ IN Motor).

I>>

I E>

ϑ>

50

51N

49

Locked rotor 49 CR

1

I 2>

7SJ60

46

2

M Fig. 102a

3

b) With high-resistance grounded infeed (IE ≤ IN Motor)

52

Notes: 1) Window-type zero sequence CT. 2) Sensitive directional ground-fault protection 67N only applicable with infeed from isolated or Peterson-coil-grounded network. (For dimensioning of the sensitive directional ground fault protection, see also application circuit No. 24) 3) If 67G ist not applicable, relay 7SJ602 can be applied.

I>>

ϑ>

50

49

I E>

7XR96 1) 60/1A

51G

Locked rotor 49 CR

I 2>

I<

46

37

7SJ62 or 7SJ551

4

3)

2) 67G

5

M 6

Fig. 102b

20. Large HV motors > about 1 MW Notes: 1) Window-type zero sequence CT. 2) Sensitive directional ground-fault protection 67N only applicable with infeed from isolated or Peterson-coil-grounded network. 3) This function is only needed for motors where the runup time is longer than the safe stall time tE. According to IEC 79-7, the tE-time is the time needed to heat up AC windings, when carrying the starting current IA, from the temperature reached in rated service and at maximum ambient temperature to the limiting temperature. A separate speed switch is used to supervise actual starting of the motor. The motor breaker is tripped if the motor does not reach speed in the preset time. The speed switch is part of the motor delivery itself. 4) Pt100, Ni100, Ni120 5) 49T only available with relay type 7SJ5 6) High impedance relay 7VH83 may be used instead of 7UT12 if separate class x CTs. are provided at the terminal and star-point side of the motor winding.

7SJ62 or 7SJ551 52

I>>

ϑ>

50

49 2)

IE>

7XR96 1) 60/1A

51G

Locked rotor 49 CR

M

I2>

U<

46

27

I< 37

8

Optional

67G

Startup super49T visior 3) 5) 3) Speed switch

7

9 7UT512

87M 6)

RTD's 4) optional

10

Fig. 103


6/55


21. Smallest generators < 500 kW LV

1

G

I>, IE>, t

I2>

ϑ>

51 51N

46

49

2

3

7SJ60

Fig. 104a: With solidly grounded neutral

Note: MV

4

G1

Generator 2

1)

5 RN =

I>, IE>, t

I2>

ϑ>

51 51N

46

49

7SJ60

1) If a window-type zero-sequence CT is provided for sensitive ground fault protection, relay 7SJ602 with separate ground current input can be used (similar to Fig. 102b of application example 19b).

VN √3 • (0.5 to 1) • Irated

6 Fig. 104b: With resistance grounded neutral

22. Small generator, typically 1 MW

7

Note: 1) Two CTs in V connection also sufficient.

52

1)

8 Field

G

9

64R

I>, t 51

P 32

I2 > 46

L.O.F 40

7UM511

10 IE>, t 51G

Fig. 105

6/56



23. Smallest generators > 1 MW

MV

Notes:

1

52

1) Functions 81 und 59 only required where prime mover can assume excess speed and voltage regulator may permit rise of output voltage above upper limit. 2) Differential relaying options: – 7UT512: Low-impedance differential protection 87 – 7UT513: Low-impedance differential 87 with integral restricted groundfault protection 87G – 7VH83: High-impedance differential protection 87 (requires class X CTs) 3) 7SJ60 used as voltage-controlled o/c protection. Function 27 of 7UM511 is used to switch over to a second, more sensitive setting group.

3) 51

2) 87

O/C v.c.

7SJ60

2

I IG

87G

27

U<

81

f>

59

U>

1)

G

64R Field

3

1)

RE Field<

I>, t

P

I2>

L.O.F.

51

32

46

40

IE>, t

ϑ>

4

49

7UM511

5

51G

6 Fig. 106

24. Large generator > 1 MW feeding into a network with isolated neutral

Relay ground current input connected to:

Minimum relay setting:

Comments:

7

General hints: – The setting range of the directional ground fault protection 67G in the 7UM511 relay is 2 – 100 mA. Dependent on the current transformer accuracy, a certain minimum setting is required to avoid false operation on load or transient rush currents:

Core-balance c.t. 60/1 A: 1 single CT 2 parallel CTs 3 parallel CTs 4 parallel CTs

2 mA 5 mA 8 mA 12 mA

8

Three-phase-CTs in residual (Holmgreen) connection

1A CT: ca. 50 mA 5A CT: ca. 200 mA

In general not suitable for sensitive earth fault protection

Three-phase-CTs in residual (Holmgreen) connection with special factory calibration to minimum residual false current (≤ 2 mA)

2 – 3‰ of secondary rated CT current In SEC:

1A CTs are not recommented in this case

10 – 15 mA with 5A CTs

10

Fig. 107


9

6/57


1

2

3

4

5

6

– In practice, efforts are generally made to protect about 90% of the machine winding, measured from the machine terminals. The full ground current for a terminal fault must then be ten times the setting value which corresponds to the fault current of a fault at 10% distance from the machine neutral. For the most sensitive setting of 2 mA, we need therefore 20 mA secondary ground current, corresponding to (60/1) x 20 mA = 1.2 A primary. This current may be delivered by the network ground capacitances if enough cables are contained. In this case, the directional ground fault protection (67G) has to be set to reactive power measurement (U x I x sin w). If sufficient capacitive ground current is not available, a grounding transformer with resistive zero-sequence load can be installed as ground current source at the station busbar. The 67G function has in this case to be set to active (wattmetric) power measurement (U x I x cosw). The smallest standard grounding transformer TGAG 3541 has a 20 s short time rating of PG = 27 kVA.

8

9

10

3)

52

Grounding transformer UN 100 500 V 3 3 3

1)

7XR96 60/1A

59 G 52

62

RB 87

7UT512

Field

G

REF<

IE

U<

U>

f

64 F

67 G

27

59

81

Uo > 59 G 4) I>,t 51

7UM512

I2>

P

L.O.F

46

32

40

In a 5kV network, it would deliver: 2) IG 20s

7

Small grid with isolated neutral

A 3 x PG A 3 x 27,000VA = ––––––- = –––––––––––– = 9.4 A UN 5000V

corresponding to a relay input current of 9.4 A x 1/60 = 156 mA. This would provide a 90% protection range with a setting of about 15 mA, allowing the use of 4 parallel connected core balance CTs. The resistance at the 500V open-delta winding of the grounding transformer would then have to be designed for RG = USEC2 / PG = 500 V2 / 27,000 VA = 9.26 Ohm (27 KW, 20 s). For a 5 MVA machine and 600/5 A CTs with special calibration for minimum residual false current, we would get a secondary current of IG SEC = 9.4 A /(600/5) = 78 mA. With a relay setting of 12 mA, the protection range would in this case be 12 100 (1- ––) = 85%. 78

6/58

Single-phase VT

Fig. 108

Notes: 1) The standard core-balance CT 7XR96 has a transformation ratio of 60/1 A. 2) Instead of an open delta winding at the terminal VT, a single-phase VT at the machine neutral could be used as zerosequence polarizing voltage. 3) The grounding transformer is designed for a short-time rating of 20 seconds. To prevent overloading, the load resistor is automatically switched off by a time-delayed zero-sequence voltage relay (59G + 62) and a contactor (52). 4) During the startup time of the generator with open breaker, the grounding source is not available. To ensure ground fault protection during this time interval, an auxilliary contact of the breaker can be used to change over the directional ground fault relay function (67G) to a zero-sequence voltage detection function (59G) via a contact converter input.



25. Generator-transformer unit

1

Notes:

52

Transf. fault press

63

Unit trans.

71

87 TU

Oil low

2

3

51 TN 87U

1) 100% stator ground-fault protection based on 20 Hz voltage injection 2) Sensitive field ground-fault protection based on 1 Hz voltage injection 3) Only used functions shown, further integrated functions available in each relay type (see ”Relay Selection Guide“, Fig. 43).

Transf. neut. OC

Unit aux. backup

Unit diff. 51

4

Oil low Transf. fault press

71 63

5 Overvolt.

Unit aux.

59 81N 78

Loss of sync.

Volt/Hz

87G

Reverse power

Relay type

Gen. diff.

2) 64 R2

64R

Field grd.

Field grd.

7

Trans. diff. 32

E

G

87T

A

Loss of field

49S

6

Trans. neut. OC

24 40

Stator O.L.

51 TN

Overfreq.

46 Neg. seq.

51 1) GN

Functions 3)

Number of relays required

7UM511

40

46

59

81N

7UM516

59 GN

32

21

78

7UM515

24

51 GN

7UT512

87G

87T

7UT513

87U

7SJ60

51N

49

64R

1

9

21 Sys. backup

59 GN Gen. neut. OV

1)

64 R2

1

2)

and optionally

10

1 87 TU

2 optionally 3 1

51

3

Fig. 109


8

6/59


26. Busbar protection by O/C relays with reverse interlocking

1

Infeed

General hint: Applicable to distribution busbars without substantial (< 0.25 x IN) backfeed from the outgoing feeders

2 Reverse interlocking

3

I>, t0 50 50N

I>, t 51 51N

7SJ60

52

4

t0 = 50 ms

5 52

6

I>

I>, t

50 50N

51 51N

7SJ60

52 I>

I>, t

50 50N

51 51N

7SJ60

52 I>

I>, t

50 50N

51 51N

7SJ60

7

8

Fig. 110

9

10

6/60



27. High impedance busbar protection

1 Transformer protection

General hints: – Normally used with single busbar and 1 1/2 breaker schemes – Requires separate class X current transformer cores. All CTs must have the same transformation ratio

51 51N

2

7VH83

Note:

87 BB

1) A varistor is normally applied accross the relay input terminals to limit the voltage to a value safety below the insulation voltage of the secondary circuits (see page 6/70).

87 S.V.

3

1) 86 52

52

52

Alarm

4 Feeder protection

G

Feeder protection

Feeder protection

5

G

Load

Fig. 111

6 28. Low-impedance busbar protection Infeed

General hints: – Preferably used for multiple busbarschemes where an isolator replica is necessary – The numerical busbar protection 7SS5 provides additional breaker failure protection – CT transformation ratios can be different, e.g. 600/1 A in the feeders and 2000/1 at the bus tie – The protection system and the isolator replica are continuously self-monitored by the 7SS5 – Feeder protection can be connected to the same CT core.

Transformer protection

7

50 50N 52

8

9 52

Isolator replica

Bus tie protection

87 BB

52

52 Feeder protection Load

7SS5

10

86 Feeder protection

BF

Back-feed

Fig. 112


6/61

Power System Protection Protection Coordination

Protection coordination 1

2

Relay operating characteristics and their setting must be carefully coordinated in order to achieve selectivity. The aim is basically to switch off only the faulted component and to leave the rest of the power system in service in order to minimize supply interruptions and to assure stability. Sensivity

3

Protection should be as sensitive as possible to detect faults at the lowest possible current level. At the same time, however, it should remain stable under all permissible load, overload and through-fault conditions.

4

6

The pick-up values of phase o/c relays are normally set 30% above the maximum load current, provided that sufficient shortcircuit current is available. This practice is recommmended in particular for mechanical relays with reset ratios of 0.8 to 0.85. Numerical relays have high reset ratios near 0.95 and allow therefore about 10% lower setting. Feeders with high transformer and/or motor load require special consideration. Transformer feeders

7

8

9

10

^ IRush ^ IN

12.0 11.0 10.0 9.0 8.0 7.0 6.0 5.0 4.0 3.0

Phase-fault relays

5

Peak value of inrush current

The energizing of transformers causes inrush currents that may last for seconds, depending on their size (Fig. 113). Selection of the pickup current and assigned time delay have to be coordinated so that the rush current decreases below the relay o/c reset value before the set operating time has elapsed. The rush current typically contains only about 50% fundamental frequency component. Numerical relays that filter out harmonics and the DC component of the rush current can therefore be set more sensitive. The inrush current peak values of Fig. 113 will be nearly reduced to one half in this case. Ground-fault relays Residual-current relays enable a much more sensitive setting, as load currents do not have to be considered (except 4-wire circuits with single-phase load). In solidly and low-resistance grounded systems a setting of 10 to 20% rated load current is generally applied.

6/62

2.0 1.0 2

10

100

400

Rated transformer power [MVA]

Time constant of inrush current Nominal power [MVA]

0.5 . . . 1.0

1.0 . . . 10

>10

Time constant [s]

0.16 . . . 0.2

0.2 . . . 1.2

1.2 . . . 720

Fig. 113: Transformer inrush currents, typical data

High-resistance grounding requires much more sensitive setting in the order of some amperes primary. The ground-fault current of motors and generators, for example, should be limited to values below 10 A in order to avoid iron burning. Residual-current relays in the star point connection of CTs can in this case not be used, in particular with rated CT primary currents higher than 200 A. The pickup value of the zero-sequence relay would in this case be in the order of the error currents of the CTs. A special zero-sequence CT is therefore used in this case as ground current sensor. The window-type current transformer 7XR96 is designed for a ratio of 60/1 A. The detection of 6 A primary would then require a relay pickup setting of 0.1 A secondary.

An even more sensitive setting is applied in isolated or Peterson-coil-grounded networks where very low ground currents occur with single-phase-to-ground faults. Settings of 20 mA and less may then be required depending on the minimum ground-fault current. Sensitive directional ground-fault relays (integrated in the relays 7SJ512, 7SJ55 and 7SA511) allow settings as low as 5 mA.



Differential relays (87) Transformer differential relays are normally set to pickup values between 20 and 30% rated current. The higher value has to be chosen when the transformer is fitted with a tap changer. Restricted ground-fault relays and highresistance motor/generator differential relays are, as a rule, set to about 10% rated current.

Time in seconds

1000 100

Time grading of o/c relays (51) The selectivity of overcurrent protection is based on time grading of the relay operating characteristics. The relay closer to the infeed (upstream relay) is time-delayed against the relay further away from the infeed (downstream relay). This is shown in Fig. 116 by the example of definite time o/c relays. The overshoot times takes into account the fact that the measuring relay continues to operate due to its inertia, even when the fault current is interrupted. This may

2

10 1

Instantaneous o/c protection (50) This is typically applied on the final supply load or on any protective device with sufficient circuit impedance between itself and the next downstream protective device. The setting at transformers, for example, must be chosen about 20 to 30% higher than the maximum through-fault current. Motor feeders The energizing of motors causes a starting current of initially 5 to 6 times rated current (locked rotor current). A typical time-current curve for an induction motor is shown in Fig. 114. In the first 100 ms, a fast decaying assymetrical inrush current appears additionally. With conventional relays it was current practice to set the instantaneous o/c step for short-circuit protection 20 to 30% above the locked-rotor current with a shorttime delay of 50 to 100 ms to override the asymmetrical inrush period. Numerical relays are able to filter out the asymmetrical current component very fast so that the setting of an additional time delay is no longer applicable. The overload protection characteristic should follow the thermal motor characteristic as closely as possible. The adaption is to be made by setting of the pickup value and the thermal time constant, using the data supplied by the motor manufacturer. Further, the locked-rotor protection timer has to be set according to the characteristic motor value.

1

10000

3

.1 .01 .001 0

1

2

3

4

5

6

7

8

9

10

4

Current in multplies of full-load amps Motor starting current

High set instantaneous o/c step

Locked rotor current

Motor thermal limit curve

Overload protection characteristic

Permissible locked rotor time

5

Fig. 114: Typical motor current-time characteristics

6 Time 51

7 51

51

8 Main 0.2–0.4 seconds Feeder

Maximum feeder fault level

9

Current

Fig. 115: Coordination of inverse-time relays

be high for mechanical relays (about 0.1 s) and negligible for numerical relays (20 ms). Inverse-time relays (51) For the time grading of inverse-time relays, the same rules apply in principle as for the definite time relays. The time grading is first calculated for the maximum fault level and then checked for lower current levels (Fig. 115).


If the same characteristic is used for all relays, or when the upstream relay has a steeper characteristic (e.g. very much over normal inverse), then selectivity is automatically fulfilled at lower currents.

6/63

10


1

Operating time 52 M 51 M

2 52 F

52 F 51 F

51 F

3

0.2–0.4 Time grading

4 Fault Fault inception detection

5

t51F

I>

Set time delay

Interruption of fault current t52F Circuit-breaker Interruption time Overshoot* tOS Margin tM

6 I> t51M

*

7

also called overtravel or coasting time

t51M – t51F = t52F + tOS + tM

8

Time grading tTG

Example 1

9

Mechanical relays: tOS = 0.15 s Oil circuit-breaker t52F = 0.10 s Safety margin for measuring errors, etc.: tM = 0.15

tTG = 0.10 + 0.15 + 0.15 = 0.40 s

10 Example 2 Numerical relays: tOS = 0.02 s Vacuum breaker: Safety margin:

t52F = 0.08 s tM = 0.10 s

tTG = 0.08 + 0.02 + 0.10 = 0.20 s

Fig. 116: Time grading of overcurrent-time relays

6/64



Calculation example The feeder configuration of Fig. 117 and the assigned load and short-circuit currents are given. Numerical o/c relays 7SJ60 with normal inverse-time characteristic are applied. The relay operating times dependent on current can be taken from the diagram or derived from the formula given in Fig. 118. The IP /IN settings shown in Fig. 117 have been chosen to get pickup values safely above maximum load current. This current setting shall be lowest for the relay farthest downstream. The relays further upstream shall each have equal or higher current setting. The time multiplier settings can now be calculated as follows: Station C: ■ For coordination with the fuses, we

consider the fault in location F1. The short-circuit current related to 13.8 kV is 523 A. This results in 7.47 for I/IP at the o/c relay in location C. ■ With this value and TP = 0.05 we derive from Fig. 118 an operating time of tA = 0.17 s This setting was selected for the o/c relay to get a safe grading time over the fuse on the transformer low-voltage side. The setting values for the relay at station C are therefore: ■ Current tap: IP /IN = 0.7 ■ Time multipler: TP = 0.05 Station B: The relay in B has a back-up function for the relay in C. The maximum through-fault current of 1.395 A becomes effective for a fault in location F2. For the relay in C, we obtain an operating time of 0.11 s (I/IP = 19.9). We assume that no special requirements for short operating times exist and can therefore choose an average time grading interval of 0.3 s. The operating time of the relay in B can then be calculated: ■ tB = 0.11 + 0.3 = 0.41 s ■ Value of IP /IN = 1395 A = 6.34 220 A see Fig. 117. ■ With the operating time 0.41 s and IP /IN = 6.34, we can now derive TP = 0.11 from Fig. 118.

Example: Time grading of inverse-time relays for a radial feeder

1 Load

F4

A

F3

B

F2

C

13.8 kV/ 0.4 kV

Fuse: D 160 A

Load

13.8 kV 51 7SJ60

51 7SJ60

51 7SJ60

1.0 MVA 5.0%

Load

Max. Load [A]

Iscc. max.* [A]

CT ratio

Ip/IN **

Iprim*** [A]

I /Ip =

A

300

4500

400/5

1.0

400

11.25

B

170

2690

200/5

1.1

220

12.23

100/5 –

0.7

70 –

19.93 –

D

50 –

1395 523

–

2

L.V. 75.

Station

C

F1

Iscc. max. Iprim

3

4

*) Iscc.max. = Maximum short-circuit current ** Ip/IN = Relay current multiplier setting *** Iprim = Primary setting current corresponding to Ip/IN

Fig. 117

The setting values for the relay at station B are herewith ■ Current tap: IP /IN = 1.1 ■ Time multiplier TP = 0.11 Given these settings, we can also check the operating time of the relay in B for a close-in fault in F3: The short-circuit current increases in this case to 2690 A (see Fig. 117). The corresponding I/IP value is 12.23. ■ With this value and the set value of TP = 0.11 we obtain again from Fig. 118 an operating time of 0.3 s. Station A:

5 t [s] 100

6

50 40 30 Tp [s]

20

7 10 3.2 5 4 3

1.6

2

0.8

1

0.4

0.50 0.4 0.3

0.2

0.2

0.1

8

■ We add the time grading interval of

0.3 s and find the desired operating time tA = 0.3 + 0.3 = 0.6 s. Following the same procedure as for the relay in station B we obtain the following values for the relay in station A: ■ Current tap: IP /IN = 1.0 ■ Time multiplier: TP = 0.17 ■ For the close-in fault at location F4 we obtain an operating time of 0.48 s.

0.05

0.1 0.05 2

4

6 8 10

Normal inverse 0.14 . Tp [s] t= (I/Ip)0.02 – 1

20 I/Ip [A]

Fig. 118: Normal inverse time-characteristic of relay 7SJ60


6/65

9

10


I – 0.4 kVmax = 16.000 kA Iscc = 1395 A Iscc = 2690 A Imax = 4500 A

t [s]

2

t [min]

1

Setting range

IN A

Ip = 0.10 – 4.00 xIn I>> I>, t 7SJ600 Tp = 0.05 – 3.2 s I>>= 0.1 – 25. xIn

400/5 A

100 1

3

5 52

Bus-B

10 200/5 A

2

5

1

52

5

IA>,t

2

IB>,t

.1

IC>,t

Ip = 0.10 – 4.00 xIn I>> I>, t 7SJ600 Tp = 0.05 – 3.2 s I>> = 0.1 – 25. xIn

Ip = 1.1 xIn Tp = 0.11 s I>> = ∞

Bus-C Ip = 0.10 – 4.00 xIn I>> I>, t 7SJ600 Tp = 0.05 – 3.2 s I>> = 0.1 – 25. xIn

100/5 A

5 2

6

Ip = 1.0 xIn Tp = 0.17 s I>> = ∞

2

5

4

Setting

Ip = 0.7 xIn Tp = 0.05 s I>> = ∞

52

.01 5

13.8/0.4 KV

fuse

2

TR

1.0 MVA 5.0%

fuse

VDE 160

.001

7

10 I [A]

2

5

1000 2

100

2

5 10 4 13.80 kV 0.40 kV 5 10 5 2

5 1000 2

5 10 4 2

HRC fuse 160 A

8 Fig. 119: O/c time grading diagram

The normal way

9

10

To prove the selectivity over the whole range of possible short-circuit currents, it is normal practice to draw the set operating curves in a common diagram with double log scales. These diagrams can be manually calculated and drawn point by point or constructed by using templates. Today computer programs are also available for this purpose. Fig. 119 shows the relay coordination diagram for the example selected, as calculated by the Siemens program CUSS (computer-aided protective grading).

6/66

Note: To simplify calculations, only inverse-time characteristics have been used for this example. About 0.1 s shorter operating times could have been reached for high-current faults by additionally applying the instantaneous zones I>> of the 7SJ60 relays.



Coordination of o/c relays with fuses and low-voltage trip devices The procedure is similar to the above described grading of o/c relays. Usually a time interval between 0.1 and 0.2 seconds is sufficient for a safe time coordination. Very and extremely inverse characteristics are often more suitable than normal inverse curves in this case. Fig. 120 shows typical examples. Simple consumer-utility interrupts use a power fuse on the primary side of the supply transformers (Fig. 120a). In this case, the operating characteristic of the o/c relay at the infeed has to be coordinated with the fuse curve. Very inverse characteristics may be used with expulsion-type fuses (fuse cutouts) while extremly inverse versions adapt better to current limiting fuses. In any case, the final decision should be made by plotting the curves in the log-log coordination diagram. Electronic trip devices of LV breakers have long-delay, short-delay and instantaneous zones. Numerical o/c relays with one inverse time and two definite-time zones can be closely adapted (Fig. 120b).

1 Time

MV Inverse relay

51

Other consumers

2

Fuse

3

n a

LV bus

0.2 seconds

Fuse

4

a) Maximum fault available at HV bus

Current

Time

5

MV bus 50 51

o/c relay I1>, t1

6

Secondary breaker

I2>, t2

n a 0.2 seconds

7

LV bus

I>> b) Maximum fault level at MV bus

8

Current

Fig. 120: Coordination of an o/c relay with an MV fuse and a low-voltage breaker trip device

9

10


6/67


Grading of zone times

1

Operating time Z3A

t3 Z2A

t2

2

Z1A

t1

~ 3

Z1B ZLA-B

A

Z2B Z1C ZLB-C

B Load

Z1A = 0.85 • ZLA-B

ZLC-D

C

D

Load

Load

The first zone normally operates undelayed. For the grading of the time intervals of the second and third zones, the same rules as for o/c relays apply (see Fig. 116). For the quadrilateral characteristics (relays 7SA511 and 7SA513) only the reactance values (X values) have to be considered for the reach setting. The setting of the R values should cover the line resistance and possible arc or fault resistances. The arc resistance can be roughly estimated as follows:

Z2A = 0.85 • (ZLA-B+Z1B) Z3A = 0.85 • (ZLA-B+Z2B)

4

RArc

Fig. 121: Grading of distance zones

IArc = Iscc Min =

X X3A

IArc x 2kV/m Iscc

Min

arc length in m minimum short-circuit current

Fig. 123

D

5

■ Typical settings of the ratio R/X are:

C

– Short lines and cables (≤ 10 km): R/X = 2 to 10 – Medium line lengths < 25 km: R/X = 2 – Longer lines 25 to 50 km: R/X = 1

X2A

B

6

=

X1A

Shortest feeder protectable by distance relays

7

The shortest feeder that can be protected by underreach distance zones without the need for signaling links depends on the shortest settable relay reactance.

A

R1A

R2A

R3A

R

8

XPrimary Minimum = = XRelay Min x

9

[Ohm]

CTratio

Fig. 122: Operating characteristic of Siemens distance relays 7SA511 and 7SA513

Coordination of distance relays

10

VTratio

The reach setting of distance times must take into account the limited relay accuracy including transient overreach (5% according to IEC 60255-6), the CT error (1% for class 5P and 3% for class 10P) and a security margin of about 5%. Further, the line parameters are normally only calculated, not measured. This is a further source of errors. A setting of 80–85% is therefore common practice; 80% is used for mechanical relays while 85% can be used for the more accurate numerical relays.

6/68

Where measured line or cable impedances are available, the reach setting may also be extended to 90%. The second and third zones have to keep a safety margin of about 15 to 20% to the corresponding zones of the following lines. The shortest following line has always to be considered (Fig. 121). As a general rule, the second zone should at least reach 20% over the next station to ensure back-up for busbar faults, and the third zone should cover the largest following line as back-up for the line protection.

Imin =

XPrim.Min [Ohm] X’Line [Ohm/km]

[km]

Fig. 124

The shortest setting of the numerical Siemens relays is 0.05 ohms for 1 A relays, corresponding to 0.01 ohms for 5 A relays. This allows distance protection of distribution cables down to the range of some 500 meters.



Breaker failure protection setting Most digital relays of this guide provide the BF protection as an integral function. The initiation of the BF protection by the internal protection functions then takes place via software logic. However, the BF protection function may also be initiated from outside via binary inputs by an alternate protection. In this case the operating time of intermediate relays (BFI time) may have to be considered. Finally, the tripping of the infeeding breakers needs auxiliary relays which add a small time delay (BFT) to the overall fault clearing time. This is in particular the case with 1-and1/2-breaker or ring bus arrangements where a separate breaker failure relay (7SV600 or 7SV512) is used per breaker (see application example 10). The deciding criterion of BF protection time coordination is the reset time of the current detector (50BF) which must not be exceeded under any condition of current interruption. The reset times specified in the Siemens digital relay manuals are valid for the worst-case condition: interruption of a fully offset short-circuit current and low current pick-up setting (0.1 to 0.2 times rated CT current). The reset time is 1 cycle for EHV relays (7SA513, 7SV512) and 1.5 to 2 cycles for distribution type relays (7SJ***). Fig. 126 shows the time chart for a typical breaker failure protection scheme. The stated times in parentheses apply for transmission system protection and the times in square brackets for distribution system protection.

1

62 BF

2

50 BF Breaker failure protection, logic circuit P1 : primary protection

A N D

P1 O R

3

P2

P2 : alternate protection

4

Fig. 125

Fault incidence Normal interrupting time

Protect.

Breaker inter.

time (1~) [2~]

time (2~) [4~]

0,5~ BFI

Current detector (50 BF) reset time

Margin (2,5~) [2,5~]

(1~) [2~] (5~) [8~]

BF timer (F) (62BF) Total breaker failure interrupting time

BFI = breaker failure initiation time (intermediate relays, if any) BFT = breaker failure tripping time (auxilary relays, if any)

0,5~ BFT

5

6

(2~) [4~]

7

Adjacent breaker int. time

8

(9~) [15~] Fig. 126

9

10


6/69


1

High-impedance differential protection: Verification of design The following design data must be established:

2

CT data

3

The CTs must all have the same ratio and should be of low leakage flux design according to Class TPS of IEC 44-6 (Class X of BS 3938). The excitation characteristic and the secondary winding resistance are to be provided by the manufacturer. The knee-point voltage of the CT is required to be designed at least for two times the relay pick-up voltage to assure dependable operation with internal faults.

4 1

2

5

3

n

RCT

RCT

RCT

RCT

RL

RL

RL

RL

Sensitivity For the relay to operate in case of an internal fault, the primary current must reach a minimum value to supply the set relay pickup current (IR-set), the varistor leakage current (Ivar) and the magnetizing currents of all parallel-connected CTs (n·ImR). Low relay voltage setting and CTs with low magnetizing demand therefore increase the protection sensitivity.

VRmax = 2 2VKN (VF –VKN) > 2kV with VF =

IFmax Through (RCT + 2·RL + RR) N

RR

Calculation example:

87B

7 Fig. 127

Sensitivity: IFmin = N·(IRset + Ivar + n·ImR)

Stability: RR ·I RL + RCT Rset CT ratio Set relay pickup current Varistor spill current CT magnetizing current at relay pickup voltage

IFThrough max < N·

10

This check is made by assuming an external fault with maximum through-fault current and full saturation of the CT in the faulted feeder. The saturated CT ist then only effective with its secondary winding resistance RCT, and the appearing relay voltage VR corresponds to the voltage drop of the infeeding currents (through-fault current) at RCT and RL. The current at the relay must under this condition safely stay below the relay pickup value. In practice, the wiring resistances RL may not be equal. In this case, the worst condition with the highest relay voltage (corresponding to the highest relay current) must be sought by considering all possible external feeder faults.

Fig. 129

Varistor

9

Stability with external faults

The differential relay must be a highimpedance relay designed as sensitive current relay (7VH80/83: 20 mA) with series resistor. If the series resistor is integrated in the relay, the setting values may be directly calibrated in volts, as with the relays 7VH80/83 (6 to 60 V or 24 to 240 V).

Voltage limitation by a varistor is required if:

6

8

Differential relay

N IRset IVar ImR

= = = =

VKN

VKN =CT knee point voltage VR =RR·IRset VKN ≥ 2·VR

VR ImR

6/70

Sensitivity: IFmin = N·(IRset + Ivar + n·ImR) IFmin = 600 ·(0.02 + 0.05 + 8·0.03) 1 IFmin = 186 A (31% IN)

V

Fig. 128

Given: n = 8 feeders N = 600/1 A VKN = 500 V RCT = 4 Ohm ImR = 30 mA (at relay setpoint) RL = 3 Ohm (max.) IRset = 20 mA RR = 10 kOhm IVar = 50 mA (at relay setpoint)

Im

Setting The setting is always a trade-off between sensitivity and stability. A higher voltage setting leads to enhanced through-fault stability, but, also to higher CT magnetizing and varistor leakage currents resulting consequently in a higher primary pickup current. A higher voltage setting also requires a higher knee-point voltage of the CTs and therefore greater size of the CTs. A sensitivity of 10 to 20% IN is normal for motor and transformer differential protection, or for restricted ground-fault protection. With busbar protection a pickup value ≥ 50 % IN is normally applied. An increased pickup value can be achieved by connecting a resistor in parallel to the relay. Varistor Voltage limitation by a varistor is needed if peak voltages near or above the insulation voltage (2 kV) are to be expected. A limitation to 1500 V rms is then recommended. This can be checked for the maximum internal fault current by applying the formula shown for VR-max. A restricted ground-fault protection may normally not require a varistor, but, a busbar protection in general does. The electrical varistor characteristic can be expressed as V=K·IB. K and B are the varistor constants.

Stability: RR ·I RL + RCT Rset IFmax Through < 600 · 10,000 ·0.02 1 3+4 IFmaxThrough < N·

IFmax Through < 17 kA (28·IN) Fig. 130

Relay setting V rms

K

B

Varistor type

≤125 125–240

450 900

0.25 0.25

600A/S1/S256 600A/S1/S1088

Fig. 131


Local and Remote Control Introduction

State-of-the-art Modern protection and substation control uses microprocessor technology and serial communication to upgrade substation operation, to enhance reliability and to reduce overall life cycle cost. The traditional conglomeration of often totally different devices such as relays, meters, switchboards and RTUs is replaced by a few multifunctional, intelligent devices of uniform design. And, instead of extensive parallel wiring (centralized solution, Fig. 132), only a few serial links are used (decentralized solution, Fig. 133). Control of the substation takes place with menu-guided procedures at a central VDU workplace.

1

Traditional protection and substation control

2

To network control center

3 Alarm annunciation and local control

Remote terminal unit

4

5

Marshalling rack

6

Approx. 20 to 40 cores per bay

7

8 F

F

9

Control

Monitoring

Protection

Mimic display Pushbuttons Position indicators Interposing relays Local/remote switch

Indication lamps Measuring instruments Transducers Terminal blocks Miniature circuit breakers

e.g. Overcurrent relays Ground-fault relays Reclosing relays Auxiliary relays

10

Fig. 132: Central structure of traditional protection and control


6/71


1

Coordinated protection and substation control system

2 Control center

3 Compact central control unit including RTU functions

PC

*

4

5 Printer

6 Profibus

Substation LAN

7

**

8

9 Control I/O unit

Protection relay

Shown with open door

10

Combined protection and control relay Low-voltage compartment of the medium-voltage switchgear

* The compact central control unit can be located in a separate cubicle or directly in the low-voltage compartment of the switchgear

Fig. 133: Decentralized structure of modern protection and control

6/72



Substation control and protection system For numerical substation control and protection system applications, two different systems are available: ■ SINAUT LSA ■ SICAM By virtue of their different functions and specific advantages, the two systems cover different applications. This means that it is possible to configure an optimum system for every application. SINAUT LSA is typically used primarily for medium-voltage and high-voltage applications in power supply utilities. The principal use for SICAM products is currently in medium-voltage applications for power suppliers and industry. Other features in which they differ are summarized in Fig. 134.

The SICAM family offers of the following options: ■ SICAM SAS, the substation automation system with the following features: – Principal function: substation automation – Decentralized and centralized process connection – Local control and monitoring with archive function – Communication with the System Control Center ■ SICAM RTU, the telecontrol system with central process connection and the following features: – Principal function: information communication

SINAUT LSA Central and decentral connection

SICAM Substation Automation System Units of the SICAM family have been in service since 1996. The SICAM system is based on SIMATIC*) and PC standard modules. SICAM possesses an open communication system with standardized interfaces. Thus, SICAM is a flexible system capable of uncomplicated further development. *)Siemens PLCs and Industrial Automation Systems. For detailed information see: Catalog ST 70, Siemens Components for Totally Integrated Automation.

Telecontrol data concentrator (connection of telecontrol remote stations)

RTU

PCC ++

6 +

+

+++

+++

+++

+++

Supplementing of project-specific telecontrol protocols

+

++

++

+++

Supply of existing telecontrol protocols

+++

+

+

+

IED link using IEC 870-5-103

+++

+++

++

+++

+++

7

8

IED link using DNP3.0

++(1)

++(1)

+++

+++

+++

+++

+++

+

Linkage of PROFIBUS DP-IEDs

+++

++

++

Addition of project-specific IED protocols

+

+

+++

++

+++

+++

+++

9

Expansion of existing SICAM substations

Uncomplicated, low-cost design (1)

+

10

+

Linkage as telecontrol remote station IED – Intelligent Electronic Device

+++ Ideally suitable ++ Very suitable + Suitable

Fig. 134: Table shows the principal application aspects of the SICAM and SINAUT LSA system families.


3

5 SAS

Telecontrol communication using standard protocols IEC 870-5-101, DNP3.0, SINAUT 8FW

Incorporation in SIMATIC automation solutions

2

SICAM

+++

Telecontrol communication via WAN with TCP/IP

Expansion of existing SINAUT LSA substations

1

4

Principal application aspects of SINAUT LSA and SICAM

SINAUT LSA substation control system Since 1986, SINAUT LSA systems have proved themselves in practice in over 1500 substations. The SINAUT LSA substation automation system was the first digital system to have integrated all the following functions in a single equipment family: ■ Telecontrol ■ Local Control ■ Monitoring ■ Automation and ■ Protection SINAUT LSA has significantly extended the scope of performance and functionality of conventional secondary equipment. It is design and operation-friendly to a very considerable extent. SINAUT LSA is a system matched to requirements – from the hardware to the PC tools – and is tailored in optimum form to the function of numerical substation control and protection systems. Fig. 134 shows the principal application aspects of the SINAUT LSA substation control and protection system in comparison with the SICAM systems.

– Central process connection – PLC functions – Communication with Control Center ■ SICAM PCC, the PC-based Substation Control System with the following features: – Principal function: local substation supervision and control – Decentralized process connection – LAN/WAN communication with IEC 60870-6 TASE.2 – Flexible communication – Linkage to Office® products.

6/73

Local and Remote Control SINAUT LSA – Overview

Technical proceedings

1

2

3

4

5

6

7

8

9

10

The first coordinated protection and substation control system SINAUT LSA was commissioned in 1986 and continuously further developed over subsequent years. It now features the following main characteristics: ■ Coordinated system structure ■ Optical communication network (star configuration) ■ High processing power (32-bit µP technology) ■ Standardized serial interfaces and communication protocols ■ Uniform design of all components ■ Complete range of protection and control functions ■ Comprehensive user-software support packages. Currently (1999) over 1500 systems are in successful operation on all voltage levels up to 400 kV.

System Control Center

Operator’s desk

Engineering Analysis

LSA PROCESS Modem

VDU Station level

Time signal

Event Logger

Modem

”Master Unit“ (i. e. 6MB55) 1…

Bay level

…n

Bay Control Unit 6 MB 524 including interlocking

Bay Protection 7S

System structure and scope of functions The SINAUT LSA system performs supervisory local control, switchgear interlocking, bay and station protection, synchronizing, transformer tap-changer control, switching sequence programs, event and fault recording, telecontrol, etc. It consists of the independent subsystems (Fig. 135): ■ Supervisory control 6MB5** ■ Protection 7S*** Normally, switchgear interlocking is integrated as a software program in the supervisory control system. Local bay control is implemented in the bay-dedicated I/O control units 6MB524. For complex substations with multiple busbars, however, the interlocking function can also be provided as an independent backup system (System 8TK). Communication and data exchange between components is performed via serial data links. Optical-fiber connections are preferred to ensure EMI compatibility. The communication structure of the control system is designed as a hierarchical star configuration. It operates in the polling procedure with a fixed assignment of the master function to the central unit. The data transmission mode is asynchronous, half-duplex, protected with a hamming distance d = 4, and complies with the IEC Standard 60 870-5. Each subsystem can operate fully in standalone mode even in the event of loss of communication.

6/74

Switchyard Serial

Parallel

Fig. 135: Distributed structure of coordinated protection and control system SINAUT LSA

Data sharing between protection and control via the so-called informative interface according to IEC 60 870-5-103 is restricted to noncritical measuring or event recording functions. The protection units, for example, deliver r.m.s. values of currents, voltages, power, instantaneous values for oscillographic fault recording and time-tagged operating events for fault reporting. Besides the high data transmission security, the system also provides self-monitoring of individual components. The distributed structure also makes the SINAUT LSA system attractive for refurbishment programs or extensions, where conventional secondary equipment has to be integrated. It is general practice to provide protection of HV and EHV substations as separate, self-contained relays that can communicate with the control system, but function otherwise completely independently. At lower voltage levels, however, higher integrated solutions are accepted for cost reasons. For distribution-type substations combined protection and control feeder units (e.g. 7SJ63) are available which integrate all necessary functions of one feeder, includ-

ing: local feeder control, overcurrent and overload protection, breaker-failure protection and metering. Supervisory control The substation is monitored and controlled from the operator‘s desk (Fig. 136). The VDU shows overview diagrams and complete details of the switchgear including measurands on a color display. All event and alarm annunciations are selectable in the form of lists. The control procedure is menu-guided and uses mouse and keyboard. The operation is therefore extremely userfriendly. Automatic functions Apart from the switchgear interlocking provided, a series of automatic functions ensure effective and secure system operation. Automatic switching sequences, such as changing of busbars, can be user-programmed and started locally or remotely. Furthermore, the synchronizing function has been integrated into the system software and is available as an option.



The synchronizing function runs on the relevant 6MB524 bay control units. The performance of these functions corresponds to modern digital stand-alone units. The advantages of the integrated solution, however, are: ■ External auxiliary relay circuits for the selection of measurands are no longer applicable. ■ Adaptive parameter setting becomes possible from local or remote control levels. High processing power The processing power of the central control unit has been enormously increased by the introduction of the 32-bit µP technology. This permits, on the one hand, a more compact design and provides, on the other hand, sufficient processing reserve for the future introduction of additional functions.

1

2

3

4 Fig. 136: Digital substation control, operator desk. Control of a 400 kV substation (double control unit)

Static memories A decisive step in the direction of user friendliness has been made with the implementation of large nonvolatile Flash EPROM memories. The system parameters can be loaded via a serial port at the front panel of the central unit. Bay level parameters are automatically downloaded.

5

6

Analog value processing The further processing of raw measured data, such as the calculation of maximum, minimum or effective values, with assigned real time, is contained as standard function. A Flash EPROM mass storage can optionally be provided to record measured values, fault events or fault oscillograms.The stored information can be read out locally or remotely by a telephone modem connection. Further data evaluation (harmonic analysis, etc.) is then possible by means of a special PC program (LSA PROCESS). Compact design A real reduction in space and cost has been achieved by the creation of compact I/O and central units. The processing hardware is enclosed in metallic cases with EMI-proof terminals and optical serial interfaces. All units are type tested according to the latest IEC standards. In this way, the complete control and protection equipment can be directly integrated into the MV or HV switchgear (Fig. 137, 138).

7

8

Fig. 137: Switchgear-integrated control and protection

Fig. 138: View of a low-voltage compartment

Switchgear interlocking and local control

The interlocking function ensures fail-safe switching and personal safety down to the lowest control level, i.e. directly at the switchpanel, even when supervisory control is not available. The bay control unit 6MB524 uses codewords to protect the switchgear from unauthorized operation. With these codewords, the authorization for local switching and unlocked local switching can be reached. The bay-to-bay interlocking conditions are checked in the SINAUT LSA central unit. Each 6MB524 bay control unit has an optical fiber link to this central unit.

With the introduction of the bay control unit 6MB524, the switchgear interlocking and the local control function have been integrated completely into the SINAUT LSA station control system. That means that there is no technical need for an additional switchgear interlocking like the 8TK system, because the SINAUT LSA system has the same reliability according to the testing of interlocking conditions. However, the 8TK system is still available for the case that an interlocking system with seperate hardware and software is required.


9

6/75

10


Numerical protection

1

2

3

4

5

6

7

A complete range of fully digital (numerical) relays is available (see chapter Power System Protection 6/8 and following pages). They all have a uniform design compatible with the control units (Fig. 139). This applies to the hardware as well as to the software structure and the operating procedures. Metallic standard cases, IEC 60255tested, with EMI-secure terminals, ensure an uncomplicated application comparable to mechanical relays. The LCD display and setting keypad are integrated. Additionally a RS232 port is provided on the front panel for the connection of a PC as an HMI. The rear terminal block contains an opticalfiber interface for the data communication with the SINAUT LSA control system. The relays are normally linked directly to the relevant I/O control unit at the bay level. Connection to the central control system unit is, however, also possible. The numerical relays are multifunctional and contain, for example, all the necessary protection functions for a line feeder or transformer. At higher voltage levels, additional, main or back-up relays are applied. The new relay generation has extended memory capacity for fault recording (5 seconds, 1 ms resolution) and nonvolatile memory for important fault information. The serial link between protection and control uses standard protocols in accordance with IEC 60870-5-103. In this way, supplier compatibility and interchangeability of protection devices is achieved.

8

9

10

Fig. 139: Numerical protection, standard design

6/76

Management terminal

System control center Modem VF

Modem Remote control

Telephone network

Modem

VF

Substation level ERTU

Printer

Marshalling rack

Bay level

Operator terminal

Interposing relays, transducers

Existing switchyard

Extended switchyard

Fig. 140: Enhanced remote terminal unit 6MB55, application options

Enhanced remote terminal units

Communication with control centres

For substations with existing remote terminal units, an enhancement towards the decentralized SINAUT LSA performance level is feasible. The telecontrol system 6MB55 replaces outdated remote terminal units (Fig. 140). Conventional RTUs are connected to the switchgear via interposing relays and measuring transducers with a marshalling rack as a common interface. The centralized version SINAUT LSA can be directly connected to this interface. The totally parallel wiring can be left in its original state. In this manner, it is possible to enhance the RTU function and to include substation monitoring and control with the same performance level as the decentralized SINAUT LSA system. Upgrading of existing substations can thus be achieved with a minimum of cost and effort.

The SINAUT LSA system uses protocols that comply with IEC Standard 60 870-5. In many cases an adaption to existing proprietary protocols is necessary, when the system control center has been supplied by another manufacturer. For this purpose, an extensive protocol library has been developed (approx. 100 protocol variants). Further protocols can be provided on demand.



Engineering system LSATOOLS

Parameterizing

Documentation Engineering system

Parameter data

Documentation

Fig. 141: Engineering system LSATOOLS

LSATOOLS parameterization station

Network control center

Documentation

In parallel with the upgrading of the central unit hardware, a novel parameterizing and documentation system LSATOOLS has been developed. It uses modern graphical presentation management methods, including pull-down menus and multiwindowing. LSATOOLS enables the complete configuration, parameterization and documentation of the system to be carried out on a PC workstation. It ensures that a consistent database for the project is maintained from design to commissioning (Fig. 141). The system parameters, generated by LSATOOLS, can be serially loaded into the Flash EPROM memory of the central control unit and will then be automatically downloaded to the bay level devices (Fig. 142). Care has been taken to ensure that changes and expansions are possible without requiring a complete retest of the system. Because of the object-oriented structure of LSATOOLS, it is easily possible for the system engineer to add new bays with all necessary information.

Master unit

1

2

3

4

5

6

Loading of parameters

7

Downloading of parameters during startup

8

PC inputs

9 Input/output units

10 Fig. 142: PC-aided parameterization of SINAUT LSA with LSATOOLS and downloading of parameters


6/77

Local and Remote Control SINAUT LSA – Distributed Structure

1

2

3

4

5

6

7

8

9

In the SINAUT LSA substation control system the functions can be distributed between station and bay control levels. The input/output devices have the following tasks on the bay control level: ■ Signal acquisition ■ Acquisition of measured values and metering data ■ Monitoring the execution of control commands, e.g. for – Control of switchgear – Transformer tap changing – Setting of Peterson coils Data processing, such as – Limit monitoring of measured values, including initiation of responses to limit violations – Calculation of derived operational measured values (e.g. P, Q, cos ϕ ) and/or operational parameters (for example r.m.s. values, slave pointer) from the logged instantaneous values for current and voltage – Deciding how much information to transmit to the control master unit in each polling cycle – Generation of group signals and deriving of signals internally, e.g. from self-monitoring ■ Switchgear-related automation tasks – Switching sequences in response to switching commands or to process events – Synchronization ■ Local control and operation (only bay control unit 6MB524): – Display of actual bay status (single line diagram) – Local control of circuit-breaker and disconnectors – Display of measurement values and event recording ■ Transmission of data from numerical protection relays to the control master unit ■ Local display of status and measured values. Input/output devices

10

A complete range of devices is available to meet the particular demands concerning process signal capacity and functionality (see Fig. 149). All units are built up in modern 7XP20 housings and can be directly installed in the low-voltage compartments of the switchgear or in separate cubicles. The smallest device 6MB525 is designed as a low-cost version and contains only control functions. It is provided with an RS485-wired serial interface and is normally used for simple distribution-type sub-

6/78

Higher-level control system

Station control center

Central evaluation station (PC)

Telecontrol channel

Telephone channel

Normal time

Central control unit 6MB51 Station level 1

n

Busbar and breaker failure protection 7SS5

Bay level

Bay control unit 6MB524

Protection relays 7S/7U

Substation Serial interface

Parallel interface

Fig. 143: SINAUT LSA protection and substation control system system

stations together with overcurrent/overload relays 7SJ60 and digital measuring transducers 7KG60. (see application example, Fig. 165). All further bay control devices contain an optic serial interface for connection to the central control unit, and an RS232 serial interface on the front side for connection of an operating PC. Further, integral displays for measuring values and LEDs for status indication are provided. Minicompact device 6MB525 It contains signal inputs and command outputs for substation control. Analog measuring inputs, where needed, have to be provided by additional measuring transducers, type 7KG60. Alternatively, the measuring

functions of the numerical protection relays can be used. These can also provide local indication of measuring values. The local bay control is intended to be performed by the existing, switchgear-integrated mechanical control. Compact devices 6MB522/523 They provide a higher number of signal inputs and outputs, and contain additional measuring functions. One measuring value or other preprocessed information can be displayed on the 2-row, 16-character alphanumeric display. If local control is required, the bay control unit 6MB524 is the right choice.



Bay control unit 6MB524 This bay control device can be delivered in five versions, depending on the peripheral requirements. It provides all control and measuring functions needed for switchgear bays up to the EHV level. Switching status, measuring values and alarms are indicated on a large graphic display. Measuring instruments can therefore be widely dispensed with. Bay control is, in this case, performed by the integrated keypad. The synchronizing function is included in the software.

1

2

3

Combined protection and control device 7SJ531 This fully integrated device provides all protection, control and measuring functions for simple line/cable, motor or transformer feeders. Protection includes overcurrent, overload and ground-fault protection, as well as breaker-failure protection, autoreclosure and motor supervision functions (see page 6/27). Only one unit is needed per feeder. Space, assembly and wiring costs can therefore be considerably reduced. Measured value display and local bay control is performed in the same way as with the bay control unit 6MB524 with a large display and a keypad.

Fig. 144: Minicompact I/O device 6MB525

Fig. 145: Compact I/O device 6MD62

Fig. 146: Combined protection and control device 7SJ63

5

6

Combined protection and control devices 7SJ61, 7SJ62, 7SJ63 and bay control unit 6MD63 (SIPROTEC 4 series) These new SIPROTEC 4 devices have been available since December 1998. With a large graphical display and ergonomically designed keypad, they offer new possibilities for bay control and protection. Via the IEC 60870-5-103 interface, connection to the substation control system SINAUT LSA is handled. The protection devices include overcurrent, over/undervoltage and motor protection functions (see page 6/27). The smaller 7SJ61 and 7SJ62 devices are delivered with an alphanumerical display with 4 lines of text for displaying of measurement values, alarms, metering values and status of switching devices. The 7SJ63 and 6MD63 units include a large illuminated graphic display for a clearly visible single-line diagram of the switchgear, alarm lists, measured and metered values as well as status messages. With the integrated key switches, the user authorization is regulated. For complete description of the new SIPROTEC 4 devices, refer to the protection chapter (page 6/8).

4

7

Fig. 147: Compact I/O unit with local (bay) control 6MB5240-0


Fig. 148: Combined protection and control device 7SJ531

8

9

10

6/79


1

Design

Type

Commands Double Single

Signal inputs Double Single

Components

Analog inputs Direct connection to transformer

Connection to measure transducer

Minicompact1)

6MB525

2

–

6

–

–

–

Double commands and alarms configurable also as ”single“

Compact1)

6MB523 6MB522-0 6MB522-1 6MB522-2

1 3 6 6

– 1 2 2

3 3 6 6

5 5 10 10

1xI 2 x U, 1 x I 3 x U, 3 x I 4 x U, 2 x I

– 2 – 2

For simple switchgear cubicles with one switching device

4 6 8 20 12

1 1 2 5 3

8 12 16 40 24

– – – – –

2 x U, 1 x I 3 x U, 3 x I 3 x U, 3 x I 9 x U, 6 x I 6 x U, 3 x I

1 2 2 5 2

High-end bay control for HV and EHV Double commands and alarms also usable as ”single“

1

–

–

–

3 x U, 3 x I

2

3 Compact with local (bay) control and large display

6MB5240-0 -1 -2 -3 -4 7SJ531

5

Combined control and protection device with local (bay) control

6MD631 6MD632

4 5 + 43)

– 1

5 12

1 –

4 x I, 3 x U 4 x I, 3 x U

– –

6

Compact with local bay control (SIPROTEC 4 design with large graphic display) 2)

6MD633

5 + 43)

1

10

–

4 x I, 3 x U

2

6MD634

3 + 43)

–

10

–

–

–

6MD635

7 + 83)

–

18

1

4 x I, 3 x U

–

6MD636

7 + 83)

–

16

1

4 x I, 3 x U

2

6MD637

4 + 83)

1

16

1

–

–

7SJ610 7SJ612 7SJ621 7SJ622 7SJ631 7SJ632

– – – – 4 5 + 43)

4 6 8 7 – 1

– – – – 5 12

3 11 7 11 1 –

4xI 4xI 4 x I, 3 x U 4 x I, 3 x U 4 x I, 3 x U 4 x I, 3 x U

– – – – – –

7SJ633

5 + 43)

1

10

–

4 x I, 3 x U

2

7SJ635

7 + 83)

–

18

1

4 x I, 3 x U

–

7SJ636

7 + 83)

–

16

1

4 x I, 3 x U

2

4

7

8

9

Combined control and protection device with local bay control (SIPROTEC 4 design with large graphic display) 2)

10

with P, Q calculation

Double commands and alarms also usable as ”single“

Bay control units in new design, optimized for mediumvoltage switchgear with 11/2-pole control (max. 7 switching devices). 2-pole control also possible (max. 4 switching devices). Double commands and alarms also usable as ”single“

Combined control and protection devices. 7SJ61 and 7SJ62 with 4 line text display, 7SJ63 with graphic display. Optimized for 11/2-pole control (max. 7 switching devices). 2-pole switching is also possible (max. 4 switching devices). Double commands and alarms also usable as ”single“

1)

Local (bay) control has to be provided separately if desired. In distributiontype substations, mechanical local control of the switchgear may be sufficient. 2) Control of switching devices: 11/ -pole; 2-pole control possible 2 3) Second figure is number of heavy duty relays Fig. 149: Standardized input/output devices with serial interfaces

6/80



The 6MB51 control master unit This unit lies at the heart of the 6MB substation control system and, with its 32-bit 80486 processor, satisfies the most demanding requirements. It is a compact unit inside the standard housing used in Siemens substation secondary equipment. The 6MB51 control master unit manages the input/output devices, controls the interaction between the control centers in the substation and the higher control levels, processes information for the entire station and archives data in accordance with the parameterized requirements of the user. Specifically, the control master unit coordinates communication ■ to the higher network control levels ■ to the substation control center ■ to an analysis center located either in the station or connected remotely via a telephone line using a modem ■ to the input/output devices and/or the numerical protection units (bay control units) ■ to lower-level stations. This is for the purpose of controlling and monitoring activities at the substation and network control levels as well as providing data for use by engineers. Other tasks of the control master unit are ■ Event logging with a time resolution of 1 or 10 ms ■ Archiving of events, variations in measured values and fault records on massstorage units ■ Time synchronization using radio clock (GPS, DCF77 or Rugby) or using a signal from a higher-level control station ■ Automation tasks affecting more than one bay: – Parallel control of transformers – Synchronizing (measured value selection) – Switching sequences – Busbar voltage simulation – Switchgear interlocking ■ Parameter management to meet the relevant requirements specification ■ Self-monitoring and system monitoring.

System monitoring primarily involves evaluating the self-monitoring results of the devices and serial interfaces which are coordinated by the control master unit. In particular, in important EHV substations, some users require redundancy of the control master unit. In these cases, two control master units are connected to each other via a serial interface. System monitoring then consists of mutual error recognition and, if necessary, automatic transfer of control of the process to the redundant control master unit.

1

2

3 The SINAUT LSA station control center The standard equipment of the station control center includes ■ The PC with color monitor and LSAVIEW software package for displaying – Station overview – Detailed pictures – Event and alarm lists – Alarm information ■ A printer for the output reports The operator can access the required information or initiate the desired operation quickly and safely with just a few keystrokes.

Fig. 150: Compact control master unit 6MB513 for a maximum of 32 serial interfaces to bay control units. Extended version 6MB514 for 64 serial interfaces to bay control units (double width) additionally available

4

5

6

7

8

9

10

Fig. 151: SINAUT LSA PC station control center with function keyboard


6/81

Local and Remote Control SINAUT LSA – Local Control Functions

Local control functions 1 Tasks of local control

2

3

4

5

6

The Siemens SINAUT LSA station control system performs at first all tasks for conventional local control: ■ Local control of and checkback indications from the switching devices ■ Acquisition, display and registration of analog values ■ Acquisition, display and registration of alarms and fault indications in real time ■ Measurement data acquisition and processing ■ Fault recording ■ Transformer open-loop and closed-loop control ■ Synchronizing/paralleling Unlike the previous conventional technology with completely centralized processing of these tasks and complicated parallel wiring and marshalling of process data, the new microprocessor-controlled technology benefits from the distribution of tasks to the central control master unit and the distributed input/output units, and from the serial data exchange in telegrams between these units. Tasks of the input/output unit

7

8

9

10

The input/output unit performs the following bay-related tasks: ■ Fast distributed acquisition of process data such as indications, analog values and switching device positions and their preprocessing and buffering ■ Command output and monitoring ■ Assignment of the time for each event (time tag) ■ Isolation from the switchyard via heavyduty relay contacts ■ Run-time monitoring ■ Limit value supervision ■ Paralleling/synchronizing ■ Local control and monitoring Analog values can be input to the bay control unit both via analog value transducers and by direct connection to CTs and VTs. The required r.m.s. values for current and voltage are digitized and calculated as well as active and reactive power. The advantage is that separate measuring cores and analog value transducers for operational measurement are eliminated.

6/82

Control master unit

Switchyard overview diagram

The process data acquired in the input/output unit are scanned cyclically by the control master unit. The control master unit performs further information processing of all data called from the feeders for station tasks ”local control and telecontrol“ with the associated event logging and fault recording and therefore replaces the complicated conventional marshalling distributor racks. Marshalling is implemented under microprocessor control in the control master unit.

A switchyard single-line diagram can be configured to show an overview of the substation. This diagram is used to give the operator a quick overview of the entire switchyard status and shows, for example, which feeders are connected or disconnected. Current and other analog values can also be displayed. Information about raised or cleared operational and alarm indications is also displayed along the top edge of the screen. It is not possible to perform control actions from the switchyard overview. If the operator wants to switch a device, he has to select a detailed diagram, say ”110 kV detailed diagram“. If the appropriate function key is pressed, the 110 kV detailed diagram (Fig. 153) appears. This display shows the switching state of all switching devices of the feeders.

Serial protection interface All protection indications and fault recording data acquired for fault analysis in protection relays are called by the control master unit via the serial interface. These include instantaneous values for fault current and voltage of all phases and ground, sampled with a resolution of 1 ms, as well as distance-to-fault location. Serial data exchange The serial data exchange between the bay components and the control master unit has important economic advantages. This is especially true when one considers the preparation and forwarding of the information via serial data link to the control center communication module which is a component of the control master unit. This module is a single, system-compatible microprocessor module on which both the telecontrol tasks and telegram adaptation to telegram structures of existing remote transmission systems are implemented. This makes the station control independent of the telecontrol technology and the associated telegram structure used in the network control center at a higher level of the hierarchy. Station control center The peripheral devices for operating and visualization (station control center) are also connected to the control master unit. The following devices are part of the station control center: ■ A color VDU with a function keyboard or mouse for display, control, event and alarm indication, ■ A printer for on-line logging (event list), ■ Mass storage.

Function field control In the menu of the function fields, it is possible, for example, to select between control switching devices and tap changing. The control diagram shows details of station components and allows control and defining of display properties or functions (e.g. change in color/flashing). Furthermore, the popup diagram window can be opened from here, where switching operations with control elements are performed. The configured switching operation works as follows: ■ Selecting the switch: A click with the left mouse button on the switch symbol opens the popup window for command output ■ Output of the command. On clicking the operate button in the popup window the command is output The color of the switch symbol depends on the state. If the command is found to be safe after a check has been made for violations of interlock conditions, the switching device in question is operated. In the case where a mouse is available, the appropriate device is selected by the usual mouse operation. Once the switching command has been executed and a checkback signal has been received, the blinking symbol changes to the new actual state on the VDU. In this way, switching operations can be performed very simply and absolutely without error. If commands violate the interlock conditions or if the switch position is not adopted by a switching device, for example, because of a drive fault, the relevant fault indications or notes are displayed on the screen.



Event list All events are logged in chronological order. The event list can be displayed on the VDU whenever called or printed out on a printer or stored on a mass-storage medium. Fig. 153 shows a section of this event list as it appears on the VDU. The event list can also be incorporated in the detailed displays. The bay-related events can therefore also be shown in the detailed displays.

1

Example event list (Fig. 154)

3

The date can be seen in the left-hand area and the events are shown in order of priority. Switching commands and fault indications are displayed with a precision of up to 1 ms and events with high priority and protection indications after a fault-detection are shown with millisecond resolution. A command that is accepted by the control system is also displayed. This can be seen by the index ”+“ of the command (OP), otherwise ”OP–“ would appear. If the switchgear device itself does not execute the command, ”FB–“ (checkback negative) indicates this. ”FB+“ results after successful command execution. The texts chosen are suggestions and can be parameterized differently. The event list shows that a protection fault-detection (general start GS) has occurred with all the associated details. The real time is shown in the left-hand column and the relative time with millisecond precision in the right-hand column, permitting clear and fast fault analysis. The fault location, 17 km in this case, is also displayed. The lower section of the event list shows examples of raised (RAI) and cleared (CLE) alarm indications, such as ”voltage transformer miniature-circuit-breaker tripped“. This fault has been remedied as can be seen from the corresponding cleared indication. The letter S in the top line, called the indication bar, indicates that a fault indication has been received that is stored in a separate ”warning list“. Example alarm list (Fig. 155) When the alarm list is selected, it is displayed on the VDU. In this danger alarm concept a distinction is made between cleared and raised and between acknowledged and unacknowledged indications. Raised indications are shown in red, cleared indications are green (similar to the fast/slow blinking lamp principle). The letter Q is placed in front of an indication that has not yet been acknowledged. Indications that are raised and cleared and acknowledged are displayed in white in the list.

2

4

Fig. 152a: Compact I/O unit with local (bay) control, extended version 6MB5240-3

This system with representation in the alarm list therefore supersedes danger alarm equipment with two-frequency blinking lamps traditionally used with conventional equipment. As stated above, all events can also be continuously logged in chronological order on the associated printer, too. The appearance of this event list is identical to that on the VDU. The alarm list can also be incorporated in the detailed displays. The bayrelated alarms can therefore also be shown in the detailed displays. Mass storage It is also possible to store historic fault data, i.e. fault recording data and events on mass-storage medium. It can accept data from the control master units and stores it on Flash EPROMs. This static memory is completely maintenancefree when compared to floppy or hard disc systems. 8Mbyte of recorded data can be stored. The locally or remotely readable memory permits evaluation of the data using a PC. This personal computer can be set up separately from the control equipment, e.g. in an office. Communication then takes place via a telephone-modem connection. In addition to fault recording data, operational data, such as load-monitoring values (current, voltage, power, etc.) and events can be stored.

tion leads the user to the display of measurands, metering values, alarm lists and status messages. The keypad design with 6 colors supports the operator for quick and secure operation. User authorization is handled via password, for example unlocked switching. The new SIPROTEC4 devices also allow local bay control. At the 7SJ63 and 6MD63 devices, a large graphic display and an ergonomic keypad assist the operator in control of the switching devices and read out messages, measurements and metering values. In the 7SJ61 and 7SJ62 protection units, the user interface consists of a 4-line text display. These smaller units also make it possible to control the feeder circuitbreaker. All SIPROTEC4 devices are parameterized with the operating program DIGSI4.


6

7

8

9

10

Local bay control (Fig.152a, Fig. 152b) With the 6MB524 bay control units, local control and monitoring directly in the bay is possible. The large graphic display can show customer-specific single-line diagrams. A convenient menu-guided opera-

5

Fig. 152b: 6MD63 bay control unit

6/83


1

2

3

4 Fig. 153: SINAUT LSA substation control, example: overview picture

Fig. 154: SINAUT LSA substation control, example: event list

Fig. 155: SINAUT LSA substation control, example: alarm list

Fig. 156: 6MB substation control system, example: fault recording

5

6

7

8

9 Example fault recording (Fig. 156)

10

After a fault, the millisecond-precision values for the phase currents and voltages and the ground current and ground voltage are buffered in the feeder protection. These values are called from the numerical feeder protection by the control master unit and can be output as curves with the program LSAPROCESS (Fig. 156). The time marking 0 indicates the time of fault detection, i.e. the relay general start (GS). Approx. 5 ms before the general start, a three-phase fault to ground occurred, which can be seen by the rise in phase currents and the ground current.

6/84

12 ms after the general start, the circuit breaker was tripped (OFF) and after further 80 ms, the fault was cleared. After approx. 120 ms the protection reset. Voltage recovery after disconnection was recorded up to 600 ms after the general start. This format permits quick and clear analysis of a fault. The correct operation of the protection and the circuit breaker can be seen in the fault recording (Fig. 156). The high-voltage feeder protection presently includes a time range of at least 5 seconds for the fault recording.

The important point is that this fault recording is possible in all feeders that are equipped with the microprocessor-controlled protection having a serial interface according to IEC 60870-5-103.


Local and Remote Control SINAUT LSA – Application Examples

Application examples The flexible use of the components of the Coordinated Protection and Substation Control System SINAUT LSA is demonstrated in the following for some typical application examples.

1 Bay

1

2

n

Bus coupler

2

Application in high-voltage substations with relay kiosks Fig. 157 shows the arrangement of the local components. Each two bays (line or transformer) are assigned to one kiosk. Each bay has at least one input/output unit for control (bay control unit) and one protection unit. In extra-high voltage, the protection is normally doubled (main and backup protection). Local control is performed at the bay units (6MB524) using the integrated graphic display and keypad. Switchgear interlocking is included in the bay control units and in the central control unit. The protection relays are serially connected to the bay control unit by optical-fiber links.

3

4 FPR BCU

FPR BCU

FPR BCU

FPR BCU

Relay kiosks

Control building

5 To the network control center

CCU with CCC and MS

Modem To the operations and maintenance office

Parallel Serial

6

7

VDU

8 Key: CCU Central control unit CCC Control center coupling MS Mass storage

VDU FPR BCU

Visual display unit Feeder protection relays Bay control unit

9

Fig. 157: Application example of outdoor HV or EHV substations with relay kiosks

10


6/85


1

2

In extremely important substations, mainly extra-high voltage, there exists a doubling philosophy. In these substations, the feeder protection, the DC supply, the operating coils and the telecontrol interface are doubled. In such cases, the station control system with its serial connections, and the master unit with the control center coupling can also be doubled. Both master units are brought up-to-date in signal direction. The operation management can be switched over between the two master units (Fig. 158).

Network control center Printer

Printer Control/ annunciation

Control/ annunciation

3

4

Control center coupling

Control system master unit 1 with mass storage 1

5

Local control level

Switchover and monitoring*

••••••••••••

Control center coupling

Control system master unit 2 with mass storage 2

••••••••••••

Bay control level

6 ••••••••••

Protection relay

Bay Control unit

••••••••••••

Bay Control unit

Protection relay

7

8 Feeder 1

9

Switchgear

Feeder n

Parallel

*only principle shown

Serial

Fig. 158: System concept with double central control

10

6/86



Application in indoor high-voltage substations

Control room

The following example (Fig. 159) shows an indoor high-voltage substation. All decentralized control system components, such as bay control unit and feeder protection are also grouped per bay and installed close to the switchgear. They are connected to the central control unit in the same way as described in the outdoor version via fiber-optic cables.

VDU To the office

Switchgear room Switchgear bay 1 bay 2 …

Bus coupler

Modem

Application in medium-voltage substations The same basic arrangement is also applicable to medium-voltage (distribution-type) substations (Fig. 160 and 161). The feeder protection and the compact input/output units are, however, preferably installed in the low-voltage compartment of the feeders (Fig. 160) to save costs. There is now a trend to apply combined control and protection units. The relay 7SJ63, for example, provides protection and measurement, and has integrated graphic display and keypad for bay control. Thus, only one device is needed per cable, motor or O H line feeder.

1

2

BCU

BCU

FPR

FPR

BCU

BCU

Control and protection cubicles

BCU FPR BCU CCU

3

To the network control center

4 Parallel

Serial

Key: CCU Central control unit with control center coupling and mass storage

FPR BCU

5 Feeder protection relays Bay control unit

VDU Monitor

6

Fig. 159: Typical example of indoor substations with switchgear interlocking system

Protection and substation control SINAUT LSA with input/output units and numerical protection installed in low-voltage compartments of the switchgear

7 VDU with keyboard

Printer

Network control center

Operation place

8

1

2

3

4

5

Central control unit with opticalfiber link

1

Feeder protection unit (e.g. 7UT51 transformer protection)

2

Feeder I/O contol unit (e.g. 6MB524)

3

Combined control and protection feeder unit 7SJ53

4 5

Miniature I/O unit 6MB525

9

10

Feeder protection (e.g. 7SD5 line differential protection)

Fig. 160: Protection and substation control system SINAUT LSA for a distribution-type substation


6/87


1

2

3

4

Fig. 162 shows an example for the most simple wiring of the feeder units. The voltages between the bay control unit and the protection can be paralleled at the bay control unit because the plug-in modules have a double connection facility. The current is connected in series between the devices. The current input at the bay control unit is dimensioned for 100xIN, 1 s (protection dimensioning). The plug-in modules have a short-circuiting facility to avoid opening of CT circuits. The accuracy of the operational measurements depends on the protection characteristics. Normally, it is approx. 2% of IN. If more exact values are required, a separate measuring core must be provided. The serial interface of the protection is connected to the bay control unit. The protection data is transferred to the control central unit via the connection between the bay control unit and the central unit. Thus, only one serial connection to the central unit is required per feeder.

Control room

Switchgear room

VDU To the office

Bus coupler

Switchgear

Modem

BCUFPR BCU FPR

Parallel

CCU

BCUFPR

To the network control center

Serial

Key:

5

CCU Central control unit

FPR Feeder protection

with mass storage and control center coupling VDU Monitor

relay BCU Bay Control Unit

For o/c feeder or motor protection also available as one combined unit (e.g. 7SJ63)

6 Fig. 161: Application example of medium-voltage switchgear

7 Plug-in module

Bay Control Unit 1) 6MB52

Numerical 1) Protection

Switching status

8 CB ON/OFF 2)

9

Protection core

10

I

close or open

2)

close or trip

2)

Short-circuiting facility

U

1)

2)

For o/c feeder protection or motor protection also available as combined control and protection unit 7SJ63 Only one circuit shown

Serial data connection

Fig. 162: Principle wiring diagram of the medium-voltage feeder components

6/88



System configuration The system arrangement depends on the type of substation, the number of feeders and the required control and protection functions. The basic equipment can be chosen according to the following criteria: Central control master unit has to be chosen according to the number of bay control units to be serially connected: ■ 6MB513 for a maximum of 32 serial interfaces ■ 6MB514 for a maximum of 64 serial interfaces At the most 9 more serial interfaces are available for connection of data channels to load dispatch centers, local substation control PCs, printers, etc. Substation control center It normally consists of a PC with keyboard and a mouse, color monitor, LSAVIEW software and a printer for the output of reports. For exact time synchronization of 1 millisecond accuracy, a GPS or DCF77 receiver with antenna may be used. Bay control units Normally, a separate bay control unit is assigned to every substation bay. The type has to be selected according to the following requirements: ■ Number of command outputs: that means the sum of circuit breakers, isolators and other equipment to be centrally or remotely controlled. The stated double commands are normally provided for double-pole (”+“ and ”–“) control of trip or closing coils. Each double-pole command can be separated into two single-pole commands where stated (Fig. 149, page 6/80). ■ Number of digital signal inputs: as the sum of alarms, breaker and isolator positions, tap changer positions, binary coded meter values, etc, to be acquired, processed or monitored. Position monitoring requires double signal inputs while single inputs are sufficient for normal alarms. ■ Number of analog inputs: depends on the number of voltages, currents and other analog values (e.g. temperatures) to be monitored. Currents (rated 1 A or 5 A ) or voltages (normally rated 100 to 110 V) can be directly connected to the bay control units. No transducers are required. Numerical protection relays also acquire and process currents and voltages.

They can also be used for load monitoring and indication (accuracy about 2% of rated value). In this way, the number of analog inputs of the bay control units can be reduced. This is often practised in distribution-type substations. The device selection is discussed in the following example.

Incoming transformer bays

1

To the central control unit

OF OF OF

2

Example: Substation control configuration Fig. 163 shows the arrangement of a typical distribution-type substation with two incoming transformers, 10 outgoing feeders and a bus tie. The required inputs and outputs at bay level are listed in Fig. 164 for the incoming transformer feeders and in Fig. 165 for the outgoing line feeders, the bus tie and the VT bay. Each bay control unit is connected to the central control unit via fiber-optic cables (graded index fibers). The o/c relays 7SJ60, the minicompact I/O units 6MB5250 and the measuring transducers 7KG60 each have RS 485 communication interfaces and are connected to a bus of a twisted pair of wires. An RS485 converter to fiber-optic is therefore additionally provided to adapt the serial wire link to the fiber-optic inputs of the central unit. Recommendations for the selection of the protection relays are given in the section System Protection (6/8 and following pages). The selection of the combined control/protection units 7SJ531 or 7SJ63 is recommended when local control at bay level is to be provided by the bay control unit. The low-cost solution 7SJ60 + 6MB5250 should be selected where switchgear integrated mechanical local control is acceptable.

Typical distribution-type substation

115 kV

115 kV

13.8 kV

13.8 kV

6MB5240-2

M M

4 I

50/ 51

V

87T RTD's

5

63

M M

MV

6

Data acqusition 1 x DSI 1 x DSI 1 x DSI 1 x DSI 8 x DSI

Isolator HV side

1 x SSI 1 x SSI 3 x V, 3 x J, 8 xϑ

Circuit-breaker HV side Isolator MV side

7

Circuit-breaker MV side Transformer tap-changer positions Alarm Buchholz 1 Alarm Buchholz 2 Measuring values

8

Control 2 x DCO 2 x DCO 2 x DCO 2 x DCO 2 x SCO 1 x SCO

Isolator HV side Circuit-breaker HV side Isolator MV side Circuit-breaker MV side Tap changer, higher, lower Emergency trip Single signal input Double signal input Double command Single command

5 feeders

Fig. 163: Typical distribution-type substation


3

7UT512

HV

SSI DSI DCO SCO 5 feeders

7SJ61

Fig. 164: Typical I/O signal requirements for a transformer bay

6/89

9

10


1 To load dispatch center Central control unit

2 To transformer feeders

6MB513

GPS

OF OF

3

4

VDU

Printer (option)

Mass storage

OF

RS485/O F

RS485

5

6

7KG60

6MB 7SJ60 5250

6MB 7SJ60 5250

6MB 7SJ60 5250

7SJ531 or 7SJ63

7SJ531 or 7SJ63

51

7 M

M 51

M 51

M 51

51

8

9

Voltage transformer-bay

10 1 x 7KG60

Per feeder

Bus tie

Per feeder

1 x DSI

Isolator

1 x DSI

Isolator

1 x DSI

Grounding switch

1 x DSI

Grounding switch

1 x DSI

Circuit-breaker

1 x DSI

Circuit-breaker

1 x DSI

Circuit-breaker

5 x SSI

5 alarms

9 x SSI

9 alarms

5 x SSI

5 alarms

Load currents are taken from the protection relays

Measuring values (3 x V, 3 x I) from protection

2 x DCO Circuit-breaker

2 x DCO Circuit-breaker

Control

2 x DCO

Circuit-breaker

Fig. 165: Typical I/O signal requirements for feeders of a distribution-type substation

6/90


Local and Remote Control SINAUT LSA – Centralized (RTU) Structure

Enhanced remote terminal units 6MB551 The 6MB55 telecontrol system is based on the same hardware and software modules as the 6MB51 substation control system. The functions of the inupt/output devices have been taken away from the bays and relocated to the central unit at station control level. The result is the 6MB551 enhanced remote terminal unit (ERTU). Special plug-in modules for control and acquisition of process signals are used instead of the bay dedicated input/output devices: ■ Digital input (32 DI) ■ Analog input (32 AI grouped, 16 AI isolated) ■ Command output (32 CO) and ■ Command enabling These modules communicate with the central modules in the same frame via the internal standard LSA bus. The bus can be extended to further frames by parallel interfaces. The 6MB551 station control unit therefore has the basic structure of a remote terminal unit but offers all the functions of the 6MB51 substation control system such as:

System control center

Station control center (option)

1

Central evaluation station (PC)

Remote control channel

Telephone channel

2

Radio time (option) Enhanced terminal unit 6MB551

3 1 … … n Marshalling rack Transducers and interposing relays

Station protection 7SS5

4 (option)

(option)

5 Protection relay 7S/7U

Substation

Bay Control Unit 6MB52*

Extension to substation

6

Communication Serial interface

■ to the higher network control levels ■ to an analysis center located either in

the station or connected remotely via a telephone line using a modem ■ to the bay control unit and/or the numerical protection units (bay control units) ■ to lower-level stations (node function). This is for the purpose of controlling and monitoring activities at the substation and network control levels as well as providing data for system planning and analysis.

Parallel interface

7

Fig. 166: Protection and substation control system LSA 678 for a distribution-type substation

8

9

10


6/91

Local and Remote Control SINAUT LSA – Centralized (RTU) Structure

1

2

3

4

5

6

Fig. 167: 6MB551 enhanced remote terminal unit, installed in an 8MC standard cubicle with baseframe and expansion frame

7

8

Other tasks of the enhanced RTU are ■ Event logging with a time resolution of 1 or 10 ms ■ Archiving of events, variations in measured values and fault records on mass storage units ■ Time synchronization using radio clock (GPS, DCF77 or Rugby) or using a signal from a higher-level control station ■ Automation tasks affecting more than one bay: – Parallel control of transformers – Synchronizing (measured value selection) – Switching sequences – Busbar voltage simulation – Switchgear interlocking ■ Parameter management to meet the relevant requirements specification ■ Self-monitoring and system monitoring. ■ Up to 96 serial fiber-optic interfaces to distributed bay control units ■ Up to 5 expansion frames. Configuration including signal I/O modules can be parameterized as desired. Up to 121 signal I/O modules can be used (21 per frame minus one in the baseframe for each expansion frame, i.e. totally 6 x 21 – 5 = 121). The 6MB551 station control unit can therefore be expanded from having simple telecontrol data processing functions to assuming the complex functionality of a substation control system. The same applies to the process signal capacity. In one unit, more than 4 000 data points can be addressed and, by means of serial interfacing of subsystems, this figure can be increased even further. The 6MB551 station control unit simplifies the incorporation of extensions to the substation by using the decentralized 6MB52* bay control units for the additional substation bays.

These distributed input/output devices can then be connected via serial interface to the telecontrol equipment. Additional parameterization takes care of their actual integration in the operational hierarchy. The 6MB551 RTU system is also available as standard cubicle version SINAUT LSA COMPACT 6MB5540. The modules and the bus system have been kept; the rack design and the connection technology, however, have been cost-optimized (fixed rack only and plug connectors). This version is limited to a baseframe plus one extension frame with altogether 33 I/O modules, and a maximum of 5 serial interfaces for telecontrol connection without communication to bay control units or numerical protection units.

9

10

6/92


Local and Remote Control SINAUT LSA – Remote Terminal Units

Remote terminal units (RTUs) 1

The following range of intelligent RTUs are designed for high-performance data acquisition, data processing and remote control of substations. The compact versions 6MB552/553 of SINAUT LSA are intended for use in smaller substations.

2

3 Fig. 170: 6MB5530-0 minicompact RTU for small process signal capacity

4

5

6

Fig. 168: 6MB552 compact RTU for medium process signal capacity

Fig. 171: 6MB5530-1 remote terminal unit (RTC) with cable-shield communication

Fig. 169: SINAUT LSA COMPACT 6MB5540 remote terminal unit installed in a cubicle

Design

Type

Single Alarm commands inputs

Analog Serial ports inputs to control centers

7

Serial ports to bay units

8 Minicompact RTU*

6MB5530-0A 6MB5530-0B 6MB5530-0C

8 8 8

8 24 32

– 8 –

1

Remote terminal unit with cable shield communication (RTC)

6MB5530-1A 6MB5530-1C

8 8

8 32

– –

1 additional gateway

–

9

Compact RTU

6MB552-0A 6MB552-0B 6MB552-0C 6MB552-0D

321)/8 321)/8 321)/8 8

72 40 104 136

32 162) – –

1 Option 2

7

10

–

* Further 3 minicompact RTUs can be serially connected in cascade for extension (maximum distance 100 m) 1) With switching-current check 2) Potential-free Fig. 172: Remote terminal units, process signal volumes


6/93


1

Control center

Control center

1…

…n

2 Modem

Modem Telecontrol channel

3 Substation level RTU

4

Point to point con. 1)

M

Line connection

M

M

RTU

5

……

RTU

M RTU

1) 1) 1)

Modem

M Optical fiber

M M M Marshalling rack

RTU Bay level M RTU

6

M M RTU

7

Interposing relays, transducers Loop configuration Existing switchgear

2)

2)

2) Protection relays and I/O units

Extended switchgear 1) Telecontrol channel 2) Only with compact RTU 6MB552

M = Modem

Fig. 173: RTU interfaces

RTU interfaces The described RTUs are connected to the switchgear via interposing relays and measuring transducers (± 2.5 to ± 20 mA DC) (Fig. 173). Serial connection of numerical protection relays and control I/O units is possible with the compact RTU type 6MB552. The communication protocols for the serial connection to system control centers can be IEC standard 870-5-101 or the Siemens proprietary protocols 8FW. For the communication with protection relays, the IEC standard 870-5-103 is implemented. Besides these standard protocols, more than 100 legacy protocols including derivatives are implemented for remote control links up to system control centers and down to remote substations (see table overleaf).

8

9

10

Fig. 174: VF coupler with ferrite core 35 mm

6/94



List of implemented legacy protocols: ■ ADLP 180 ■ ANSI X3.28 ■ CETT 20 ■ CETT 50 ■ DNP3.0 ■ DUST 3964R (SINAUT 8-FW-data structure) ■ EFD 300 ■ EFD 400 ■ F4F ■ FW 535 ■ FW 537 ■ Geadat 90 ■ Geadat 81GT ■ GI74 ■ Granit ■ Harris 5000 ■ IDS ■ IEC 60870-5-101

■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■ ■

IEC 870-5-BAG IEC 870-5-VEAG Indactic 21 Indactic 23 Indactic 33 Indactic ZM20 LMU Modbus Netcon 8830 RP570 SAT 1703 SEAB 1F SINAUT 8-FW SINAUT HSL SINAUT ST1 Telegyr 709E Telegyr 809 Tracec 130 Ursatron 8000 Wisp+

Cable-shield communication The minicompact RTU can be delivered in a special version for communication via cable shield (Type 6MB5530-1). It does not need a separate signaling link. The coded voice frequency (9.4 and 9.9 kHz) is coupled to the cable shield with a special ferrite core (35 mm or 100 mm window diameter) as shown in Fig. 174. The special modem for cable-shield communication is integrated in the RTU. Fig. 175 shows as an example the structure of a remote control network for monitoring and control of a local supply network.

1

2

3

4

5 Higher telecontrol level Power cable (typically 5 km) … VF couplers

Modem (optional)

VF couplers Signal loop

6

VF couplers

Modem Channel 1 Channel 2


Mini RTU 6MB5530-1 (RTC)




Branch 1

1 2 3 4 5 6 7

VF couplers

7

8

Multiplexer (optional) Modem Channel 1 Channel 2

… Branch 2 …

8

16th station of branch 1

1st station of branch 1

Power cable (typically 5 km)

Communication control unit 6MB5530-1 (CCU)

9

… VF couplers Signal loop

VF couplers

VF couplers

VF couplers





Substation

Substation

1st station of branch 8

10

16th station of branch 8

Fig. 175: Remote control network based on remote terminal units with cable-shield communication


6/95

Local and Remote Control SICAM – Overview

1

2

3

4

5

6

7

8

SICAM is an equipment family consisting of products for digital power automation. The system is continuous, from the system control center, through the information technology, to the bay protection and control units. The SICAM System is based on SIMATIC*) and PC standard modules. SICAM is thus an open system with standardized interfaces, readily lending itself to further development. The SICAM family consists of the following individual systems (see Fig. 176): ■ SICAM RTU, the telecontrol system with the following features – Principal function: information transfer – Central process connection – PLC functions – Communication with control center ■ SICAM SAS, the decentralized automation system – Principal function: substation automation – Decentralized and centralized process connection – Local operation and monitoring with archiving functions – Communication with the control center ■ SICAM PCC, the PC-based Station Control System with the following features – Principal function: Substation supervision and control – Decentralized process connection – LAN/WAN communication with IEC 60870-6 TASE.2 – Flexible communication – Linkage to Office® products

SICAM RTU IEC 60 870-5-101 SINAUT 8-FW PROFIBUS Industrial Ethernet

PROFIBUS

...

Marshalling rack

...

SIMEAS Q or T Transducers Switchgear

Interposing relays, transducers

IEDs (Relays, etc.)

SICAM SAS System Control center IEC 60 870-5-101

SICAM WinCC

PROFIBUS IEC 60870-5-103

IEC 60 870-5-103 SIPROTEC 4 Protection and control devices

Process control unit

Other IEDs

SIPROTEC 3 Protection relays

SICAM PCC Other networks

WAN e.g. ICCP

9

Corporate information system System Control center

10

PROFIBUS IEC 60870-5-103

SIPROTEC 4 Protection and control devices *) Siemens PLCs and Industrial Automation Systems (see Catalog ST70)

6/96

Other IEDs

Protection relays

Fig. 176: The SICAM family


Local and Remote Control SICAM RTU – Design

SICAM: Open system structure

1

SICAM 2 Database

Data recording

Software

Communication

Communication

SICAM WinCC

3

SCADA

DIGSI

CPU

SICAM plusTOOLS

4 Central I/O

5

SIPROTEC

Bay control devices

Protective devices

6 Fig.177: SICAM system structure

7 System control center

SICAM RTU 6MD201 Enhanced Remote Terminal Unit Overview The SICAM RTU Remote Terminal Unit is based on the SIMATIC S7-400, a powerful PLC version of the Siemens product range for industrial automation. The SIMATIC S7400 has been supplemented by the addition of modules and functions so as to provide a flexible, efficient remote terminal unit. Based on worldwide used SIMATIC S7-400, it is possible to add project-specific automation functions to the existing telecontrol functions. The SIMATIC S7-400 System has been expanded to include the following properties: ■ All-round isolation of all connections with 2.5 kV electric strength ■ Heavy duty output contacts (10 A, 150 VDC, 240 AC) on external relay module (type LR with up to 16 command relays)

■ CT and VT graded measuring value ac-

quisition via serially connected numerical transducers SIMEAS Q or T (see page 6/132) ■ Acquisition of short-time event signals with 1 ms resolution and real-time stamping ■ Preprocessing of information acquired (e.g. double indications, metered values) ■ Fail-safe process control (e.g., 1-out-of-n check, switching current check) ■ Secure long-distance data transmission using the IEC 60870-5-101 or SINAUT 8-FW protocol ■ Remote diagnostic capability The open and uniform system structure is illustrated in Fig. 177, showing the essential modules. A variety of SICAM equipment family products are available depending on the different requirements and applications. The individual system modules are described in detail in the sections below.


8

9

Communication SICAM RTU

10

Central process connection Fig. 178: SICAM RTU remote terminal unit

6/97


System architecture

1

2

3

4

5

6

7

8

9

The SICAM RTU is a modular system. It is suitable for substation sizes from approximately 300 up to 2048 data points. The SICAM RTU consists of the: ■ SICAM S7-400 basic rack with its extension facilities and ■ Any S7-400 CPU (412 to 477, with/without PROFIBUS connection). As standard CPU, the CPU 412 or CPU 413 is used. To supplement the SIMATIC S7-400 modules, telecontrol-specific modules have been developed in order to fulfill the required properties and functions, such as for example electric insulation strength and time resolution. These are the following modules: ■ Power supply – Voltage range from 19 V–72 V DC – 88 V–288 V AC/DC ■ Process input and output modules – Digital input DI (32 inputs) for status indications, counting pulses, bit patterns and transformer tap settings • voltage ranges: 24–60 V DC 110–125 V DC – Analog input AI (32 analog inputs grouped, 16 AIR (analog inputs isolated) for currents (0.5 mA–24 mA) and voltages (0.5 V–10 V) – Command output (32 CO) for commands and digital setpoints • voltage range: 24 –125 V DC – Command release (8 DI, 8 DO) for local inputs and outputs and monitoring of command output circuits • voltage ranges: 24–60 V DC 110–125 V DC ■ Communication module – Telecontrol processor TP1 for communication with the system control center with protocols IEC 60870-5-101 and SINAUT 8-FW and as time signal receivers for DCF77 or GPS reception. The Power Supply and the I/O modules can also be used in SICAM SAS.

Fig. 179: SICAM mounting rack

10

6/98



Construction The SICAM RTU is based on the SIMATIC S7-400. The construction of the SICAM RTU is therefore, as is the case with SIMATIC, highly compact, straightforward and simple to operate: ■ All connections are accessible from the front. Therefore, no swivel frame is necessary. ■ The modules are enclosed and therefore extremely rugged. ■ Plugging and unplugging of modules is possible while in operation; therefore maintenance work can be carried out in a minimum of time (reduced MTTR). ■ Direct process connection is effected by means of self-coding front plug connectors of screw-in or crimp design. ■ During configuration, no module slot rules have to be observed; the SICAM RTU permits free module fitting. ■ No forms of setting are necessary on the modules; replacement can be carried out in a minimum of time. Dependent on configuration level and customer requirements, there are two housing variants: ■ a floor-mounting cabinet and ■ a wall-mounting cabinet. Both housing variants are optimized for the SICAM RTU; they are of flexible modular construction. Thus, for example, provision is made for installation of accessories to provide a cost-effective rack system.

1

2

3

4

5 Fig. 180a: SICAM RTU wall-mounting cabinet

6

7

8

9

10

Fig. 180b: SICAM RTU floor-mounting cabinet


6/99


SICAM Modules SICAM RTU modules have been developed to be SIMATIC-compatible and can therefore be used in a standard SIMATIC S7-400, for example for the following applications: ■ Acquisition of status indications with a resolution of 1 ms and an accuracy of ± 2 ms ■ Time synchronization of the SIMATIC CPU to within an accuracy of ± 2 ms ■ An analog input module with 32 channels with current or voltage inputs ■ Use of modules with 2.5 kV electric insulation strength in order to save interposing relays The modules are used for example in hydropower plants for acquisition of fault events via digital input with a resolution of 1 ms and relaying them to a power station system, for example via an Industrial Ethernet. The other application is the use of the communication module TP1 in a SIMATIC NET IEC 60870-5-101 gateway. Fig. 182 shows an example of a PROFIBUS gateway.

1

2

3

4

5

6

7

Fig. 181: SICAM module

SICAM RTU

8

IEC 60870-5-101 SINAUT 8-FW PROFIBUS Industrial Ethernet

9

Gateway Profibus

10 IEDs

Switchgear Fig. 182: Gateway: PROFIBUS – IEC 60870-5-101

6/100


Local and Remote Control SICAM RTU – Functions

SICAM RTU functions SICAM RTU possesses telecontrol functions, such as: ■ Alarm acquisition and processing, including: – Single point information – Double point information – Bit patterns – Transformer taps – Metering pulses ■ Measured value acquisition and processing, including: – parameterizable current inputs in ranges from 0.5 mA–24 mA – parameterizable voltage inputs in ranges from 0.5 V – 10 V ■ Fail-safe command output, including: – Single commands – Double commands – Bit pattern outputs – Transformer tap change control – Pulse commands – Continuous commands ■ Telecontrol communication with a maximum of two system control centers with different telecontrol messages, with the standardized IEC 60870-5-101 and/or with the worldwide proven SINAUT 8-FW protocol. In addition to the standard RTU functions, the SICAM RTU provides additional functions, such as: ■ Efficient operation mode control with 15 priorities and various send lists, such as: – Spontaneous lists with/without time – Scan lists for measured values, metered values or status indications – Cyclic lists – Time-controlled lists With the aid of this mode control system, it is possible to optimize the data flow between remote terminal unit and system control center.

1

2

3 1. Select a module from the Hardware Catalog and 2. Drag it to the desired module location –

4

automatic plausibility checking and addressing

Fig. 183: plusTOOLS for SICAM RTU, hardware configuration ■ Time synchronization via DCF or GPS re-

■

■ ■

■ ■ ■

ceiver on the TP1 module. The SIMATIC CPU is synchronized to within an accuracy of 1 ms. Serial interface to a maximum of two control centers. In addition to selection of the telecontrol protocols IEC 60870-5-101 and SINAUT 8-FW, the scope of status indications, measured values and commands per control center per interface can be configured, with separate telecontrol protocols, different process data, different message addresses and different modes. Can be extended up to 4096 information points Comprehensive remote diagnostic facilities locally or in remote form with the aid of the SIMATIC TeleService. Output of analog setpoints via the S7-400 AO module (1500 kV insulated) SICAM RTU is maintenance-free and requires no fan cooling The variety of available module types with wide-range inputs is kept to a minimum; the value ranges are parameterizble.


5

Engineering The SICAM RTU is designed such that all telecontrol functions are parameterizable. Comprehensive Help texts assist the operator during configuration. The following configuration steps are carried out with the aid of the intuitive-operation program plusTOOLS for SICAM RTU: ■ Creation of hardware configuration, SIMATIC modules and SICAM modules ■ Setting of module parameters on the SIMATIC modules and SICAM modules ■ Assignment of process data to the message addresses ■ Assignment of message addresses to the message lists in the mode control system, stipulation of send priorities. ■ Checking of all parameters for plausibility. ■ Loading of parameters into a non-volatile flash EPROM of the CPU. Fig. 183 shows as an example the mask for hardware configuration.

6

7

8

9

10

6/101

Local and Remote Control SICAM RTU – Functions

Automation functions

1

2

3

4

5

The SICAM RTU is based on the SIMATIC S7-400. Therefore, all modules of the SIMATIC S7-400 System can be used in a SICAM RTU: For example, a CPU 413-DP with PROFIBUS connection or the communication processor CP 441, e.g. for connection of a Modbus device. If additional functions are to be introduced project-specifically by S7 PLC means, these can be integrated with the aid of the internal API Interface (Application Program Interface). Thus, for example, the data received via the CP 441 can be processed internally and sent via the TP1 to the system control center. The following functions can for example be implemented: ■ Initiate functions by commands from the system control center ■ Derive commands as a function of measured value changes (e.g. load shedding when a frequency drop has been measured) ■ Connection of an operator panel to the serial system interface (Fig. 184a/b) ■ Connection of decentralized peripherals via the PROFIBUS DP

Fig. 184a: Operator Panel

6

7

8

9

10

Fig. 184b: Operator Panel mounted in a cubicle door

6/102


Local and Remote Control SICAM MRTU/microRTU

SICAM MRTU 6MD202/6MD203 Small Remote Terminal Unit

1

Overview Supplementary to the SICAM RTU, the following small remote terminal units are available for low-level upgrades: ■ SICAM microRTU 6MD203 up to 50 process inputs/outputs ■ SICAM miniRTU 6MD202 up to 300 process inputs/outputs The two remote terminal units are based on the SIMATIC S7-200. Supplementary to the SIMATIC modules, a “SICAM TCM” communication module has been developed for the SICAM miniRTU. The TCM module is installed in a S7-214 housing. The SICAM micro and miniRTUs provide small remote terminal units which handle the process data and communicate by means of an assured IEC 60870-5-101 telecontrol protocol with the system control center. The SICAM miniRTU makes it possible to supplement project-specific functions. Both units possess the following advantages of the SIMATIC S7-200 System in terms of construction: ■ Compact design ■ Quick mounting by snapping onto a hat rail ■ Low power consumption ■ Extensive range of expansion modules – Digital inputs – Relay outputs – Electronic outputs – Analog inputs – Analog outputs ■ Connection of expansion modules by means of plug-in system ■ Connection of process signals by means of screw terminals ■ Automatic recognition of upgrade level

2

3

4

Fig. 185: SICAM microRTU

SICAM microRTU 6MD203 5

For the SICAM microRTU, it is possible to use an S7-214 or an S8-216 CPU. The PPI interface is used for loading the programs and the parameters and also for communication with the system control center. The standardized transmission protocol IEC 60870-5-101 has been implemented. Unbalanced mode has been chosen as traffic mode because small remote terminal units are generally operated in partyline (that is to say polling) mode. The SICAM microRTU performs the following functions: ■ Acquisition and processing of a maximum of 24 single point items of information ■ Acquisition and processing of metering pulses (maximum 20 Hz) for a maximum of 4 metered values ■ Acquisition of a maximum of 12 measured values ■ Command output as pulse or persistent command for a maximum of 14 digital outputs ■ Transmission of data (priority-controlled) spontaneously or on demand in half duplex mode ■ Transmission rate: 300 – 9600 bit/sec Parameterizing takes place with STEP7 MicroWIN. All parameters are preset; they only have to be adapted slightly. The parameters are loaded locally from the PC. For transmission, there is a gradable V.23 hat-rail-mounted modem with an RS-485 interface. The transmission rate is 1200 bit/sec.


6

7

8

9

10

6/103

Local and Remote Control SICAM miniRTU

SICAM miniRTU 6MD2020 1

2

3

4

5

6

7

Overview The SICAM miniRTU differs from a SICAM microRTU in the following respects: ■ Volume of data: 300 instead of 50 information points ■ Clock control: messages with time stamp are possible ■ An integrated V.21 modem is available ■ Project-specific additions can be introduced via the API interface The SICAM miniRTU is a small, efficient modular remote terminal unit with a wide range of functions. The SICAM miniRTU can be upgraded from a configuration level of 14 digital inputs up to a medium-sized terminal with a maximum of 300 process points. For the SICAM miniRTU, it is possible to use the S7-200 CPUs 27-214 or S7-216. In addition, the TCM (telecontrol module) communication module is required. The TCM incorporates an RS-232 interface for communication with the system control center; this implements the entire message interchange. The standard transmission protocol is implemented: IEC 60870-5101, unbalanced mode. IEC 60870-5-101 balanced mode and SINAUT 8-FW point-topoint traffic are in preparation. Fig. 186 illustrates a minimum configuration level of a SICAM miniRTU with an S7-214 CPU. Fig. 187 shows in diagrammatic form a maximum configuration level with 3 S7-200 CPUs.

Fig. 186: SICAM miniRTU with TCM and S7-214 CPU

Functions

■ Acquisition and processing of measured

The SICAM miniRTU performs the following functions or incorporates the following features: ■ Acquisition and processing of single point and double point information. Transmission with or without time in message. ■ Acquisition and processing of metering pulses (maximum 20 Hz). Re-storing by means of internal timer or by means of message from the system control center. Transmission with or without time in message.

■

■ ■ ■

values, threshold processing, threshold matchable by means of message. Transmission with or without time in message. Command output as pulse commands with 1-out-of-n monitoring and command release. Persistent command output is possible. Analog setpoint output. Bit-by-bit assignment of process information to processing functions Clock control with synchronization by message from system control center

2-wire, partyline traffic, transmission on demand

8 IEC 60870-5-101 unbalanced mode

9

10

Fig. 187: SICAM miniRTU with TCM and three S7-214 CPUs

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Communication Communication with the system control center is carried out by the SICAM miniRTU with the TCM communicaton module. A gradable V.21 modem is already integrated in the TCM, so that the SICAM miniRTU can be used directly. Other communication characteristics are: ■ Transmission speed of 300 – 9600 bit/ sec. adjustable ■ Mode control with 15 priorities which can be freely assigned ■ Different send lists for: – Spontaneous mode – Polling mode – Cyclic mode Linkage of small remote transmission units generally takes place by means of transmission on demand. The lines with the remote transmission units are compressed with the aid of a data concentrator and are relayed to the system control center. Fig. 188 shows an example of configuration. Rail-mounted modems with RS-232 interface are available for transmission with an external modem: ■ Gradable V.23 modem with 1200 bit/sec transmission speed ■ Dedicated line modem – V.32 modem – with a transmission speed of 9600 bit/ sec.

To control center Point-to-point traffic

1

2 SINAUT LSA data concentrator

3

4 2-wire, polling mode

5

Fig. 188: SICAM miniRTU, typical configuration

6 Project-specific expansion options In the SICAM miniRTU, an API interface (Application Program Interface) is available. Project-specific programs can thus be upgraded. Access by the API interface to communication is supported by the system. That is to say, the information from the control center can be processed in the user program; information derived in the user program can be remotely controlled. Examples of this are: ■ Formation of group alarms, ■ Transmitting internally formed measured values or metered values to the control center, ■ Initiating functions by means of commands from the control center, ■ Influencing of alarm processing, for example filtering, relaying via API, ■ Activating PROFIBUS link on an S7-215.


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Engineering

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3

4

Parameterizing is effected with the plusTOOLS program for miniRTU. The program can be run on Windows 95, 98 or NT 4. Parameterizing takes place operator-guided by means of menus. Extensive help texts facilitate operation. Figs. 190 and 191 illustrate as examples the mask for hardware configuration and the mask for assignment of message addresses. The parameters are checked for plausibility prior to loading. They are loaded in nonvolatile form from the PC into the flash EPROM of the TCM. All parameters of a SICAM miniRTU can be read locally with the PC. For this purpose, the parameter set of the station to be read out does not have to be present on the PC. Modification and reloading is possible.

Design

RTU Type

SICAM RTU

6MD201

SICAM miniRTU

6MD202

192 2)

192 2)

SICAM microRTU

6MD203

24

16

1)

2)

Single point information 1)

Analog Single commands 1) inputs

Analog outputs

typical up to 2048 maximum: 4096 36 2)

Serial ports to CC

2 12 2)

1

4

1

12

Processing of double point information and double commands is also possible. The table is intended solely to represent the number of connection points. Maximum values; note combination options!

Fig. 189: Remote terminal units, process signal volumes

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8 Fig. 190: plusTOOLS, generation of hardware configuration

Fig. 191: plusTOOLS, parameterizing of communication

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Local and Remote Control SICAM SAS – Overview

SICAM SAS Overview 1 In order to assure security of supply, the substation automation system must be capable in normal operation of real-time acquisition and evaluation of a large volume of individual items of information. In the event of a fault, additional information is required to assist rapid fault diagnosis. Graphic display functions, logs and curve evaluations are aids suitable for this purpose. The SICAM SAS substation control and protection system provides a system solution for efficient implementation of these functions. SICAM SAS is designed as an open-type system which, based on international standards, provides simple interfaces for integration of additional bay control units or new transmission protocols, as well as interfaces for implementation of project-specific automation functions.

2

3

4

5

Field of application SICAM SAS is used in power transmission and distribution for automation of mediumvoltage and high-voltage substations. It is used wherever: ■ Distributed processes are to be monitored and controlled. ■ Functions previously available on a higher control level are being decentralized and implemented locally. ■ High standards of electric insulation strength and electromagnetic compatibility are demanded. ■ A real-time capability system is required. ■ Reliability is very important. ■ Communication with other control systems must be possible.

6

Fig.192: SICAM SAS components: SICAM SC Substation Controller, SIPROTEC 4 relays and 6MB525 bay control units

7

Functions SAS assumes the following functions in a substation: ■ Monitoring ■ Data exchange with and operation of serially connected protection devices and other IEDs ■ Local and remote control with interlock ■ Teleindication ■ Automation ■ Local processing and display ■ Archiving and logging

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Local and Remote Control SICAM SAS – Structure

System architecture

1

2

3

4

The typical configuration of a SICAM SAS consists of: ■ SICAM SC Substation Controller ■ Connection to higher-level system control centers ■ Connection to bay level ■ Bay control units, protection relays or combined control and protection bay units. ■ Configuration PC with SICAM plusTOOLS ■ Operation and monitoring with SICAM WinCC The modular construction of the system permits a wide range of combination options within the scope of the system limits. In the SICAM SC substation controller, the SICAM I/O modules can be used for alternative central connection of process inputs and outputs (see description of the SICAM RTU).

5

System control center(s) or telecontrol node(s) GPS

IEC 60 870-5-101 SINAUT 8-FW

SICAM plusTOOLS Configuration

SICAM SC Substation Controller

SIMATIC NET PROFIBUS FMS

SICAM WinCC Operator control, monitoring, and archiving

SIPROTEC 4 protection and control devices

IEC 60870-5-103 wire RS485

6MB525 bay control units and 7**6 relays

O.F.

O.F.

SIPROTEC 3 protection relays

Fig. 193: Typical configuration of a SICAM SAS

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Local and Remote Control SICAM SAS – SC Substation Controller

SICAM SC Substation Controller The SICAM SC is an open-type, modular construction telecontrol and substation controller. The specific functions of a telecontrol system are combined with those of a programmable automation system (PLC). Standard functions of the automation system and control and protection-specific applications, such as real-time processing, fail-safe command output or telecontrol functions, combine to form a rugged, future-oriented hardware system. The basis of the SICAM SC is formed by the SIMATIC M7- 400 family of systems. In order to meet the increased requirements of telecontrol and substation control technology for electric insulation strength, you now have at your disposal a wide range of modules and devices to supplement the SIMATIC standard modules. The communication processors of the system support the IEC 60870-5-101, SINAUT 8FW, IEC 60870-5-103, PROFIBUS FMS, PROFIBUS DP and Industrial Ethernet communication protocols.

Hardware

Construction

The hardware of the SICAM Substation Controller is based on the standard modules of the SIMATIC S7/M7- 400 automation system and on additional modules which have been developed for the special requirements of control and protection. The following modules form the basic complement of the SICAM SC: ■ Power Supply ■ SIMATIC M7- 400 CPU (Pentium processor) ■ MCP (Modular Communication Processor) The MCP module is the function module which supports the communication functions, such as telecontrol connection to higher-level system control centers, e.g. with the IEC 60870-5-101 protocol, and serial connection of bay control units by means of the IEC 60870-5-103 protocol. In addition, it is in SICAM SAS the time master, to which can be connected time signal receivers for DCF77 or GPS. Additionally available for the MCP are the XC2 (eXtension Copper 2 interfaces) and XF6 (eXtension Fiber optic 6 interfaces) extension modules for additional communication interfaces to higher-level system control centers and bay control units (IEC 60870-5-103). In addition, the following modules can be used for supplementary functions in the SICAM SC: ■ For central process connection: SICAM I/O modules (see description of the SICAM RTU) and SIMATIC 400 Standard I/O modules (see Siemens Catalog ST 70) ■ For connection of bay control units via Profibus DP and FMS: SIMATIC 400 communication processor modules ■ For connection to SICAM WinCC: SIMATIC 400 modules for Profibus FMS and Industrial Ethernet

Like the SICAM RTU, the SICAM SC is based on the SIMATIC 400. Consequently, the statements on construction of the SICAM RTU are also applicable to the SICAM SC.

1

2

Software The bases of the run-time system (SICAM RTC for SAS) in the SICAM SC are to be found both on the M7-CPU and on the MCP module real-time operating systems for event-controlled program execution. Among other things, this assures an essential requirement for control applications: State change of information may not be lost or remain unnoticed in critical situations (→ alarm surge).

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1

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System security

Measured value capturing

System capacity

SICAM SAS fulfills to a very considerable extent the reliability and security requirements imposed on a substation control and protection system. In the case of all electronic devices incorporated in the SAS SICAM System, special attention has been paid to electromagnetic compatibility.

■ Live zero monitoring (4 –20 mA)

The maximum configuration of the SICAM SC substation controller consists of: ■ 1 baseframe with 7 to 11 free module locations, dependent on choice of MCP communication link and ■ Maximum of 6 expansion racks, each with 14 free module locations Thus, you have available a maximum of 95 free module locations which you can equip for example with 95 I/O modules or a further 4 MCP(4) communication assemblies and 75 I/O modules. For connection of bay control units via PROFIBUS FMS, up to 4 CP443-5 base communication processors can be plugged into the baseframe. Each CP443-5 requires one module location. For connection of PROFIBUS DP devices, an interface module is used which is plugged into a module shaft of the CPU module. Connection to Industrial Ethernet can be implemented via the CP443-1 communication processor and will then require one module location. Alternatively, you can also however use the CP1401 interface module which is plugged into a module shaft of the CPU module. Under these conditions, it is possible to implement up to a maximum of 3040 items of information to a SICAM SC via centralized process connection. With the use of bay control units – linked to the SICAM SC via MCP communication assemblies or PROFIBUS – it is possible for up to 10,000 items of information to be managed, for decentralized process connection.

Interruption of power supply

3

The SICAM SAS System is designed to be maintenance-free, that is to say no backup batteries are required for restart after mains failure. Safety functions

4

Hardware self-test: On startup and cyclically in the background. General check: At start of the transfer time system and creep mode in background. Communication

5

6

7

Errors in data transmission due to electromagnetic effects, earth potential differences, ageing of components and other sources of interference and noise on the transmission channels are reliably detected. The safety measures of the protocols provide protection from: ■ Bit and message errors ■ Information loss ■ Unwanted information ■ Separation or interference of assembled items of information Priority-controlled message initialization Messages initiated by events are initialized quickly (priority-controlled).

Command output Safe command output, i.e. ■ Destination monitoring (1-out-of-n) ■ Switching current check ■ Interference voltage monitoring ■ Determination of the coil resistance The SICAM SC system provides the following five operating modes, thus allowing the user to take into account different safety requirements for process output: ■ 1-pole command output 1 ■ 1 /2-pole command output ■ 2-pole command output 1 ■ 1 /2-pole command output with separate command release through CR module ■ 2-pole command output with separate command release through CR module By combining the CO module with the CR module, a single error (in case of 11/2pole command output) in the command output circuit results in the command not being executed. Through the test and monitoring measures provided by the CR module, which make it possible to distribute the command output circuit to two independent modules, high requirements are met.

Interfaces

8

9

10

Failure indication The failure status is derived in case of: ■ Contact chatter ■ Signalling-circuit voltage failure ■ Module out of order A telecontrol malfunction group alarm can be parameterized from individual pieces of information, for example: ■ MCB trip ■ Voice-frequency telegraphy error ■ Channel error ■ No signalling-circuit voltage ■ Module out of order ■ Buffer overflow

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The variability and expansion capability of a substation control and protection system depends primarily on its outward interfaces. SICAM SAS supports international standards, such as PROFIBUS, the IEC 60870 5-101 telecontrol protocol or the IEC 60870-5-103 relay communication protocol and thus assures optimum flexibility of substation planning. The SICAM communication modules of the SICAM SC are equipped with serial interfaces (parameterizable as RS232 or as RS422/485) and with optical fiber links. They are combined, according to application, to form MCP communication assemblies which consist of the MCP communication processor and XC2 and/or XF expansion modules.



Telecontrol interfaces Via the serial interfaces of the MCP communication processor and the XC2 expansion modules, one can connect the SICAM SC to a maximum of three higher-level system control centers. The telecontrol interfaces are operated with the IEC 60870-5-101 or SINAUT 8FW transmission protocols and are parameterizable as RS232, RS422/RS485 or optical fiber interfaces.

Substation bus

1

Telecommunication

– Industrial Ethernet – PPROFIBUS FMS Connection to SICAM WinCC

– IEC 60 870-5-103 SINAUT 8FW

Module MCP (XC2, XF6)

2

Module CP443-1 or -5

Bay control unit interfaces For connection of decentralized items of information via bay control interfaces, various options are available: ■ A maximum of 4 CP 443-5 base modules for connection of bay control units with PROFIBUS FMS interface. One can connect a maximum of 48 devices (SIPROTEC 4, 6MB525) per module; the total number in the design may not however exceed 96 devices. ■ One IF964-DP interface module for connection of a maximum of 20 SU200 bay control units and/or SIMEAS measuring transducers via PROFIBUS DP. For all other bay control units with PROFIBUS DP interface, the upper limit of 127 devices will apply. ■ A maximum of 4 MCP(4) communication assemblies, each consisting of one MCP communication processor and 4 XF6 expansion modules with optical fiber interfaces for a maximum of 96 bay control units (IEC 60870-5-103). ■ A maximum of 1 MCP (1) communication assembly (consisting of 1 MCP communication processor and 1 XC2 expansion module) and 1 MCP communication assembly (consisting of 1 MCP communication processor) for a maximum of 186 bay control units via a maximum of 6 RS485 lines (IEC 60870-5-103). Combinations of the above examples are possible, but the quantity of 10,000 information points should not be exceeded. MPI interface On the CPU module is located 1 MPI interface (token ring multipoint-capability bus structure) for design, parameterizing, diagnostics. Time signal reception The MCP communication processor possesses an interface for receipt of an external time signal. Time synchronization is effected by means of DCF77 or GPS.

3

Field bus

4

– PROFIBUS FMS Connection to SIPROTEC

IED-communication

Module CP443-5

– IEC 60 870-5-103 protection relays and bay units

– PROFIBUS DP DP-“devices“

Module IF964

5

Module MCP (XC2, XF6)

Fig. 194: SICAM SC communication interfaces

6 Design tools

Bay control units

Design of the SICAM SC is carried out with SICAM plusTOOLS which is based on the SIMATIC basic modules: STEP7, SIMATIC CFC and Borland C/C++.

In the design and parameterizing of subdevice connections, SICAM plusTOOLS accesses databases which describe the interface complement of the devices. Creation of a new protection unit type with IEC 60870-5-103 transmission protocol is made possible by the parameterizer in SICAM plusTOOLS.

Process visualization For visualization and control of the process, SICAM WinCC is used; this is based on SIMATIC WinCC. Expandability SICAM has been designed for a new generation of devices and function modules for the automation of substations in power supply. SICAM integrates complementary and compatible product lines and is the logical continuation of proven, available modules. By virtue of its open system concept, SICAM SAS is adaptable to the growing demands of the future. System expansion and further development are readily possible.


7

8

Protocols Telecontrol and field bus protocols will in future be incorporated in modular fashion by means of an expansion interface.

9

SIMATIC modules Within SICAM SAS, it is possible to use the SIMATIC Standard I/O modules (see Siemens Catalog ST70, Siemens Components for Totally Integrated Automation.)

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Local and Remote Control SICAM SAS – Bay Control Units

1

2

3

Bay control units

6MB525 Mini Bay Unit

Serial connection of distributed bay control units allows access to extensive detailed information about your switchgear in the substation control and protection system. For this purpose, SICAM SAS offers bay control units with differing scope of information and function. The range extends, according to requirements, from pure bay control units and protection relays on the one hand, to combined devices on the other hand which provide the bay protection and control functions in a single unit. SICAM SAS supports bay control units with IEC 60870-5-103, PROFIBUS FMS and PROFIBUS DP interface.

(see description of SINAUT LSA) This low-end unit with its limited range of information is preferably used in singlebusbar substations. It can be connected via RS485 with IEC 60870-5-103 or via PROFIBUS FMS to the SICAM SC. 7SJ531 Combined Bay Control and Protection Unit (see description of SINAUT LSA and Power System Protection) The 7SJ531 possesses, in addition to protection functions, the facility for controlling a switching device (also remotely). It can be integrated in the SICAM SAS with IEC 60870-5-103 via optical fiber link.

4 Design

Signal inputs Double Single

Analog inputs Direct connection to transformer

Connection to measure transducer

6MD631 6MD632

4 5 + 4 2)

– 1

5 12

1 –

4 x I, 3 x U 4 x I, 3 x U

– –

6MD633

5 + 4 2)

1

10

–

4 x I, 3 x U

2

6MD634

3+4

2)

–

10

–

–

–

6MD635

7 + 8 2)

–

18

1

4 x I, 3 x U

–

6MD636

7 + 8 2)

–

16

1

4 x I, 3 x U

2

6MD637

4 + 8 2)

1

16

1

–

–

7SJ610 7SJ612 7SJ621 7SJ622 7SJ631 7SJ632

– – – – 4 5 + 4 2)

4 6 8 7 – 1

– – – – 5 12

3 11 7 11 1 –

4xI 4xI 4 x I, 3 x U 4 x I, 3 x U 4 x I, 3 x U 4 x I, 3 x U

– – – – – –

7SJ633

5 + 4 2)

1

10

–

4 x I, 3 x U

2

7SJ635

7 + 8 2)

–

18

1

4 x I, 3 x U

–

7SJ636

7 + 8 2)

–

16

1

4 x I, 3 x U

2

5

6

Compact bay control unit (SIPROTEC 4 design with large graphic display) 1)

7

8

Combined control and protection device with local bay control 1)

9

Components

Commands Double Single

Type

10

1) 2)

Bay control units in new design, optimized for medium voltage switchgear with 11/2-pole control (max. 7 switching devices). 2-pole control is also possible (with max. 4 switching devices). Double commands and alarms also usable as ”single“

Combined control and protection devices. 7SJ61 and 7SJ62 with 4 line text display, 7SJ63 with graphic display. Optimized for 11/2 pole control (max.7 switching devices). 2-pole control is also possible (with max. 4 switching devices). Double commands and alarms also usable as ”single“

11/2-pole control; 2-pole control possible Second figure is number of heavy duty relays

Fig. 195: Survey of bay units

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Local and Remote Control SICAM SAS – Bay Control Units

SIPROTEC 4 (see description of Power System Protection) The 7SJ63 and the 6MD63 are designed for larger volumes of information and thus are also suitable for use in duplicate-busbar substations. SIPROTEC 4 units are preferably connected to the SICAM SAS via PROFIBUS FMS. Connection via IEC 60870-5-103 with reduced functionality (compared to the use of PROFIBUS FM) is also possible. The SIPROTEC 4 7SJ61 and 7SJ62 relays can also be used via Profibus FMS and IEC 60870-5-103 in SICAM SAS. These two units support control of the feeder circuit-breaker.

1

System control center or telecontrol node GPS SIMATIC plusTOOLS Configuration

SICAM SC Substation Controller

3

4

Protective relays (V3 type)

MPI

By means of IEC 60870-5-103, all SIPROTEC 3 protective relays (see Power System Protection, page 6/8), and also protection relays of other manufacturers supporting IEC 60870-5-103 can be connected to the SICAM SC substation controller.

PROFIBUS FMS Fiber optic cables

OLM (Optical Link Module)

5 Fiber optic cables

Other bay control units In addition, the following can be connected to the SICAM SC: ■ SIMEAS T transducer via IEC 60870-5-103 ■ SIMEAS Q Power Quality via PROFIBUS DP ■ Maschinenfabrik Reinhausen transformer tap voltage controllers (for example VC100, MK30E) via IEC 60870-5-103 ■ Eberle transformer tap voltage controller (RegD) via IEC 60870-5-103 ■ SU200 bay control unit for high-voltage use via PROFIBUS DP ■ Decentralized peripherals via PROFIBUS DP (for example ET200)

2

IEC 80 870-5-101 SINAUT 8-FW

SICAM WinCC Operator control and monitoring, archiving

6

7

SIPROTEC 4 devices via PROFIBUS FMS Fig.196: SICAM SAS, connection of SIPROTEC 4 bay control units via PROFIBUS FMS and optical fiber

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Local and Remote Control SICAM SAS – Human-Machine Interface

SICAM WinCC

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In the SICAM SAS substation automation system, SICAM WinCC is the human-machine interface HMI between the user and the computer-assisted monitoring and control system. For efficient system management, numerous single information items must be displayed quickly and clearly. The state of the substation must be displayed and logged correctly at all times. Important indications, along with measured and metered values of past time periods must be archived in such a way that they are available for specific evaluation in the form of curves or tables at any time. The SICAM WinCC human-machine interface meets these requirements for efficient system management and also provides the user with numerous options for individual design of the system user interface and numerous open interfaces for implementing operation-specific functions. The windowing technique of SICAM WinCC makes it easier to work with. In designing the graphic displays, the user has every degree of freedom and also has the support of a pool of predefined substation automation symbols such as switchgear, transformers or bay devices. SICAM WinCC consists of the WinCC process visualization system and SICAM software components. ■ WinCC WinCC offers standard function modules for graphical display, for messaging, archiving and reporting. Its powerful process interface, fast display refresh and reliable data archiving function assure high availability. S7-PMC serves as a basis for a chronological messaging and archiving of data. ■ SICAM components They consist of: – SICAM symbol library, – SICAM message management expansion, – SICAM wizards, – SICAM processing functions and – SICAM Valpro, (Measured/ Metered Value Processing Unit)

protection systems. One can use them for designing detail images. The symbols are selected from the library and placed in a detail image using the Drag & Drop function. The symbols are dynamized. Thus, for example, there are several different views of a circuit-breaker which visualize the ON, OFF or fault position switching states.

Fig. 197: Overview diagram in Graphics Designer

SICAM symbol library The SICAM symbol library contains switchgear, bay devices, transformers and other object templates for bay representations which are typical for substation control and

Fig. 198: Selecting a circuit-breaker from the symbol library

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Local and Remote Control SICAM SAS – Human-Machine Interface

SICAM message management expansion

1

The SICAM message management expansion ensures a chronological messaging and archiving of data. On the basis of S7-PMC, the SICAM Format DLL evaluates the data and assigns the corresponding messages to them. Based on this, a millisecond resolution of all events is given and for every event not only the state of indication itself is available, but also additional information without the need for additional parameterizing effort. For message assignment, the format DLL recurs to the WinCC text libary. You can adapt the texts contained in the text library to meet your project-specific requirements. SICAM wizards The SICAM wizards assist the user in creating a new WinCC project. The following tasks are carried out with help of the wizards: ■ Creating SICAM structure types: The Create SICAM tag structure types wizard helps the user to generate the structure types for structured tags which are necessary in a SICAM system. Structure types are needed for importing tags from SICAM plusTOOLS. ■ Taking over tags from SICAM plusTOOLS: The Import SICAM tags wizard helps to import tags from SICAM plusTOOLS into SICAM WinCC. This function allows the user to visualize information, i.e. to represent it in process diagrams, configured and parameterized with SICAM plusTOOLS. ■ Creating the SICAM message management: The SICAM message management wizard helps the user to generate a message management system under WinCC which meets the specific requirements of a substation automation system. In addition to a message archive, the SICAM message management includes the following templates: event list, alarm list and protection message list. Each of these lists always contains message blocks, message window templates, message line formats, message classes, message sequence reports, layouts and texts.

2

3

4

Fig.199: SICAM WinCC event list

■ Taking over messages from SICAM

plusTOOLS: The Import SICAM messages wizard helps the user to import messages from SICAM plusTOOLS into WinCC. This function allows the user to report information in the message management system which was configured and parameterized with SICAM plusTOOLS. This function allows the user to visualize information from SICAM plusTOOLS under WinCC, i.e. to use it in process diagrams. ■ Creating the SICAM archiving system: The Create SICAM archives wizard helps generation of an archiving system under WinCC. The SICAM WinCC archiving system consists of: – a sequence archive for measured values and – a sequence archive for metered values. One can import metered values und measured values from SICAM plusTOOLS into this archiving system. ■ Integrating the SICAM symbol library: The Import SICAM libary wizard helps the user to load the SICAM symbol library into the current project. One can use the symbol library for designing individual detail images.


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Local and Remote Control SICAM SAS – Engineering Tools

SICAM Valpro

1

2

3

Curve and tabular display of archived measured values and metered values is carried out by means of the SICAM Valpro program. Valpro provides the facility for using archived values for various evaluation purposes, without altering them in the archive. The user decides at the time of evaluation (in a dialog) which values should be displayed in which raster. In addition to the variables to be displayed, he specifies the time range, the color and if necessary the mathematical function to be carried out. One can have totals, averages, maximums, minimums or the power factor formed and displayed. The calculation interval can be individually specified. Stored presets can be altered at any time.

4 Engineering System SICAM plus TOOLS

5

6

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10

With SICAM plusTOOLS, a versatile and powerful system solution is available, which supports the user efficiently in configuring and parameterizing the SICAM SAS (SICAM Substation Automation System). SICAM plusTOOLS is based on Windows 95 and Windows NT. Thus the user moves within a familiar system environment and can recur to the well-known, convenient functionality of the Windows technique. SICAM plusTOOLS allows a flexible procedure when configuring and parameterizing a station, while providing consequent user guidance at the same time. Plausibility checks allow only operations and combinations which are permissible in the respective context. ■ Permissible input variables are displayed in drop-down lists or scroll boxes. ■ The Drag & Drop function makes it easy to group, separate or move data. ■ Context-sensitive help texts explain the text boxes and the permissible input variables. ■ Copy functions on different levels optimize the configuration procedure. ■ Help texts which are organized according to topics explain the configuration. The SICAM plusTOOLS Software Package The SICAM plusTOOLS configuration system is divided into individual, function-specific applications.

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Fig. 200: Example of curve evaluation using Valpro

Fig. 201: Hardware Configuration of a demo station

SIMATIC Manager

Hardware Configuration

The SIMATIC Manager is the platform of SICAM plusTOOLS. With the help of the SIMATIC Manager, the user defines and manages the project and calls the individual applications. The project structure is created automatically in the course of the configuration procedure. The data areas are organized in separate containers. In the navigation window of the SIMATIC Manager, the project structure is represented similar to a Windows 95 directory tree. Each container corresponds to a folder on the respective hierarchical level.

The Hardware (HW) Configuration application serves for configuring the modules and their parameters. The configuration is represented as a table on the screen. The user chooses the components from a Hardware Catalog and places them into the hardware configuration window using Drag & Drop or double-clicks. The tabs for parameterizing the modules are already filled with the default values, which can be modified by the user.


Local and Remote Control SICAM SAS – Engineering Tools

COM IED The COM IED application (Communication to Intelligent Electronic Devices) serves for configuring the connection of bay devices in control and monitoring direction. The bay devices are imported into COM IED with their maximum information volume from an IED Catalog using Drag & Drop. The information volume can be reduced later. If SIPROTEC 4 bay units with Profibus FMS communication are used, then the information parameterized with DIGSI 4 will be taken over automatically.

1

2

3

COM TC The COM TC application manages all parameters which are related to the information exchange with higher-level control centers. The telegrams are configured separately for control and monitoring direction. For the transmission of the telegrams in monitoring direction, these are assigned to priority-specific and type-specific lists. The list types are provided in a Telecontrol List Catalog and are copied into COM TC using Drag & Drop.

4 Fig. 202: MCP Parameterizing

5

CFC In the SICAM SAS System, automation functions, such as: ■ Bay-related and cross-bay interlocks ■ Switching sequences (busbar changes, etc.) ■ Status indication and command derivatives (group indications, load shedding, etc.) ■ Measured value and metered value processing (limit value processing, comparative functions, etc.) are projected graphically with the CFC (Continuous Function Chart). The scope of supply of SICAM plusTOOLS includes a comprehensive library of SICAM SAS components. The designer makes his selection from this library, positions the selected component by Drag and Drop on his worksheet and interconnects the components required for its function to one another and to the process signals.

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8 Fig. 203: COM IED and bay units catalog

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Fig. 204: CFC with Component Library


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Local and Remote Control SICAM PCC – System Design

Introduction 1

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7

ICCP (ISO/IEC 870-6 TASE.2) Link To Control Center (Optional)

Changing requirements The ongoing deregulation of the power supply industry has been creating a competitive environment with new challenges for the utilities: ■ The liberalized production, transmission and distribution of electrical power call for more flexible operation of the power system resulting in more complex control, metering and accounting procedures. ■ The deregulated system structure requires the extension of load and quality of supply monitoring, as well as event and disturbance recording, to control the business processes and to care for liability cases. ■ Operation data that has traditionally been used only within a given utility must now be shared by a number of players in various locations, such as utilities, independent power producers, system operators and metering or billing companies. More effective data acquisition, archiving and communication is therefore needed. ■ Competition requires that costs have to be reduced wherever possible. The optimization of processes has consequently been given high priority. System automation and in particular distribution automation including automatic meter reading and customer load control can therefore be observed as the future trend. The SICAM PCC meets these requirements by integrating modern PC-technology and open communication.

SICAM PCC

Router Substation LAN

LAN-Enabled IEDs

(Legacy) IEDs

Fig. 205: Sample Substation with SICAM PCC

(Legacy) IEDs SICAM Substation Controller

Substation LAN “A”

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9

ICCP (ISO/IEC 870-6 TASE.2) Link To Control Center(Optional)

Legacy Protocol (e.g., DNP, IEC 870-5) Link To Control Center

Router SICAM PCC

Substation LAN “B”

(LAN-Enabled IEDs) Fig. 206: Sample Substation with SICAM PCC and SICAM SC

10

Some Typical Configurations

■ One or more legacy IEDs, connected to

PC-Based Substation Automation

■ One or more RTUs. ■ ICCP communications to a Control Center

the PCC in a star configuration. Fig. 203 illustrates a typical configuration employing the SICAM PCC. The components of such a configuration include: ■ SICAM PCC. ■ Substation LAN. ■ One or more LAN Enabled Intelligent Electronic Devices (IEDs).

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(optional). ■ Siemens’ SICAM WinCC Human Machine

Interface (HMI) (optional component of SICAM PCC).



A PLC can be added This, of course, is not the only way in which the SICAM PCC may be used in a substation configuration. Fig. 206 illustrates a slightly more complex substation configuration which includes both the SICAM PCC and the SICAM Substation Controller (SC)1). The SICAM Substation Controller is an advanced Programmable Logic Controller (PLC) (see 6/109 and following pages). Open-ness A product is not ”open“ just because its manufacturer decides to publish the specifications of a proprietary communications protocol. A product is really open if it supports standard and de facto industry standard communications. There was a time, not so very long ago, when vendors of substation and control center equipment offered only proprietary solutions. The designer and maintainer of substations was forced to choose among a number of options, many – in fact almost all-of which would force the designer to use a proprietary communications protocol. After the choice, either the future options became very limited or one was forced to deal with the problem of installing protocol gateways. With SICAM, those days are over. SICAM, and specifically the SICAM PCC, are designed with ”open-ness“ as a primary design consideration. Siemens’ goal in designing this product line is to provide the tools and features which enable the user to design and upgrade the substations the way he wants. The sample configuration diagrams shown are not meant to illustrate all the possible configurations using the PCC and other components of the SICAM product line. Rather, they show that the components of the SICAM product line are designed so that users may take a ”building block” approach to designing or upgrading their substations.

1) In PCC version 2.0, WinCC is required for configurations in which there is communication between PCC and the SICAM Substation Controller.

Real-Time Data

1

DSI “DSI” API Application ODBC

User Interface For Configuration

2

ODBC DSI Central Server

Status Data

ODBC Configuration Data

3

Configuration Data

Status Data

4

RDBMS Configuration Data

Fig. 207: DSI with RDBMS

PCC At A Glance Platform The SICAM PCC executes on Intel-based hardware running the Microsoft Windows NT operating system (Version 4.0 and above). Siemens chose this platform because it offers an effective combination of low hardware and software cost, ease of use, scalability, flexibility, and easy access to support. Distributed Architecture & Database The SICAM PCC uses a high-performance data distribution subsystem for distribution of real-time data among system components. The data distribution subsystem permits distribution of applications across multiple computers to address performance, physical connectivity and redundancy requirements. This means that if a configuration contains more devices than can physically be connected to a single computer, one can distribute the system across multiple computers. Or, if the applications require more processing power than can be provided by a single computer, one can solve the problem by adding additional computers to the system and distributing the processing load. In designing the PCC, the data distribution subsystem was combined with a standard third-party RDBMS. The PCC architecture uses the RDBMS to do what an RDBMS does best – organize and store data.


5 The architecture uses the data distribution subsystem to augment the RDBMS to meet those data distribution performance requirements which the RDBMS cannot address. The presence of both the data distribution subsystem and the RDBMS is largely transparent to the average user. However, for designers and programmers who wish to interface to the PCC infrastructure, Siemens publishes full details of the Applications Programming Interface (API) provided by the data distribution system, including all details of the RDBMS data model used by SICAM PCC. DSI (Distributed System Infrastructure) is a simple data distribution switch which operates in conjunction with a standard RDBMS. While DSI does have some characteristics of a database, it lacks certain others, so it is not referred to as a database. DSI allows distributed applications to share data in a consistent, efficient (i.e. high-performance) manner. There are three basic components which make up DSI: ■ A central application called the DSI central server. ■ A collection of interface functions which make up the DSI API. ■ A data model which describes the RDBMS tables used to store the configuration and status information used by DSI and applications which interface to DSI.

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Interfacing to Other Systems

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The PCC is designed to be an effective integration platform by including support for both modern and legacy communications protocols. The SICAM PCC does several things to simplify the task of interfacing to other systems: ■ The interface to PCC’s data distribution subsystem is fully externalized and documented. All interfaces are available for use by customers or third parties in developing software (including gateways) to interface to the PCC. Siemens provides a Software Development Kit which can automatically generate the basis for a working application, as well as the user interface windows to configure it. PCC’s DB Gateway feature allows you to use familiar RDBMS tools and techniques to exchange data with the PCC. DB Gateway provides a bidirectional mechanism which may be used to insert data into the real-time data distribution system via the RDBMS. That is, one can write an object into the RDBMS using, for example, SQL statements. DB Gateway will retrieve that object from the RDBMS and enter it into the real-time data distribution stream for distribution to other components of the system. Similarly, one can configure DB Gateway to accept data objects from the real-time data distribution stream and write them into the RDBMS. The user can then read them using RDBMS tools and techniques. All of this can be done with almost no knowledge of the internals of the PCC architecture – all one needs to know is which RDBMS table to read and/or which to write. Fig. 208 illustrates the position of Device Master in the architecture. In this picture, it is easy to visualize a protocol module which is isolated from other system components while at the same time has full access to all system services required. ■ Version 2.0 of PCC makes available a set of ActiveX controls which can be embedded into an ActiveX container application. This feature is included as a “proof of concept“ feature to explore the scope of the ability to embed a realtime value from PCC’s data distribution subsystem into a “web” document.

ODBC

DSI API Real-Time Data

Configuration Data Device Master Device Master API

Protocol Module DSI Central Server

RDBMS

Fig. 208: Device Master

”Enterprise” Protocols

”Legacy“ Protocols

Siemens is the acknowledged leader in delivering ICCP solutions. The PCC’s fullfeatured ICCP implementation allows communication with any system which supports this popular protocol. PCC’s ICCP currently supports Conformance Blocks 1, 2, 5, and 8. Whenever a power system disturbance occurs or even during normal operations, it is very useful to be able to collect a log of changes in one or more data objects. Many modern field devices (e.g. relays, meters, etc.) allow collection of this type of data within the device itself. However, many others do not. PCC’s Sequence of Events Logger option allows collection and storage to the RDBMS of any data objects processed by PCC’s data distribution subsystem. Data may be collected either periodically or ”on event“. Since data are stored into the RDBMS, they may be retrieved for analysis using standard RDBMS tools and techniques.

Perhaps the largest problem the user will tackle in attempting to upgrade and automate existing substations arises from the large number of communications protocols used by existing equipment in those substations. Many of these devices simply will not talk to each other. Many of them will not talk to the control center. Even if a completely new substation is built, one may face this problem because the choice of devices may be limited by the suite of protocols which are supported by the existing SCADA or EMS system. A primary design consideration in the PCC is the ability to support legacy1) protocols. The ability to support these protocols has been enhanced by a PCC feature called Device Master. It allows Siemens (and third parties) to develop protocol modules in much less time than would be required for a traditional system. This means that more protocols can be made available more quickly and at reduced cost.

1}

”Legacy“, when used to refer to communications protocols, is an euphemism for ”old and proprietary”.

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Data Conditioning

Human-Machine Interface.

The SICAM PCC includes the feature Data Normalization (or simply Normalization) which provides a simplified method by which normalize procedures may be associated with data objects. These normalize procedures perform transformations on data objects as they enter and leave PCC’s data distribution subsystem. The types of transformation which may be performed include (but are not limited to): jitter suppression, deadband calculations, linear transformation, and curve-based transformation. In addition, custom procedures can be developed and added to the system to perform any type of calculation and data transformation. Up to 16 normalization procedures may be concatenated and applied to a single data object. PCC’s user interface provides a simple, intuitive way to create custom normalization procedures and associate normalization procedures with individual data objects or groups of data objects.

Frequently, it is desirable for personnel working in a substation to have access to HMI displays. If an HMI is available in the substation, costs can be reduced by eliminating or reducing the size of local control panels and the wiring associated with them. Additionally, well-designed HMI displays can reduce the risk of error by presenting data and controls in a logical schematic representation – interlocks can be included to prevent certain operations or to ”remind” personnel to follow certain procedures. If an HMI is used in a substation automation and integration system like the PCC, it is important to ensure that the HMI integrates well into the system. The HMI must be integrated in such a way that it does not become a performance ”bottleneck”. The HMI must not be the ”center” of the substation automation architecture. No HMI offers a sufficient level of data distribution performance to allow it to be used as the “center” of the architecture. Another strong consideration in integrating an HMI is to ensure that whoever has the job of configuring the system is not required to enter data a number of times. Nor should the HMI require the user to become a computer programmer. The PCC’s optional HMI Gateway provides a pathway through which data are exchanged between PCC’s data distribution subsystem and the HMI. Point and click methods are used to select data objects which are to be exchanged with the HMI. If one adds, for example, a new meter to the substation and one wants to place some data from that meter on an HMI one-line display, only a few mouse clicks are required to perform the task. Typing the name of a data object is at no time required. Definition of data objects may be performed either via PCC’s user interface or from within the HMI. The recommended HMI is the WinCC product from Siemens. While WinCC is a superior product, it is recognized that some customers have ”standardized” on another product. The Siemens HMI Gateway however is designed to simplify customization to meet these requirements.


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Local and Remote Control SICAM PCC – User Interface

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Fig. 209: PCC Main Configuration Window

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Fig. 210: PCC Configuration Window – Distributed System

User Interface 8

9

10

The user interface used to configure and operate the PCC is very much influenced by de facto industry standards. Specifically, the user interface has a ”look and feel” established by Microsoft’s Windows 95. The great popularity of Windows 95 made this an easy decision. The choice of a Windows 95 ”look and feel” means that the user interface is familiar to anyone who has used Windows 95 software. The PCC development team has worked with Siemens human factors engineers to make the user interface as intuitive as possible. The PCC’s user interface is divided into two parts: ■ User Interface for Configuration, also called the PCC Configuration Manager. ■ User Interface for Operation, also called the PCC Operations Manager.

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User Interface for Configuration

The navigation window has four elements:

The PCC user interface is started just like any other Windows 95 or Windows NT 4.0 program: 1. Click on the Start button of the taskbar. 2. Select Programs from the menu which appears. 3. Select the SICAM PCC folder from the menu which then appears. 4. Double-click on SICAM PCC. Now a window appears like shown in Fig. 209. It looks like the Windows Explorer of Windows 95 and Windows NT 4.0. On the left is a navigation window. At the top is a menu bar and a tool bar. The navigation window can be undocked and then resized or moved around on your screen.

■ A Systems folder: By opening this fold-

er, one sees an icon for each computer in the PCC configuration. ■ An Interfaces folder: By opening this folder, one sees the interfaces which are configured on the PCC. ■ A Normalization folder: By opening this folder, one is able to create custom normalize procedures. ■ A Tools icon: By opening this, one sees a number of tools which may be used in configuration mode. Fig. 210 illustrates the PCC main window (configuration mode) with several folders open. In this case, the system is a distributed configuration with two computers.


Local and Remote Control SICAM PCC – User Interface

When the user wishes to work with an interface or device, it is done by double-clicking on the device he wishes to work with. For example, Fig. 211 shows the PCC user interface after double-clicking on Meter1 (a relay which speaks the DNP 3.0 protocol). As one can see in this illustration, a new window has appeared on the righthand side of the PCC main window. In this case, the new window contains a tabbed display which may be used to select and rename data objects from Meter1.

1

2

If a mistake is made…

3

The user can change interface and device parameters by double-clicking on the appropriate folders and / or icons. For example, by a double-click on the icon for a device, windows appear which are almost identical to those used to initially configure the device. By working with these windows, one can make any necessary changes to the PCC configuration.

4

Fig. 211: Working with an Existing Device

5

User Interface for Operation The user interface for operation is very much like what has already been shown. One can switch between two modes by clicking on toolbar buttons:

6 selects configuration mode. selects operational mode.

7 The user interface in operational mode looks like the illustration in Fig. 212. Navigation in operational mode is just like configuration mode. The items displayed on the navigation tree are very similar. ■ Operations Manager: By double-clicking on this, the Operations Manager is opened which allows the user to view and control the status of the software and devices which make up the PCC system. ■ Event Log: This is a tool which opens the Windows NT event log viewer. It is used to examine messages which PCC software places in the event log. ■ SCADA Value Viewer: This is a tool which allows the user to examine data which is being distributed by PCC’s data distribution subsystem. Using this tool, one can verify that changes which occur in a device are being correctly communicated throughout the system.

8

9 Fig. 212: User Interface (Operation Mode)

■ Generic Value Viewer: This is a tool

which allows the user to view details of complex data types used within PCC. Like the SCADA Value Viewer, it can also be used to view data being distributed by PCC’s data distribution subsystem. It can also be used to introduce manual changes in data for debugging, testing, and checkout.


The PCC’s Operations Manager displays are built automatically during system configuration. The configuration mode to add a new interface or device will appear on the Operations Manager display the next time the Operations Manager is started. For those who want to customize their display, the PCC user interface provides an interactive tool for customizing colors and text on status indicators.

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10

Local and Remote Control SICAM PCC – Application Example

Application example for Sicam PCC

1

2

3

The example shows the application of SICAM PCC to a large industrial power supply system with distributed substations. (Fig. 213) Remote substation 1 has been built completely new. In the existing substation 2 only the secondary equipment has been refurbished. Control of both substations takes place at the operator workstation in substation 2. The operator workstation in substation 2 is only used in special cases for local control (maintenance, emergency control). Substation 1:

4

5

6

7

Consists of two half-bars, each with 2 incoming cable bays and 8 outgoing feeder bays. The incoming feeder bays are all equipped with a bay control unit 6MD63 for command output, data acquisition and local bay control. In addition, cable differential protection 7SD600 and overcurrent protection relays 7SJ600 are also provided. The outgoing feeders each have a combined protection and control relay 7SJ63, providing overcurrent protection and bayrelated measuring, data acquisition and control functions. The SICAM PCC station serves in this substation predominantly as data concentrator and communication node for the distributed bay units. The connection of the bay units is established by a copper-based multi-drop link (RS 485 bus) according to the IEC 870-5-103 standard. Substation 2:

8

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10

Combined protection and control relays 7SJ63 are used in this substation in all feeder bays. Connection to the substation control system SICAM PCC is again established with the wired RS485-bus as in substation 1. The SICAM PCC, located in the control room of this substation, is designed as a full server and uses WinCC as operating and monitoring tool. The data concentrator SICAM PCC of substation 1 is connected to this common SICAM PCC control station in substation 2 via an optical fiber network using the network-capable protocol IEC 60870-6 TASE.2.

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Distributed SICAM PCC Substation control system FO-ETHERNET ICCP

SICAM PCC

SICAM PCC Win CC

2 incoming feeders

CU/RS 485 (IEC 970-5-103) CU/RS 485

…

… 8 outgoing feeders 2 incoming feeders

CU/RS 485

… 8 outgoing feeders Substation 2

Substation 1

Fig. 213: System Configuration

This configuration provides numerous facilities for expansion. Thus, for example, it is possible to expand bays in each of the remote stations and to link the devices on the bay level necessary for protection and control via Profibus or IEC 60 870-5-103 to the existing PCC. Additional devices can also be connected to the control room PCC. For expansion of a complete remote station, it is possible for example to use a further Device Interface Processor as SICAM PCC, to which in turn devices on the bay level are connected. For expansion of the operating and monitoring function, it is possible, instead of the Single-User WinCC System, to use for example a WinCC Client Server System with several operator terminals. This system offers redundancy as an option.


Local and Remote Control Device Dimensions

1

6MB5515 Side view 251

Front view 37.4

482.6 84 E = 426.72

Rear view 30

2

57.15 133.35

57.15 SV

…

BA BA BF

AE AR DE DE

FP/LPII RK RK SC

6 U = 266.7

7

182

3

11 465.1

4

All dimensions in mm. Fig. 214: Enhanced RTU 6MB551

5 6MB5540 Rear view

Side view

Front view

6

482.6 217 182

57.15 133.35

57.15 SV

…

BA BA

AE AR

FPI RK

…

7 Subrack

8

11

3 U m = 266.87

7

37.4

456.1 84 TE = 426.72

471.2

9

10 90

45

Connection board

One screw terminal block at top, one at bottom, per transducer module (two of each per module BF) All dimensions in mm. Fig. 215: SINAULT LSA COMPACT 6MB5540, basic frame


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1

6MB5130

2

172

29.5

Panel cutout

Rear view

Side view 37 39

7.3

225

13.2

220

7.3 13.2

180

3

5.4

ø 5 or M4 266

245

244

255.8

ø6

4

5

206.5

277.5

221

All dimensions in mm. Fig. 216: Compact central control unit 6MB513

6 6MB5140

29.5

Panel cutout

Rear view

Side view

7

172

37 39

7.3 13.2

450 445

7.3 13.2

431.5 405

5.4

8 ø5 266

255.8

245

9

ø6

277.5

10

446

All dimensions in mm. Fig. 217: Compact central control unit 6MB514

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6MB522

Side view 29.5

30

FSMA optical-fiber connector

Panel cutout

Rear view 7.3

220

1

206.5 180

5.4

4

2

ø 5 or M4 266

244

245

255.8

ø6 231.5 277


3

221

225

Fig. 218: Compact input/output device 6MB522

6MB523

4 Panel cutout

Side view

Front view 145

30

29.5

7.3

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131.5 105

ø6 ø5 244

6

245

255.8

7 160


231.5

146

5.4

Fig. 219: Compact input/output device 6MB523

8 6MB524-0, 1, 2

Rear view

Side view 29.5

172

30

225 220

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7.3 13.2 8 7 6 5

266

FE D C

244


Terminal blocks

Terminal blocks

Panel cutout

4 3 2 1

206.5±0.3 180±0.5

9

5.4

ø 5 or M4 BA

Optical-fiber sockets

255.8±0.3

245+1

ø6 221+2

Fig. 220: Compact I/0 unit with local (bay) control 6MB524-0,1,2


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6MB5240-3, -4

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Side view

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Panel cutout 450

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445 8 7 6 5

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244

ML K J H G F E

4 Terminal block

Terminal block

431±0.3 405±0.5

7.3 13.2

4 3 2 1

5.4

255.8±0.3

245+1

D C BA

ø5 ø6

Optical-fiber sockets

446+2


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Fig. 221: Compact I/0 unit with local (bay) control, extended version 6MB5240-3

6MB525

6 Side view 29.5

Rear view 172

37

75 70

7

Panel cutout 7.3

71+2

56.5±0.3

ø5 or M4

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266

255.8±0.3

245+1

244

Terminal block

ø6

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Case for 6MD631/632/633/634/637

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Panel cutout

Rear view

172/6.77

29.5 1.16

34 1.33

221/8.70

225/8.85 220/8.66

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244/9.61

266/10.47

FO SUB-D Connector

2 0.07

3

255.8/ 10.07

ø 6/0.24 diameter

4 RS232port

180/7.08 206.5/8.12

Mounting plate

5

Fig. 223: 6MD63 in 1/2 flush-mounting case for surface mounting with detachable operator panel

Case for 6MD63

6 Side view 29.5 27.1 1.16 1.06

Side view

Rear view Mounting plate

450/17.71 445/17.51

Rear view 225/8.85 220/8.66

29 30 202.5/7.97 1.14 1.18

7

8 266/ 10.47 2 0.07

246.2/ 9.69

266/ 10.47

312/12.28 244/9.61 FO

9 RS232port

Connection cable 68 poles to basic unit length 2.5 m/ 8 ft., 2.4 in

Detached operator panel

Mounting plate 1M case

SUB-D Connector 1/2

10

case1)

1) applicable to 6MD631/632/633/634/637 1) applicable to 6MD635/636

Fig. 224: 6MD63 in 1/2 and 1/1 surface mounting case (only with detached operator panel, see Fig. 42, page 6/21)


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6MB552

172

29.5

Panel cutout

Rear view

Side view

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206.5 ±0.3 180 ±0.5

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13.2

5.4

3 Bus cover 266

ø 5 or M4 1)

BNC socket for antenna

244

4

2)

255.8 ±0.3

245+1

ø6

Optical-fiber socket FSMA for connection of bay units

221+2

225

5 All dimensions in mm.

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Fig. 225: Compact RTU 6MB552 in 7XP20 housing

6MB5530-0 and -1

8

300

Rear view

Side view

Front view 1.5

200

20

Wall mount 18

A

20 35

9

20

8

20

8.2

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400

10

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Section A-A

45 15

225

A

Cable bushing

All dimensions in mm. Fig. 226: Minicompact RTU 6MB5530

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Power Quality Measuring, Recording, Compensation

Introduction For more than 100 years, electrical energy has been a product, measured, for example, in kilowatt-hours, and its value was determined by the amount of energy supplied. In addition, the time of day could be considered in the price calculation (cheap night current, expensive peak time tariffs) and agreements could be made on the maximum and minimum power consumption within defined periods. The latest development shows an increased tendency to include the aspect of voltage quality into the purchase orders and cost calculations. Previously, the term “quality” was associated mainly with the reliable availability of energy and the prevention of major deviations from the rated voltage. Over the last few years, however, the term of voltage quality has gained a completely new significance. On the one hand, devices have become more and more sensitive and depend on the adherence to certain limit values in voltage, frequency and waveshape; on the other hand, these quantities are increasingly affected by extreme load variations (e.g. in steelworks) and non-linear consumers (electronic devices, fluorescent lamps). Power Quality standards The specific characteristics of supply voltage have been defined in standards which are used to determine the level of quality with reference to ■ frequency ■ voltage level ■ waveshape ■ symmetry of the three phase voltages. These characteristics are permanently influenced by accidental changes resulting from load variations, disturbances from other machines and by the occurrence of insulation faults. In contrast to usual commodity trade, the quality of voltage depends not only on the individual supplier but, to an even larger degree, on the customers.

The IEC series 1000 and the standards IEEE 519 and EN 50160 describe the compatibility level required by equipment connected to the network, as well as the limits of emissions from these devices. This requires the use of suitable measuring instruments in order to verify compliance with the limits defined for the individual characteristics as laid down in the relevant standards. If these limit values are exceeded, the polluter may be requested to provide for corrective action.

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3 Competitive advantage though power quality In addition to the requirements stated in standards, the liberalization of the energy markets forces the utilities to make themselves stand out against their competitors, to offer energy at lower prices and to take cost-saving measures. These demands result in the following consequences for the supplier: ■ The energy tariffs will have to reflect the quality supplied. ■ Customers polluting the network with negative effects on power quality will have to expect higher power rates – “polluter-must-pay” principle. ■ Cost saving through network planning and distribution is different from today’s practice in network systems, which is oriented towards the customers with the highest power requirements. The significant aspect for the customer is that non-satisfying quality and availability of power supply may cause production losses resulting in high costs or leading to poor product quality. Examples are in particular ■ Semiconductor industry ■ Paper industry ■ Automotive industry (welding processes) ■ Industries with high energy requirements Siemens offers a wide range of products including different types of recording equipment, as well as systems for active quality improvement.

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Power Quality Measuring and Recording

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The SIMEAS T Measuring Transducer SIMEAS T is a new generation of measuring transducers for quantities present in electrical power supply systems. The compact housings are mounted to a standard rail with the help of a snap-on mechanism. Depending on the specific application, the devices are available with or without auxiliary power supply or can be provided with a multi-purpose measuring transducer which can be configured according to individual requirements.

Block diagram

UH

RS 232 RS 485

Digital output

IL1 Analog output 1 IL2 IL3 Analog output 2

Applications

UL1

■ Electrical isolation and conditioning

UL2

of electrical measurands for further processing. ■ Industrial plants, power plants and substations. ■ Easy-to-instal, space-saving device.

Serial interface

UL3 N

Analog output 3

AC

Fig. 227: Measuring transducer 7KG60, block diagram

5

Front view

6 75

7 Fig. 228: Measuring transducer 7KG60

8

90 Side view Connection terminals

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90 105 All dimensions in mm Fig. 229: Measuring transducer 7KG60, dimensions

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Functions

Outputs

Serial interface

Conversion of the measured values into analog or digital values suitable for systems in the fields of automatic control, energy optimization and operational control.

■ 3 isolated outputs for ± 20 mA or ± 10 V

Standard-type RS 232 C (V.28) interface for connection to a personal computer for configuration, calibration and transfer of the measured values; an RS 485-type serial interface is available with an additional bus function according to IEC 60 870-5-103.

Special features ■ Minimum dimensions, ■ Short delivery time, standard types

delivered ex-warehouse, Complies with all relevant standards, High-capacity output signals, Electrical isolation at high test voltage, Suitable to extend the beginning and end of the measuring range, ■ Design variants for true r.m.s measurement. Additional features of the multi-purpose measuring transducers: ■ Acquisition of up to 16 measurands, ■ Connection to any type of single-phase or three-phase systems, 16 2/3, 50, 60 Hz, ■ 3 electrically isolated outputs, ± 10 V and ± 20 mA, ■ 1 binary output, ■ Type of network, measurand, measuring range, etc. can be freely programmed, ■ V.28 or RS 485 serial interface for configuration and output of the measured values. ■ ■ ■ ■

and smaller values, ■ 1 contact, definable for error or limit indication or as energy pulse, ■ 1 serial interface type RS 232C (V.28) or, as an option, type RS 485 for connection to a personal computer for configuration and data transmission.

Two versions: 24 to 60 V DC and 110 to 250 V DC, as well as 100 to 230 V AC.

■ Single-phase, ■ Three-wire three-phase current with

Characteristic line with breakpoint

■ ■ ■ ■

Measured and calculated quantities ■ R.m.s. values of the line-to-line and star ■ ■ ■ ■ ■

Measurands ■ AC voltage, ■ AC current, ■ Extension of the measuring range is

possible. Additional features of the multi-purpose measuring transducer: ■ AC voltage and current, ■ Active, reactive and apparent power, power factor, phase angle, ■ System frequency, ■ Energy pulses, ■ Limit-value monitoring. Special features of the parameterizable multi-purpose measuring transducer Input quantities ■ 3 voltage inputs for 0 –346 V, up to 600 V

line-to-line voltage in the three-phase system, ■ 3 current inputs for 0–10 A.

2

Auxiliary power

Types of connection

constant/balanced load, Three-wire three-phase current with any load, Four-wire three-phase current with constant/balanced load, Four-wire three-phase current with any load, Connected either directly or via external transformer.

■ ■

■

■ ■

voltages, R.m.s. value of the zero sequence voltage, R.m.s. value of the line-to-line currents, R.m.s. value of the zero sequence current, Active and reactive power of the single phases and the sum thereof, Power factors of the single phases and the sum thereof, Total apparent power, Active energy, incoming supply at the single phases and the sum thereof (pulses), Active energy, exported supply at the single phases and the sum thereof (pulses), Reactive energy, inductive, at the single phases and the sum thereof (pulses), Reactive energy, capacitive, at the single phases and the sum thereof (pulses), Line frequency.

Alarm contact ■ Violation of the min./max. limits for

voltage, current, active power, reactive power, frequency, ■ Violation of the min. limit for power factor, ■ Functional error.


1

The start and end periods of the analog outputs can be extended according to requirements. This enables enlarging of the display of the operating range of voltages, while the less interesting overcurrent range can be compressed.

3

4

Configuration and adjustment With the help of a personal computer connected to the serial interface, the type of network, the measurands and the output signals can be configured to suit the individual situation. The SIMEAS PAR software program enables easy adjustment of the devices to different requirements. Since only one type needs to be kept on stock, the user can benefit from the advantages of reduced storage costs and easier project planning and ordering procedures. The software also supports and facilitates the adjustment of the transducers.

5

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7

Data output with SIMEAS T PAR SIMEAS T PAR can also be used to continuously collect the data of 12 measurands from the transducer and to display them both graphically and numerically on the screen. These data can then be saved or printed.

8

Bus operation with IEC protocol The transducer is suitable for the acquisition of up to 43 measurands and for the monitoring of up to 39 measurands. With three analog outputs and one contact output only part of these data can be transferred. With the help of the RS 485 serial interface which uses the IEC 60 870-5-103 protocol, however, any number of measured data can be transmitted to a central unit (e.g. LSA or PC). As this protocol restricts the number of data units to 9 or 16 measuring points, the function parameters for file transfer can be assigned in such a way as to bypass this restriction and to load any desired number of data.

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SIMEAS T PAR parameterization software Description By means of the SIMEAS T PAR software, SIMEAS T transducers with an RS232 or an RS485 interface can be parameterized or calibrated swiftly and easily. Measured quantities can be displayed on the PC online via a graphical meter or can be recorded and stored over a period of up to one week. SIMEAS T PAR was designed for installation on a commercially available PC or laptop with the MS-DOS operating system. It is operated via the MS-Windows V3.1 or Windows 95 graphical user interface by PC mouse and keyboard. Operating instructions can be created by printing the ”Help“ file. Communication with the transducer is achieved by means of a cable (optionally available) connected via the interface that is available on every PC or laptop. For units featuring an RS232 interface, use the connecting cable 7KG6051-8BA or, for units featuring an RS485 interface, use the converter 7KG6051-8EB/EC. Three mutually independent program sections can be called up.

Fig. 230: Parameterization of the basic parameters

Fig. 231: Parameterization of the binary output

Fig. 232: Parameterization of an analog output

Fig. 233: Calibrating an analog output

Parameterization

Features

Calibration

Parameterization serves to set the transducer to the required measured quantities, measuring ranges and output signals etc. Users are able to parameterize the transducer themselves in only a few steps. Entry of the data in the windows provided is clear and simple, supported with ”Help“ windows. Parameterization is also possible without the transducer. After storage of the data under a separate name, the transducers can be adjusted with the ”Send file“ command. They can also be reparameterized online during operation.

■ Extremely simple and straightforward

As the transducer features neither setting potentiometers nor other hardware controls, it is calibrated easily by means of the SIMEAS T PARA software, by selection of the ”Calibrate“ function. Generally, all the transducers are already calibrated and factory-set when delivered. Recalibration of the transducers is normally only necessary after repairs or in the event of readjustment. It goes without saying that the windows and graphical characteristics displayed in the ”Calibrate“ program can be operated with ease. Here also, the test setup and explanations of how to operate the programm are provided in ”Help“ windows.

■

■ ■

■

9 ■

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10 ■

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operation Storage of parameterization data under a user-defined name even without the transducer Parameters are sent to transducers even after installation on the site When ”Receive“ is selected, the transducer‘s parameters are read into the ”Parameterization window“, can be modified and can be sent back by selecting ”Send“ Entered data is subjected to an extensive plausibility check and a message and ”Help“ are displayed in the event of invalid inputs A parameterization list with the specific connection diagram of the transducer can be printed A self-adhesive data plate can be printed and affixed to the transducer, including a possibility of entering three lines of text containing the name and location etc. When units featuring an RS485 interface are chosen, an additional window is available for entry of the bus parameters

Features ■ Sealed for life design ■ Calibration without tools or special

devices ■ No test field environment is needed

Current inputs, voltage inputs and the individual analog outputs can be calibrated independently of one another.



Reading out data

Fig. 234: Measured value display with 3 measured quantities

Fig. 235: Measured value display with 6 measured quantities

With graphical instruments, all measured quantities calculated in the transducer and power quantities can be displayed online on a PC or laptop, and either in analog form or digitally. To improve the resolution of the graphics, users can freely choose the number of instruments on the screen and can freely assign the measured quantity and measuring range. These are selected and assigned independently of the unit’s analog outputs. Displayed measured values can be stored, printed or recorded for the EVAL evaluation software. Features ■ Online measurements in the system

1

2

3

4

with high accuracy ■ The meters for the 3 analog outputs

■

■ ■ ■ ■

with the appropiate measuring range appear automatically when the program part is called up Easy addition or modification of meters with measured quantity and measuring range Selection of measured quantities independently of the analog outputs Storage of the layout under a file name Printing of the instantaneous values of the displayed measured quantities Recording and storage of measured values for the EVAL evaluation software

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SIMEAS EVAL evaluation software Fig. 236: SIMEAS EVAL, overview recorded values

Description With a PC or a notebook with the SIMEAS T PAR software installed on it, up to 25 measured quantities can be displayed and recorded online with the SIMEAS T digital transducer. A maximum of one week can be recorded. Every second, one complete set of measured values is recorded with time information. The complete recording can then be saved under a chosen name. Using the SIMEAS EVAL evaluation software, the stored values can then be edited, evaluated and printed in the form of a graphic or a table (Figs. 236 to 238).

Fig. 237: After setting cursors in the overview, the affiliated measurements and times are displayed in the table


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1

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SIMEAS EVAL is a typical Windows program, i.e. it is completely Windows-oriented and all functions can be operated with the mouse or keyboard. SIMEAS EVAL is installed together with SIMEAS T PAR and is started by double clicking on the EVAL icon. A window containing the series of measurements recorded by SIMEAS T PAR is displayed for selection. Features

3

4

■ ■ ■ ■

■ ■ ■

5 ■ ■

6

■ ■ ■

7 ■

Automatic diagram marking Graphic or tabular representation Sampling frequency: 1 s A measured value from the table can be dragged to the graphic by simply right-clicking it Add your own text to graphics Select measured quantities and the measuring range Easy zooming with automatic adaption of the diagram captions on the X and Y axes Up to 8 cursors can be set or moved anywhere Tabular online display of the chosen cursor positions with values and times Characteristics can be placed over one another for improved analysis The sequence of displayed measured quantities can be selected and modified The complete recording or edited graphic can be printed, including a possibility of selecting the number of curves on each sheet The table can be printed with measured values and times pertaining to the cursor positions.

8 Information for SIMEAS T Project Planning

9

The transducer is suitable for low-voltage applications, 400 V three-phase and 230 V single-phase voltages, (max. measuring 600 L-L) and currents of 1, 5, 10 A (max. measurement 12 Ar.m.s), either directly or via current transformers, as well as for connection to voltage transformers of

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Fig. 238: When a cursor is moved by the mouse, the measured values and times in the table are adapted automatically

—

—

—

1000√ 3, 110√ 3, 200√ 3. The devices can be pre-configured at the factory according to customer requirements or configuration can be performed by the customer himself. The latter possibility facilitates and considerably reduces the customer’s expense for storage and spare parts service. All usual variants of connection (two, three or fourwire systems, constant/balanced or any/ unbalanced load 16 2/3, 50, 60 Hz) can be configured according to individual requirements. Please note that two different types are available which differ in their types of interface: V.28 (RS 232C) and RS 458. The standard interface (V.28) is used for configuration. It enables loading of the measured values to a personal computer, whereby only one transducer can be connected to a computer. Both versions are operated with the SIMEAS PAR software. The RS 485 enables connection to a bus, i.e. up to 31 transducers can be connected to a central device (e.g. PC) simultaneously. Data transmission is based on IEC 60 870-5-103 protocol. The type of power supply is to be specified when ordering, either 24..60 V DC or 100..230 V AC/DC. Please note that analog output 1 and the serial interface use the same potential and can be operated simultaneously only under certain conditions.



SIMEAS P

Power Meter SIMEAS P

Front view SIMEAS P

96 (3.78")

The SIMEAS P power meter is suitable for panel mounting. The digital multi-function display can replace any measuring devices usually required for a three-phase feeder. Furthermore, it offers a variety of additional functions. The optional equipment with a PROFIBUS enables centralized access to the measured values.

1

2

Application All systems used for the generation and distribution of electrical power. The device can be easily installed for stationary use.

96 (3.78")

3

Functions Measuring instrument for all relevant measurands of a feeder. Combination of several measuring instruments in one unit.

Side view

4

Special features

86 (3.39")

Dimensions for panel mounting according to DIN (front frame 96 x 96 mm). Integrated PROFIBUS as optional equipment. Data output is effected via the Profibus.

5

Measuring inputs ■ 3 voltage inputs up to 347 V (L-E), 600 V

162.2 (6.39")

(L-L), ■ 3 current inputs for 5 A rated current, measuring range up to 10 A with an overload of 25%.

7

Communication Fig. 239: Power Meter SIMEAS P, views and dimensions

6

■ LCD display with background illumina-

tion, ■ Simultaneous display of four measuring

values, ■ Parameter assignment by using the keys

on the front panel, ■ 1 serial interface type RS 485 for connection to the Profibus (option).

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Auxiliary power

1

Two versions: 24 to 60 V DC and 85 to 240 V AC/DC.

SIMEAS P

Measured and calculated quantities ■ R.m.s. values of the line-to-ground or

2

3

line-to-line voltages and the mean value,

■ ■ ■

■

4

■

■ ■

5

SHORTING BLOCK or TEST BLOCK

■ R.m.s. values of the line-to-line currents

and the mean value, Line frequency, Power factor (incl. sign), Active, reactive and apparent power, separately for each phase and as a whole, imported supply, Total harmonic distortion (THD) for voltage and currents, separately for each phase, up to the 15th harmonic order, Unbalanced voltage and current, Active and reactive power (import, export), total sum, difference, Apparent power, total sum, Minimum and maximum values of most quantities.

Barrier-type terminals (ring or spade connectors)

PROFIBUS DE PWR

Thumbscrew

Chassis ground AWG 14 (2.5 mm)

V

V

V

V N–

Basic Function

L+

G

Captured-wire terminals

Display of the measured quantities and transfer to the Profibus.

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10

Fuses 2 Amp

Information for Project Planning The SIMEAS P can be delivered in different designs varying with regard to the measuring voltage, auxiliary voltage, line frequency and type of terminals. It is always designed for four-wire connection at any load. The measuring voltages are: ■ 120 V, 277 V, 347 V L-N for screw clamps, up to max. 277 V for selfclamping contacts. ■ The basic rated current value is 5 A; fully controlled it is 10 A. Two variants are to be considered for the auxiliary voltage: standard version and 85–240 V AC/DC and, as an option 20–60 V DC. The standard version of the device can be used only for the display of the different measurands. Communication with a centralized system is possible only in connection with the Profibus which can be ordered as optional equipment.

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Power supply connections, phase voltage and current connections, and fuse, CT and PT details depend on the configuration of the power system.

Phase voltage and power supply connections: AWG 12 to AWG 14 (2.5 mm to 4.0 mm)

Fig. 240: Power Meter SIMEAS P, back panel diagram



The SIMEAS Q Quality Recorder

Front view

1

SIMEAS Q is a measuring and recording device which enables monitoring of all characteristics related to the voltage quality in three-phase systems according to the specifications defined in the standards EN 50160 and IEC 61000. It is mounted on a standard rail with the help of a snap-on mechanism.

20 21 22 23 24 25

PROFIBUS-DP

RUN BF DIA

SIMEAS Q 7KG-8000-8AB/BB

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4

75 5

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Application Medium and low-voltage systems. The device requires only little space and can be easily installed for stationary use. Functions Instrument for network quality measurement. All relevant measurands and operands are continuously recorded at freely definable intervals or, if a limit value is violated, the values are averaged. This enables the registration of all characteristics of voltage quality according to the relevant standards. The measured values can be automatically transferred to a central computer system at freely definable intervals via a standardized PROFIBUS DP interface and at a transmission rate of up to 1.5 Mbit/s. Special features ■ Cost-effective solution. ■ Comprehensive measuring functions

which can also be used in the field of automatic control engineering. ■ Minimum dimensions. ■ Integrated PROFIBUS DP. ■ The integrated clock can be synchronized via the PROFIBUS. Configuration and data output via PROFIBUS DP.

Fig. 241: The SIMEAS Q quality recorder

Communication

Side view

■ 2 optorelays as signaling output, availa-

Terminal block

ble either for – device in operation, – energy pulse, – signaling the direction of energy flow (import, export), – value below min. limit for cos ϕ, – pulse indicating a voltage dip, ■ 3 LEDs indicating the operating status and PROFIBUS activity, ■ 1 RS 485 serial interface for connection to the PROFIBUS.

4

5

90 105

Auxiliary power Two versions: 24 to 60 V DC and 110 to 250 V DC, as well as 100 to 230 V AC.

6

Connection terminals

Measured and calculated quantities

20 21 22 23 24 25

■ R.m.s. values of the line-to-ground or ■ ■ ■

Measuring inputs 3 voltage inputs, 0 – 280 V, 3 current inputs, 0 – 6 A.

3

90

■ ■ ■ ■

line-to-line voltages, R.m.s. values of the line-to-line currents, Line frequency (from the first voltage input), Active, reactive and apparent power, separately for each phase and as a whole, Harmonics for voltages and currents up to the 40th order, Total harmonic distortion (THD), voltages and currents of each phase, Unbalanced voltage and current in the three-phase system, Flicker irritability factor.

7 Aux. Volt.

PROFIBUS-DP

SIMEAS Q 7KG-8000-8AB/BB

Input: Current AC

8

Input: Volt. AC

IL1 IL1 IL2 IL2 IL3 IL3 ULN UL1 UL2 UL3 1

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10

All dimensions in mm

9

Fig. 242: The SIMEAS Q quality recorder, dimension drawings

Averaging intervals

10

■ Voltages and currents from 10 ms to

60 min., ■ Other quantities from 1s to 60 min.


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Operating modes

1

■ Continuous measurement with definable

Single phase – alternating current

averaging intervals, ■ Event-controlled measurement with definable averaging intervals.

1

Storage capacity

2

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10

Up to 20,000 measured and calculated values. Parameters for the measuring points can be freely defined. The PROFIBUS DP enables quick loading of the measured values, so that the apparently small storage capacity is absolutely sufficient. Assuming a usual parameter setting with regard to the measuring points and averaging intervals for quality monitoring, the storage capacity will last for seven days in case of a PROFIBUS failure.

k L1 N

Information for SIMEAS Q Project Planning Up to 400 V (L-L), the device is connected directly, or, if higher voltages are applied, via a external transformer. The rated current values are 1 and 5 A (max. 6 A can be measured) without switchover. Communication with the device is effected via PROFIBUS DP or, as an option, via modem (telephone network). Auxiliary voltage is available in two variants: 24 to 60 V DC and 110 to 250 V DC or 100 to 230 V AC.

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l L

K

4-wire – 3-phase with any load (low voltage network)

1

Basic Functions In the course of continuous measurement, the selected measuring data are stored in the memory or transferred directly via the PROFIBUS. The averaging interval can be selected separately for the different measurands. In the event-controlled mode of operation, the data will be stored only if a limit value has been violated within an averaging interval. Apart from the mean values, the maximum and minimum values within an averaging interval can be stored, with the exception of flicker irritability factors and the values from energy measurement. Parameter assignment and adjustment of the device are performed via the Profibus interface.

Connection terminals SIMEAS Q 3 4 5 6 7

2

k L1 L2 L3 N

2


l

K

k

l

k

l

L K

L K

L

3-wires – 3-phase with any load

1 k

L1 L2 L3

2


l

K

k

l

u

v

u

v

U

V

U

V

L K

L

4-wire – 3-phase with any load (high voltage network)

1 k

L1 L2 L3 N

K

2


l

k

l

k

8

9

10

u

u

u

X

X

X

U

U

U

l

L K

L K

L

Fig. 243: SIMEAS Q connection terminals

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The SIMEAS N Quality Recorder SIMEAS N is a measuring and recording device which is used to monitor all characteristics referring to the voltage quality in three-phase systems in compliance with the requirements stated in the EN 50160 and IEC 1000 Standards. Application Medium and low-voltage systems, laboratories, test bays. Portable device for mobile use. Functions Device for network quality measurement. The measurands and operands are continuously recorded over definable intervals; in case of limit violations, the values will be averaged. This enables the recording of all characteristics relevant to voltage quality. In addition, this multi-purpose device can be used for general measurement tasks in the field of AC power engineering. Special features Comprehensive measuring functions. A lockable cover protects the terminals against accidental contact. The operator access can be password-protected. Clamp-on probes with an error correction function facilitate connection. A back-up battery stores the measured data in case of voltage failure. The integrated battery-backed real-time clock will be usable until the year 2097. Output of the measured values via integrated thermal printer, floppy disk or serial interface. Measuring inputs ■ 4 voltage inputs, 0–460 V, ■ 3 of these inputs with additional transient

acquisition ± 2650 Vpeak at a sampling rate of 2 MHz, ■ 4 voltage/current inputs, voltage 0–460 V/clamp-on probe or transducer.

Communication

Function

1 input for trigger signal, 1 contact as alarm output, 1 integrated thermal printer, 1 3.5" floppy disk drive, 1.44 MB for parameters and data storage, ■ 1 serial interface type RS 232C (V.24) for connection to a personal computer for configuration and data transmission.

Continuous measurement without storage roughly corresponds to the function of a multimeter. The selected values to be measured are continuously displayed and the whole screen content including the graphic illustrations can be printed on the integrated thermal printer by key command. This operating mode is used to check correct connection of the device and is suitable for general measurement tasks. Monitoring of the network quality is effected by continuously calculating and storing the mean values of the measured quantities. In the storage mode, the averaging interval can be configured individually from one period of the system voltage up to several months. Two types of storage modes can be selected, either linear mode (stops when the memory is full) or overwrite mode (the oldest data will be overwritten by the new information). With the help of the OSCOP Q program, the measuring data can be transmitted to a personal computer for detailed analysis.

■ ■ ■ ■

Measured and calculated quantities ■ R.m.s. values of voltages, AC, AC+DC,

DC, ■ Peak voltage values during transient

measurement, ■ R.m.s values of currents, AC, AC+DC,

■ ■ ■ ■ ■ ■ ■

■

DC (depending on transducer or clampon probes), Voltage dips and voltage cutoffs, Overvoltages, System frequency, Active, reactive and apparent power, 1- to 3 phases, Phase angle, Harmonics of voltages and currents up to the 50th order, Total harmonic distortion (THD), voltages and currents, unweighted or weighted inductively or capacitively, Unbalanced voltage and current in the three-phase system.

Connection types ■ Single phase, ■ Four-wire three-phase current.

Measurands and operands, available as an option ■ Direction of harmonics, ■ Flicker measurement, ■ Digital storage oscilloscope.

Operating modes ■ Continuous measurement with display

at one-second intervals, ■ Continuous measurement with data stor-

age, ■ Event-controlled measurement with data

storage. Storage capacity

2

3

4

5

Information for Project Planning The basic version of the device is fully capable of simultaneous acquisition of up to 55 measurands. The voltage range of 400 V +15% is suitable for connection to 400 V three-phase systems. Clamp-on probes (10, 100 and 1000 A) for current measurement are available. The connection of a transducer is possible, if a resistor provides a voltage drop of 1 V nominal value. The device can also be delivered for highspeed processing which enables simultaneous acquisition of up to 186 different measurands. Optional functions which can be added at a later date by software installation: ■ Power measurement of individual harmonics and their direction in order to identify the cause. ■ Extension of the device functions for use as an additional three-channel digital oscilloscope. ■ Flicker measurement according to IEC 60 868.

Up to 500,000 measured and calculated values; various options for defining the measuring points.

Fig. 244: SIMEAS N Quality Recorder


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Recording Equipment 1

The SIMEAS R Fault and Digital Recorder Application ■ Stand-alone stationary recorder for extra-

2

high, high and medium-voltage systems. ■ Component of secondary equipment of

power stations and substations or industrial plants. Functions

3

4

Fault recorder, digital recorder, frequency/ power fault recorder, power quality recorder, event recorder. All functions can be performed simultaneously and are combined in one unit with no need for additional devices to carry out the different tasks.

Fig. 245: SIMEAS R Systems are used in power plants …

Special features Fig. 247: Fault record

■ The modular design enables the realiza-

5

6

tion of different variants starting from systems with 8 analog and 16 binary inputs up to the acquisition of data from any number of analog and binary channels. ■ Clock with time synchronization using GPS or DCF77. ■ Data output via postscript printer, remote data transmission with a modem via the telephone line, connection to LAN and WAN.

Fig. 246: … and to monitor transmission lines

7 Fault Recording (DFR) This function is used for the continuous monitoring of the AC voltages and currents, binary signals and direct voltages or currents with a high time resolution. If a fault event, e.g. a short-circuit, occurs, the specific fault will be registered including its history. The recorded data are then archived and can either be printed directly in the form of graphics or be transferred to a diagnosis system which can, for example, be used to identify the fault location.

8

9

Fault detection is effected with the help of trigger functions. With analog quantities this refers to ■ exceeding the limit values for voltage, current and unbalanced load (positive and negative phase sequence system). ■ falling below the limit values for voltage, current and unbalanced load (positive and negative phase sequence system). ■ limit values for sudden changes in up or downward direction. Monitoring of the binary signals includes ■ signal status (high, low) ■ status changes

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Logical triggers Logical triggers can be defined by combining any types of trigger event (analog or binary). They are used to avoid undesired recording by increasing the selectivity of the trigger function. The device can distinguish between different causes of a fault, e.g. between a voltage dip caused by a short-circuit (low voltage, high current) which needs to be recorded, and the disconnection of a feeder (voltage low, current low) which does not need to be recorded. Sequential control An intelligent logic operation is used to make sure that each record refers to the actual duration of the fault event. This is to prevent continuous violation of a limit value (e.g. undervoltage) from causing permanent recording and blocking of the device. Analog measurands 16-bit resolution for voltages and DC quantities and 2 x 16-bit resolution for AC voltages. The sampling frequency is 256 times the period length, i.e. 12.8 kHz at 50 Hz and 15.36 kHz at 60 Hz for each channel. A new current transformer concept enables a measuring range between 0.5 mA and 400 A r.m.s. with tolerances of <0.2% at <7 Ar.m.s. and <1% at >7 Ar.m.s. Furthermore, direct current is registered in the range above 7 A; this enables a true image of the transient DC component in the short-circuit current.

In single-phase and three-phase systems, the following measurands are recorded: ■ R.m.s. values of voltages and currents ■ Active power, phase-segregated and overall ■ Reactive power, phase-segregated and overall (displacement or total reactive power) ■ Power factor, phase-segregated and overall ■ Frequency ■ Positive and negative sequence voltage and current ■ Weighted and unweighted total harmonic distortion (THD) ■ 5 th to 50 th harmonics (depending on the averaging time) ■ DC signals, e.g. from transducers Depending on the individual network configuration, a three or four-wire connection is used. Frequency/Power Recording (FPR)

Sequence of Event (SOE) Recording Each status change occurring at the binary inputs is registered with a resolution of 0.5 ms and is then provided with a time stamp indicating the time information from the year down to the millisecond. 200 status changes per second can be stored for each group of 32 inputs. The mass memory of the device can be configured according to requirements (a 5 MB memory, for example, enables the storage of approx. 120,000 status changes). Modules for signal voltages between 24 and 250 V are available. The time-synchronous output enables the combined representation with analog curves, e.g. of alarm and command signals together with the course of relay voltages and currents. With the help of the OSCOP P program, the event signals can however also be displayed in the form of a text list in chronological order. The use of a separate sequence of event recorder will no longer be required.

This function uses the same principle as a fault recorder. It continuously monitors the gradient of the frequency and/or power of one or more three-phase feeders. If major deviations are detected, e.g. caused by the outage of a power plant or when great loads are applied, the profile of the measurands will be recorded including their history. The recorder is also used for the registration of power swings.

1

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3

4

5

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7

Measurands ■ Frequency of one of the voltages,

Binary signals The sampling frequency at the binary inputs is 2 kHz. Data compression

(limit of error ± 1 mHz)

■ Active power, reactive power

(reactive displacement power), (limit of error ≤ 0.2%) ■ Power factor

For best utilization of the memory space and for high-speed remote transmission the data can be compressed to as little as 2% of their original size.

Averaging interval

Fault diagnosis

History

Performed with the OSCOP P software package.

Depends on the averaging interval; 10 s times the averaging periods.

A value between 1 and 250 periods of the network frequency can be selected.

8 Fig. 248: SIMEAS R for 8 analog and 16 binary inputs, 1 /2 19'' design

9

10

Automatic power analysis Digital Recording (DR) This function is used for the continuous registration of the mean values of the measurands at intervals which can be freely defined (min. interval is one period). The main function of this device is the continuous recording of quantities at the feeders and to make these values available for the analysis of the network quality.

With the help of the OSCOP software package (see The OSCOP P) a power analysis of a station can be created automatically.


6/143


The OSCOP P Evaluation Program

1

2

3

4

5

6

The OSCOP P software package is suitable for use in personal computers provided with the operating systems MS WINDOWS 95/98 or WINDOWS NT. It is used for remote transmission, evaluation and archiving (database system) of the data received from a SIMEAS R or OSCILLOSTORE and from digital protection devices. The program includes a parameterization function for remote configuration of SIMEAS R and OSCILLOSTORE units. The program enables fully-automated data transmission of all recorded events from the acquisition units to one or more evaluation stations via dedicated line, switched line or a network; the received data can then be immediately displayed on a monitor and/or printed (Fig. 249). The OSCOP P program is provided with a very convenient graphical evaluation program for the creation of a time diagram with the curve profiles, diagrams of the r.m.s. values or vector diagrams (Fig. 252).

The individual diagrams can, of course, be adjusted to individual requirements with the help of variable scaling and zoom functions. Records from different devices can be combined in one diagram. The different quantities measured can be immediately calculated by marking a specific point in a diagram with the cursor (impedance, reactance, active and reactive power, harmonics, peak value, r.m.s. value, symmetry, etc.). Additional diagnosis modules can be used to perform an automatic analysis of fault events and to identify the fault location. The program also supports server/client structures.

Load Dispatch Center

The secondary components of high or medium-voltage systems can either be accommodated in a central relay room or in the feeder dedicated low-voltage compartments of switchgear panels. For this reason, the SIMEAS R system has been designed in such a way as to allow both centralized or decentralized installation. The acquisition unit can be delivered in two different widths, either 1/2 19" or 19" (full width). The first version is favorable if measurands of only one feeder are to be considered (8 analog and 16 binary signals). This often applies to high-voltage plants where each feeder is provided with an extra relay kiosk for the secondary equipment. In all other cases, the full-width version of 19" is more economical, since it enables the processing of up to 32 analog and 64 binary signals. The modular structure with a variety of interface modules (DAUs) provides a maximum of flexibility. The number of DAUs which can be integrated in the acquisition system is unlimited.

Office

RMS values + diagnostic

7

Information for Project Planning with SIMEAS R

Spontaneous print

Spontaneous print

Containerized Data Base

WAN ISDN X.25 Telephone

8

Evaluation

Office LAN

Station Level

Decentralized Data Base Configuration

9

Configuration

Evaluation

Diagnostic system

DAKON

Data compression

Printer

Remote control, automatic mode

10

Stations LAN

Bay Level

SIMEAS R 8 analog/ 16 binary inputs

Fig. 249: Example of a distributed recording system realized with SIMEAS R recorders and data central unit DAKON

6/144



With the help of a DAKON, several devices can be interlinked and automatically controlled. In addition, digital protection devices of different make can be connected to the DAKON. The voltage inputs are designed for direct connection to low-voltage networks or to low-voltage transformers. Current inputs are suitable for direct connection to current transformers (IN = 1 or 5 A). All inputs comply with the relevant requirements for protection devices acc. to IEC 60 255. The binary inputs are connected to floating contacts. Data transmission is preferably effected via telephone network or WAN (Wide Area Network). If more than one SIMEAS R is installed, we recommend the use of a DAKON (data concentrator). The DAKON creates connection with the OSCOP P evaluation program, e.g. via the telephone network. Moreover, the DAKON automatically collects all information registered by the devices connected and stores these data on a decentralized basis, e.g. in the substation. The DAKON performs a great variety of different functions, e.g. it supports the automatic fax transmission of the data. A database management system distributes the recorded data to different stations either automatically or on special command.

Use of the interface modules

1

DAU Type

Measurands

Application

VCDAU

4 AC voltages, 4 AC currents, 16 binary signals

Monitoring of voltages and currents of three-phase feeders or transformers including the signals from protective equipment. All recorder functions can be run simultaneously.

2

VDAU

8 AC voltages, 16 binary signals

Monitoring of busbar voltages

3

CDAU

8 AC currents, 16 binary signals

Monitoring of feeder and transformer currents or currents at the infeeds and couplings of busbars

DDAU

8 DC currents or 16 binary signals

For monitoring of quantities received from measuring transducers and telecontrol units, 20 mA or 1 and 10 V.

BDAU

16 binary signals

Event recording of alarm signals, disconnector status signals, circuit-breaker monitoring

4

5

Fig. 251: Use of the data acquisition units

6

7

8

9 Fig. 250: Rear view of a SIMEAS R unit with terminals for the signals and interfaces for data transmission

10 Fig. 252: OSCOP P Program, evaluation of a fault record


6/145

Compensation – Introduction Power Quality

Compensations Systems 1

2

3

4

5

6

7

8

Many consumers of electrical energy (transformers, engines, fluorescent lamps) may cause a number of different problems: reactive displacement power, non-linear loads (rectifiers, transformers), resulting in distorted waveshapes. Harmonics are generated and, finally, an unbalanced load at the three phases leads to increased apparent power and thus to increased power consumption. This is accompanied by higher conduction losses, which require the installation of lines and operating equipment suitable for higher capacities and at higher costs than actually necessary. The cost for power rates in relation to the apparent power and distortion should also be considered. In many cases it is favorable to perform compensation of the undesired components. Siemens offers two different systems for the compensation of reactive power and of harmonics – SIPCON T and SIPCON DVR/ DSTATCOM – both suitable for three-phase LV systems up to a rated voltage of 690 V. The latter system is available in designs also capable of compensating short-term voltage dips and surges, as well as load unbalances. ■ SIPCON T Passive systems using switched capacitors or capacitors with permanent wiring. ■ SIPCON DVR / DSTATCOM Active systems using IGBT converters for quick and continuous operation. The use of SIPCON can enable energy suppliers worldwide to provide the end consumer with distinctive quality of supply. As it is now possible with this technology to supply ”Premium Energy“, an energy supplier can formulate differing tariffs for his product – electrical energy – so that he will stand out from his competitors.

9

For industry, especially in the case of complex manufacturing processes (such as for example in the semiconductor industry) ”Premium Energy“ is an absolute necessity. SIPCON is capable of effectively suppressing system perturbation, such as for example harmonics. Here as well, tariff changes are to be expected worldwide in the future. Investigations in Europe have shown that the increase in harmonics is imposing a particular strain on systems. Such harmonics occur through the operation of variable speed drives, of rectifiers – for example in electroplating – and of induction furnaces or wind power plants. In private houses, the principal loads are singlephase, such as TV sets and personal computers. With the aid of selective recording of weaknesses in the electrical system and subsequent use of the SIPCON Power Conditioner, it will be possible to improve system loading and to significantly rationalize the high capital investment necessary for system expansion.

Frequency of voltage dips [%] 30.00 25.00 20.00 15.00

Magnitude of voltage dip [%]

10.00

10 to 30 30 to 60 60 to 100 interruption 100

5.00 0.00

10 ms 100 ms 500 ms to 100 ms to 500 ms to 1 s

1s to 3 s

3s to 20 s

20 s to 60 s

Duration of voltage dips Fig. 253: Frequency and duration of voltage dips

10

Fig. 254: Active compensation system (Power Conditioner DSTATCOM)

6/146


Power Quality Passive Compensation – Power Factor Correction

The SIPCON T Passive Filters and Compensation Systems

Under unfavorable conditions, adherence to this rule may lead to a power factor smaller than 0.9. In this case, centralized correction should be performed additionally.

All consumers based on an electromagnetic operation principle (e.g. motors, transformers, fluorescent lamps with series reactors) require a lagging reactive power. This leads to an increase in the amount of apparent power and consequently in current. The supply of reactive power from the mains leads to additional load applied to the operating equipment which, as a result, needs to be configured for higher capacities than actually required. The higher current is accompanied by an increased power loss. However, the required reactive power can also be generated close to the consumer with the help of capacitors which prevent the above mentioned disadvantages. When selecting the capacity it is general practice to calculate with a power factor of 0.9 or higher. Compensation can be effected according to three different principles: individual correction, group correction and centralized correction.

Group Correction

Individual Correction This type of compensation is reasonable for consumers with high capacities, constant load and long operating times. (Fig. 255). ■ The capacitor is installed close to the operating equipment. The lower current flows already in the line from the busbar to the consumer. ■ The capacitor and the consumer are turned on and off together; an additional switch is not required. When selecting the type of capacitors please note that in the case of induction motors, the reactive power supplied by the capacitor must not exceed approx. 90% of the motor reactive power in idle operation. Otherwise, disconnection might cause selfexcitation by the resonance frequency, since the motor and the capacitor form a resonant circuit. This effect may lead to high overvoltages at the terminals and affect the insulation of the operating equipment. As a general rule, the following values should be considered for the capacitor: ■ Approx. 35% of the motor power at ≥ 40 kW, ■ Approx. 40% of the motor power from 20 to 39 kW, ■ Approx. 50% of the motor power at < 20 kW.

Individual correction

1

A group of consumers, e.g. motors or fluorescent lamps, operated by one common switch, can be compensated with one single capacitor (Fig. 256).

2

Centralized Correction The solution for correcting the power factor for a great number of small consumers with varying power consumption is a centralized compensation principle (Fig. 257) using switched capacitor modules and a controller. The low losses of the capacitors allows them to be integrated directly in the switchboards or distributors. A programmable controller is used to monitor the power factor and to switch the capacitors according to the reactive-power flow. The devices for group correction differ in their power and in their number of switching steps. For example, a unit with 250 kVA can be switched in steps of 50 kVA. We recommend the use of units suitable for switching between five and twelve steps.

3

M

Fig. 255: Individual correction

4 Group correction

5

6 M

M

M

7

Fig. 256: Group correction

Centralized correction

8

9

M

M

M

10

Controller

M

M

M

Fig. 257: Centralized correction


6/147

Power Quality Passive Compensation – Power Factor Control

1

The SIMEAS C Power Factor Controller

Q1 QC

Q2

2

P

S2

S1

ϕ1

ϕ2

3

Fig. 258: SIMEAS C Power Factor Controller

Fig. 259: Effect of compensation

4 Two examples

5

1 Uncompensated system, rated voltage 400 V Active power Pa Power factor cos ϕ1 Apparent power S1 Current I1

6

550 kW 0.6 920 kVA 1330 A

S1 =

Pa 550 kW = = 920 kVA cos ϕ1 0.6 S1

I1 =

√3 • U

=

920 kVA √3 • 400 V

= 1330 A

7 2 Compensated system, rated voltage 400 V Power factor cos ϕ2 Capacitor power QC Apparent power S2 Current I2

8

0.9 470 kvar 610 kVA 880 A

QC = Pa (tan ϕ1 – tan ϕ2)

S2 =

9 I2 =

Pa 550 kW = = 610 kVA 0.9 cos ϕ2 S2

√3 • U

=

610 kVA √3 • 400 V

= 880 A

10 The correction of the power factor from cos ϕ1 = 0.6 to cos ϕ2 = 0.9, results in a 34% reduction in apparent power transmitted. Line losses can be reduced by 56%.

S1 – S2 S1 I12 – I22 I12

=

0.34

=

0.56

The centralized correction principle is effected with the help of a controller. This unit is designed for panel mounting (front frame dimensions 144 x 144 mm according to DIN) in the door of the compensation equipment. It is connected to L1, L2 and L3 of the mains voltage; the current is taken from a current transformer in L1 rated 1 A or 5 A. All capacitor modules connected are switched stepwise in such a way as to enable best approximation to the setpoint value of the power factor. Defined waiting periods prevent excessive switching operations and ensure that the capacitor will be discharged properly before the next connection. Two setpoints (cos ϕ1 and cos ϕ2) can be specified separately to enable different modes for day and night time. Each capacitor module is operated by contactors which are controlled by means of six contacts. A further contact is used for error indication. One input for a floating contact is used to select one of the two setpoints for the power factor. Apart from the control function, the device also offers a great amount of information on the status of the supply system. It shows: ■ Setpoint cos ϕ1, ■ Setpoint cos ϕ2 (e.g. night operation), ■ Line current, ■ Voltages, ■ Active power in kW, ■ Apparent power in kVA, ■ Actual reactive power in kvar, ■ Deviation of the reactive power from the setpoint value, ■ Reactive power of the activated capacitors, ■ Harmonics of voltage U5, ■ Harmonics of voltage U7, ■ Harmonics of voltage U11, ■ Harmonics of current U5, ■ Harmonics of current U7, ■ Harmonics of current U11. A fiber-optic interface is accessible at the rear of the device. On request, a cable suitable for the conversion of optical pulses into RS 232C (V.2) signals can be supplied. This cable enables connection to a personal computer which can be used to program the controller and to read out parameters, as well as the measured values.

Fig. 260: Examples of power factor control

6/148


Power Quality Passive Compensation – Power Factor Control

Selecting the Capacitor Power When defining the capacitor power for a system, the active power P and the power factor cos ϕ1 of the system have to be considered. In order to upgrade cos ϕ1 to cos ϕ2, the following applies to the power QC of the capacitor:

QC = Pa·(tan ϕ1 – tan ϕ2) Fig. 261

The diagram in Fig. 259 shows how the apparent power S1 – caused by active power Pa and reactive power Q1 – is reduced to the value S2 by the capacitor power QC. When taking into account that the current is proportional to the apparent power, whereby the loss caused by the current increases by the power of two, the saving is remarkable. This result is possibly supported by a lower energy tariff to be paid. With systems in the planning stage we can assume that the reactive load is caused mainly by induction motors. These motors operate with an average power factor of ≥ 0.7. Increasing the power factor to 0.9 requires a capacitor power of approx. 50% of the active power. In present industrial plants, the required capacitor power can be determined on the basis of the energy bill, provided the plant is equipped with an active and reactive energy meter.

QC

=

E r– (E a • tan ϕ2) t

Er Ea t

= reactive energy (kvarh) = active energy (kWh) = operating time in hours over the accounting period tan ϕ2= calculated from the setpoint value for cos ϕ2 Fig. 262

If no reactive energy meters are installed, the required data can be determined with the help of a reactive power recorder.

Correction of the Power Factor in Networks with Harmonics Consumers with non-linear resistors, i.e. with non-sinusoidal power consumption, cause a distorted voltage waveshape. However, all waveshapes are made up of sine curves the frequencies of which are integer multiples of the system frequency – the harmonics. When using capacitors for power factor correction, the capacity of these capacitors and the inductivity of the network (supplying transformer) form a series resonant circuit. The two impedances of the resonance frequency are the same and cancel each other out; the relatively low active resistance, however, causes current peaks which may possibly lead to the tripping of protection devices. This may occur if the resonance frequency equals or is close to the frequency of a present harmonic. This effect can be corrected by the use of capacitor units equipped with an inductor. These inductors are designed in such a way that the resonance frequency in combination with the network inductivity falls below the fifth harmonic. With all higher harmonics, the capacitor unit is then inductive which excludes the generation of resonances. We recommend use of these inductor-capacitor units in all cases where more than 20% of the power is caused by harmonicsgenerating equipment. Compensation in Networks with Ripple Control Ripple control is effected by superimposing the network voltage with signals of a frequency between 160 and 1350 Hz. Since the capacitor conductance is rising in a linear manner in relation to the frequency, these signals can be practically shortcircuited. For this reason, the influence of the compensation measures should be considered and, if inadmissible, it should be corrected. VDEW (German Utility Board) has issued a recommendation on this subject, where the impedance factor α has been defined as the ratio of the network impedance to that of the compensation equipment at the frequency of the ripple control signal. The practical consequence is that in networks without harmonics and with ripple control frequencies of less than 250 Hz, capacitors without inductors can be used to correct the power factor at a capacity of up to 35% of the apparent transformer power. In this case, follow-up measurements can be omitted.


Ripple control frequencies

Reactor/capacitor ratio p

< 250 Hz

14%

> 250 Hz

≥ 7%

> 350 Hz

≥ 5%

1

2

Fig. 263: Types of compensation for different ripple control frequencies

Only in cases with a higher capacitor power should the power supply companies be consulted for an agreement on the use of audio frequency hold-offs. With frequencies greater than 250 Hz, capacitor powers without audio frequency hold-off are admissible only up to 10 kvar. If the capacitor power exceeds this value, audio frequency hold-offs are to be integrated. This refers mainly to parallel resonant circuits which are connected to the capacitors in series and which show a high impedance in their resonance frequency. In networks where harmonics are clearly present, inductor-capacitor units should be used for compensation in any case. The specific type of compensation equipment is to be selected with consideration of the ripple control frequency. Fig. 263 shows some guide values for this procedure.

3

4

5

6

7

Compensation of Harmonics The continuous progress in power semiconductor technology has resulted in an increased use of controlled rectifiers and frequency converters, e.g. for variablespeed drives. The common and characteristic feature of these devices is their nonsinusoidal power consumption. This leads to distortion of the network voltage, i.e. it contains harmonics. This distortion is then forced upon other consumers connected to the same network and will also have an effect on higher voltage levels. This disadvantage may lead to operational failures and cause a higher apparent power in the network. In order to keep to the limit values as specified in the EN 50160 standard, filtering may become necessary.

6/149

8

9

10

Power Quality Passive Compensation – Harmonics Filter

The following example shows the harmonics present in a typical three-phase, fullycontrolled, bridge-circuit rectifier (Fig. 264).

1

ν = 6 · k ± 1,

k = 1, 2, 3, …

2 Fig. 266

The amplitude of the currents decreases inversely to the increase of the order number, ideally, in a linear manner in relation to the frequency:

3

Iν =

4

1 · I1 ν

M Fig. 267

5

Fig. 264: Three-phase bridge circuit

6

Primary distribution network Transformer

7

Drive

Low-voltage Filter

8

ν

M

9

Reactive power Active power

10

=5

ν

=7

ν

=11…

Actually, the values are often slightly higher, since the DC current is not completely smoothed. Harmonics of the fifth, seventh, eleventh and thirteenth order may show amplitudes which need to be reduced; harmonics of a higher order can usually be neglected. The effect of harmonic currents on the system can be reduced considerably by the use of filters. This is effected by generating a series resonant circuit from a capacitor and an inductor which is then adjusted exactly to the corresponding frequency for each harmonic to be absorbed. The two impedances cancel each other out, so that the remaining ohmic resistance is reduced to a negligible amount, compared to the network impedance. The harmonic currents are absorbed to a large extent; the rest remains present in the supply network. This results in a lower voltage distortion and a considerable increase in voltage quality. Referring to the fundamental component, the filters form a capacitive load. This supports the general reactive power compensation. This measure enables the corresponding equipment to be designed for lower capacities (Fig. 265).

Fig. 265: Correction of the power factor with the help of filters

6/150


Power Quality Passive Compensation – Selection Guide

Help for Selection

Type Series 4RF6

Siemens offers capacitors with and without reactors, suitable for single-phase and three-phase systems for reactive powers between 5 and 100 kvar and for nominal voltages between 230 and 690 V. These capacitors are suitable for the compensation of constant reactive power.

Fixed reactor-capacitor units for stationary compensation in networks with a non-linear load percentage of more than 20% related to the supply transformer apparent power rating. Voltages between 400 and 690 V, rating from 5 to 50 kvar. Reactor/ capacitor ratios: 5.67%, 7% or 14%.

Type Series 4RB

Type Series 4RF14

MKK Power Capacitors for fixed compensation without reactors, ratings 5 to 25 kvar. The three-phase capacitors can be directly connected at the load. Discharge resistor 4RX92 are to be connected in parallel.

Passive, adjusted filter circuits for the absorption of harmonics. Voltages from 400 to 690 V, rating from 29 to 195 kvar. In the course of project planning, the customer will be requested to specify the currents of the generated harmonics, the harmonic content in the higher-level network and the short-circuit reactance at the connecting point.

Type Series 4RD MKK power capacitors for fixed compensation without reactors, mounted in a protective housing or on a plate. Ratings 5 to 100 kvar. Discharge resistors included. Type Series 4RY Complete small systems without reactors for the automatic stepwise control of the power factor with and without integrated audio frequency hold-off in different housings and at different ratings. The units are equipped with a BLR-CC controller suitable for 8 switching steps. Without audio frequency hold-off, the capacity ranges from 10 to 100 kvar, with hold-off from 12 to 50 kvar. The nominal voltage for both versions is 400 V, the frequency is 50 Hz. Larger, fully-equipped systems without reactors are delivered in cabinets. The ratings of these systems range from 37.5 up to 500 kvar for nominal values between 230 V and 690 V and frequencies between 50 and 60 Hz. With these systems the SIMEAS C controller for operation in six switching steps is used. This controller optimizes the switching sequence for constant use of the capacitors. For voltages of 400 V, systems with ratings between 75 and 300 kvar and with an integrated audio frequency hold-off are available. Type Series 4RY56 Capacitor modules without reactors between 20 and 100 kvar for installation in racks of 600 or 800 mm in width. Type Series 4RF56

1

2

3 Fig. 269: 4RY56 Capacitor module 100 kvar, switchable as 2 x 50 kvar module for cable connection

4

Type Series 4RF1 Fully-equipped compensation systems with reactor suitable for 400 to 690 V, with a capacitor rating up to 800 kvar and with additional reactors for a total rating up to 1000 kvar. The controller function is realized by SIMEAS C.

Version

Reactor/capacitor ratio

4RF16

5.67%

4RF17

7%

4RF18

8%

4RF19

14%

5

6 Fig. 270: 4RY19 power factor correction unit in sheetsteel wall cabinet, 50 kvar

7

8

Fig. 268

Type Series 4RF3

9

Fully-equipped compensation systems with reactors suitable for 400 to 525 V (and also for other voltages on request) for ratings between 200 and 400 kvar. Special feature: audio frequency blocking and simultaneous filtering of harmonics. The controller function is realized by SIMEAS C.

10

Reactor-capacitor modules from 5 to 100 kvar for installation in racks of 600 or 800 mm in width.

For technical data of SIPCON T Passive Filters and Compensation Systems see Power Quality Catalog SR 10.6


Fig. 271: 4RF1 power factor correction unit 250 kvar (5 x 50 kvar) in a cabinet 2275 x 625 mm

6/151


Flowcharts

1

The flowcharts can be used as a reference when selecting the suitable compensation equipment with regard to the individual preconditions of the specific network.

Percentage of non-linear load in the network < 20% of Sr*)

2 No

Must resonances with the higherlevel network be avoided?

No

Ripple control in the network?

3

Yes Ripple control in the network?

No

4 Yes Audio frequency > 250 Hz

Yes No

Audio frequency > 250 Hz?

5 Yes U5 < 3% U7 < 2% present in the network?

6

Yes

No

1 Go to flowchart 2

No

2

Yes Capacitors and compensation units without 4RY. Audio frequency hold-off on the supply side.

7

8

Special audio frequency holdoff on request or compensation unit with reactor (7%).

Capacitor type 4RB, stationary compensation equipm. type 4RD. Equipment for power factor correction without reactors, type 4RY.

Equipment for power factor correction, type 4RF17, reactors (7%). Filtering of 5th harmonic up approx. 30%

*) Sr is the apparent power of the upstream infeeding system (transformer)

9

Fig. 272: Flowchart 1: Power factor correction for low, non-linear load

10

6/152



Percentage of non-linear load in the network ≥ 20% of Sr *)

No

1

Yes

Improving the power factor

2

Avoiding resonances with higher level network

3

Partial filtering of selfgenerated harmonics

Filtering a large amount of self-generated harmonics.

Ripple control present in the network?

Ripple control present in the netwok?

4 No

Yes No

Audio frequency > 350 Hz?

Yes

No

5

Yes No

1 2 Compensation equipment for power factor correction, type 4RF16, with reactors (5.67%). Filtering of selfgenerated 5th harmonic up to approx. 50%.

Audio frequency < 250 Hz?

6

Yes 4RF34 or 4RF36 special reactor connected power factor correction unit, or power factor correction unit, type 4RF19, with reactors (14%).

Requires special version, available on request.

Passive, tuned filter circuit type 4RF14 required, available on request.

7

8

*) Sr is the apparent power of the upstream infeeding system (transformer)

9

Fig. 273: Flowchart 2: Power factor correction for large non-linear load

10


6/153

Power Quality Active Compensation

1

SIPCON-DVR/SIPCON-DSTATCOM Active Filter and Compensation Systems

Advantages of Active Compensation Equipment ■ No capacitance, in order to exclude the

generation of undesired resonances. ■ Reactive power and harmonics are

2

3

4

5

6

7

8

A great number of industrial processes based on the supply of electrical energy require a high degree of reliability in power supply, including the constancy of the voltage applied and the waveshape. A shorttime voltage failure or voltage dip may cause the destruction of a component presently being processed in an NC machine or of a whole production lot in the semiconductor, chemical or steel industry. In the automotive and semiconductor industries, for example, the cost incurred by these losses may quickly accumulate to millions of dollars. In return, some production processes cause unacceptable perturbations in the supply network resulting from voltage dips (rolling mills), flickers and asymmetries (steel mills). Correction is possible with the help of active compensation systems. These systems are capable of absorbing harmonics and of compensating voltage dips, reactive power, imbalance in the three-phase system and flicker problems. Their characteristic features go far beyond the capabilities of passive systems (e.g. SIPCON T) and offer great advantages when compared with other applications. The function principle is based on a pulse-width modulated, three-phase bridge-circuit rectifier, as used for example in variable-speed drives. The switching elements – IGBTs (insulated gate bipolar transistors) – are controlled by means of pulses of a certain length and phase angle. These pulses initiate charging and discharging of a capacitor, used as an energy store, at periodical intervals in order to achieve the desired effect of influencing the current flow direction. The control function is performed by means of a microprocessorbased, programmable control unit.

■ ■

■ ■ ■ ■ ■

treated independently of each other; the compensation of harmonics has no effect on the power factor and vice versa. The audio frequency ripple control levels remain unaffected. Stepless control avoids sudden changes and enables compensation at any degree of accuracy. Most rapid reaction to load changes with a minimum delay. No overvoltages caused by switching operations. The equipment protects itself against overload. The functions will not be affected by ageing of the power capacitors. The user can re-configure the system at any time; this greatly enhances flexibility, even if the specific tasks have changed.

Network

There are two systems available, the DVR (Dynamic Voltage Restorer) and the DSTATCOM (Distributed Static Compensator) which differ in their specific design and application. DSTATCOM is designed for parallel and the DVR for serial connection. The DSTATCOM is connected to the network between the incoming supply line and the consumer or a group of consumers as shown in Fig. 274. The compensation unit functions as a current source and sink. Correction includes all network characteristics related to the reactive power. The DSTATCOM is used to compensate load reactions on the network. Connection of the DVR requires some more effort, since the system is to be looped into the line (Fig. 275) in series connection. In this connection, the DVR can influence the line current flow which enables a complete compensation of voltage dips as occurring, for example, in the event of short-circuits in the network. The DVR improves the voltage quality of the supply system.

Load

IGBT Converter Intermediatecircuit capacitor Fig. 274: DSTATCOM

Network

Load

9

10 Fig. 275: DVR

6/154



The DSTATCOM Compensation Equipment The DSTATCOM is used to compensate reactive power, harmonics, unbalanced load and flickers caused by a consumer. The current supplied from the network is measured and modified by injecting corrective current in such a way as to prevent violation of the limit values defined for reactive power and for specific harmonics flowing to the supply system; flicker problems can also be reduced. The power required for this compensation is derived from the intermediate-circuit capacitor which is simultaneously re-charged with line current. This line current is also used to correct the network current. Apart from the comparatively low losses, no active power flow occurs. The DSTATCOM reduces or fully compensates perturbations on the network caused by the consumer.

Network

Load

1

LCL filter

2

DSTATCOM

3 PWM IGBT converter

4

5

Intermediate-circuit capacitor

Fig. 277: Basic diagram of the DSTATCOM

Network

Harmonics Reactive power Imbalance Flickers

6

Load

Fig. 276: Load perturbations are compensated

Function Principle The DSTATCOM unit measures the current applied to the supply side and injects a corrective current which compensates load perturbations in the supply system or reduces them to the admissible amount. Since no capacitors are used for correction, the risk of resonances, as with passive systems, can be neglected. Inductors are not required. The signals from the audio frequency ripple control systems are not affected. The use of audio frequency hold-offs can be omitted. The DSTATCOM is available in two control variants: control variant 1 for standard operation and variant 2 for flicker mode.

Fig. 277 shows the basic diagram of the system. The IGBT rectifier bridge is connected to the network via an LCL filter. The impedance of the inductivity causes the pulse-width modulated voltage to impress a current into the network and absorb components of higher frequency. With the help of capacitors, the filter effect will be improved. DC voltage is applied to the intermediate-circuit capacitor which is adjusted according to its specific function. The current is measured on the network side with the result that the correcting functions improve the network current and reduce the load reactions on the system.

7

8

9

10


6/155


Application of Variant 1

1

2

3

4

5

6

7

8

9

10

This is the standard design used to fulfill the tasks as described below. All functions can be performed simultaneously; they are carried out completely independently and do not affect each other, as occurs when using solutions with passive components (capacitors). DSTATCOM protects itself against overload by limiting the current. The individual tasks can be allocated to different priority levels. In case of overload, the tasks with the lowest priority will then be skipped and the device will use its full capacity for the other tasks. The control functions with the highest priority level will be the last ones remaining active. In this operating mode the DSTATCOM shows excellent dynamic behavior. Within only a few network periods, the system will reach the setpoint value. Operating variant 1 is used for: ■ Absorption of Harmonics A maximum of 4 harmonics up to the 13th order, e.g. 5, 7, 11 and 13, are compensated. The remaining residual current can be adjusted. This option avoids excessive system load, since the increasing effect of correction causes a decline in the internal resistance for the corresponding frequency. In return, the loadcaused current will considerably increase and with it the losses, which might result in a system overload. Therefore, it is reasonable to correct the harmonics only up to the limit specified by the supplier. ■ Reactive Power Compensation Reactive power compensation, i.e. correction of the power factor, is possible for both inductive and capacitive loads. The continuous control principle avoids switching peaks and deviations which might occur when switching from one step to the next. ■ Correction of Unbalanced Load Loads in single and two-phase connection cause voltage imbalance in the three-phase system which may also have negative effects on other consumers. Especially three-phase motors may then be exposed to overheat. An active load can be symmetrized by means of a Steinmetz compensator. While this compensator can correct only constant loads, the SIPCOM is capable of adjusting its correction dynamically to the load, even if this load is changing quickly.

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Fig. 278: Example: SIPCON DSTATCOM LV

Applications of Variant 2 Variable loads require an even quicker reaction than can be realized with variant 1. Therefore, variant 2 has been optimized in such a way as to enable reactive power compensation and load balancing within the shortest time. Possible applications of this variant are: ■ Reduction of flickers Heavy load surges as occurring, for example, in welding machines, presses or during the startup of drives, may cause voltage line drops. Fluorescent lamps react to these voltage drops with variations in their brightness, called flickers. The reactive components of the load current have usually a greater effect in this case. The DSTATCOM can be operated in the flicker mode which provides an optimized reaction within the shortest time in order to reduce these voltage variations to a large extent. The delay time of the system is only 1/60 of the period length and control is completed within one network period.

L1 Three-phase system

Active load

L2

L3 Fig. 279: Steinmetz compensator

■ Correction of unbalanced load conditions

The DSTATCOM is suitable to fully correct unbalanced loads of the three phases. Until now, this was achieved with the help of stepwise controlled inductors and capacitors, but now correction can be performed continuously and very precisely. The quick reaction of the DSTATCOM in the flicker mode enables control within only one network period. Consumers in single or two-phase connection, such as welding devices, will no longer affect symmetry.



Information for Project Planning When selecting a DSTATCOM, three aspects should be considered: 1. The nominal voltage. Nominal voltages of 400 V, 525 V, 690 V and for medium-voltage applications up to 20 kV. 2. The supply current ISN required by the DSTATCOM. 3. The type of application. Application can be broken down into three types of different tasks (Fig. 280).

100% use for the filtering of harmonics

1

The whole nominal current of the DSTATCOM can be used for the filtering of harmonics. Reactive power compensation and load balancing can also be performed. This function should be used if the device is mainly used for the filtering of harmonics

50% use for the filtering of harmonics

Only 50% of the DSTATCOM nominal current is used for the filtering of harmonics. The remaining current can be used for reactive power compensation and load balancing.

Flicker mode

Instead of harmonics filtering, the whole nominal current is used to perform highly dynamic reactive power compensation and load balancing. Compared with other control variants, the dynamic behavior is many times better.

Required nominal current

The required nominal current for the DSTATCOM is calculated as the geometrical sum of the required partial currents according to the following formula:

2

3

4

5 ISN

= √ I12+ I52+ I72+ I112+ I132

I1

= Reactive component of the fundamental current component

6

I5…I13 = Current harmonics Fig. 280: Application modes of DSTATCOM

SIPCON can be used for the generation of either capacitive or inductive reactive current. Since the latter can usually be neglected as regards reactive power compensation, the working point of the DSTATCOM can be displaced by means of fixed compensation with the help of traditional compensation (SIPCON T). The power of the DSTATCOM can thus be almost doubled. (Fig. 281).

7 Control range of a DSTATCOM with permanent compensation

Network

8

Load 2 x capacitive

9

capacitive

SIPCON DSTATCOM

Permanent compensation

inductive

10 Control range DSTATCOM

Fig. 281: Displaced control range


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The DVR Compensation Equipment

1

2

The DVR unit is used to correct interfering influences from the supply network on the consumer. Short-time and even longer voltage dips, harmonics and unbalanced load may cause considerable damage to sensitive consumers. The DVR has been designed for the compensation of such faults in order to improve the quality in power supply and to prevent production loss and damage.

Network

Load

IGBT converter

LCL filter

3

4

Network

Voltage dips Voltage overshoots Harmonics Imbalance

Load

5 Fig. 282: Improving the quality in power supply

6

7

8

Fig. 283: Block diagram – DVR

Function Principle The DVR is used as a voltage source which is integrated in the feeder line between the supply system and the consumer in series connection. The voltage applied to the consumer is measured and if it deviates from the ideal values, the missing components will be injected, so that the consumer voltage remains constant. Apart from the prevention of voltage dips, the DVR is also used to correct overvoltages and unsymmetries. The highly dynamic system is capable of realizing the full compensation of voltage dips within a period of 2 to 3 milliseconds.

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The signals from audio frequency ripple control systems are not affected. An audio frequency hold-off is not required. Application The DVR is basically used to improve the quality of the voltage supplied by the power supply system. ■ Correction of voltage variations Remote short-circuits in the supply network occasionally result in voltage dips of different strength and of a duration of only few tenths of a second. In weak networks it may also occur that the usual voltage limits cannot be held over a long period of time or that sensitive consumers require smaller tolerances than offered by the power supply company. With the DVR, single, two and threephase voltage dips up to a certain intensity can be compensated independently of their duration. Additional power is taken from the rectifier part from the network, even if the voltage is too low; this power is then supplied to the series transformer on the load side via the converter. The value of the nominal power of the DVR is reciprocal to the voltages to be corrected. Statistics show that most of the short-time voltage dips have a residual voltage of at least 70 to 80%. The power to be generated by the DVR must be sufficient to compensate the missing part. ■ Compensation of unbalanced load The DVR can be used to inject a positive phase-sequence voltage which enables the compensation of imbalance in the supply voltage in order to avoid excessive temperatures of three-phase machines. ■ Absorption of harmonics The quick-action control of the DVR enables elimination of harmonics by correcting distortions of the voltage waveshape. Since the system can be configured for different tasks, it can also be used to process harmonics of the fifth, seventh, eleventh and thirteenth order, either separately or as a whole.

Information for Project Planning In contrast to the principle of SIPCON DSTATCOM, which corrects the reactive power only for the parallel-connected load, the whole load current flows through the DVR system. Therefore, all preconditions and marginal conditions are to be considered to enable correct configuration. Basically, the following points should be taken into account: ■ Fault characteristics: What kind of network faults are to be corrected (single, two or three-phase) and up to which residual voltage value and fault duration shall correction become effective. ■ Load: Nominal value of the apparent power, type of load, e.g. what types of drive, resistance load, etc. are to be supplied with the help of the DVR. ■ Corrective behavior: What degree of accuracy is to be observed for the voltage on the load side. It will often be sufficient if the DVR supplies only part of the nominal load. To ensure correct project planning, a Siemens expert should be consulted.

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Power Systems Control and Energy Management

Contents

Page

Energy Management Solutions Introduction ....................................... 7/2 SINAUT Spectrum ........................... 7/2 EMS from Siemens – a key to success .............................. 7/3 Available Services ........................... 7/3 Integrated IT Solutions for Utilities ........................................ 7/4 Power Network Telecommunication Introduction ....................................... 7/5 Power Line Carrier .......................... 7/6 Fibre Optic Communication ......... 7/13

7

Energy Management Solutions

Introduction 1

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Energy market liberalization is changing the world of energy companies. Deregulation of the energy sector is going ahead throughout many countries. The focal point of energy company business used to be on the technical side with emphasis on supply reliability and cost minimization, but the business side with competition and optimization of earnings will be the most important aspect in future. More intensive and efficient use of information systems is the means to the company’s success. Deregulation of the energy market places new demands on the network control centers of energy companies. New tasks have to be handled in addition to adapting such traditional activities as network supervision and control, network analysis and optimization, generation control and scheduling and distribution management. Siemens is in a position to deliver optimum, state-of-the-art solutions in close cooperation with the customers. As technological pacemaker Siemens invests considerable funds annually in the further development of its products. Planned for the long term, the user-oriented product lines have release compatibility to guarantee that the benefits of tomorrow’s R&D investments can still be adopted by systems delivered today. Siemens furthers this strategy by participating in a variety of IEC, IEEE, EPRI, CIGRE and CIRED committees and by enlisting support from active user groups. The quality management certified by DQS according ISO 9001 ensures quality products and a smooth and reliable project implementation within contractual schedule and budget. Siemens has a large support staff of dedicated experts with power industry experience. With its broad range of products Siemens is able to supply the control systems, all necessary components (communication equipment, control room equipment, uninterruptible power supplies, products for deregulated energy markets, etc.) from one supplier on a turnkey basis.

Expandability

SINAUT Spectrum General SINAUT Spectrum® is the open, modular and distributed control system for electrical networks as well as for gas, water and remote heating networks. It reflects the experience of more than 600 electricity network control systems installed worldwide since the early sixties. Its extensive and modular functionality provides scalable solutions tailored to the needs and budgets of: ■ Municipalities ■ Large industries with their own networks ■ Regional distribution companies ■ National and regional generation and transmission companies ■ Traction power supply networks

SINAUT Spectrum consists of self-contained subsystems that intercommunicate via defined interfaces. This modularity makes it possible to combine subsystems for a specific application. Via a flexible system configuration control center functions can be adapted to customer-specific requirements. The demands on network control systems keep on growing as secure and economic energy management is becoming ever more important. To expand or modify the system it is easy to replace modules or add further modules without a time-consuming and high cost redesign. Due to its modular and distributed system architecture SINAUT Spectrum offers unlimited horizontal and vertical growth opportunities, e.g. from a small entry-level SCADA system up to a large EMS or combined SCADA/EMS/DMS.

Open architecture SINAUT Spectrum is solidly based on industry standards. Therefore the system can be upgraded to take advantage of the rapidly moving technology in the IT market, without losing any of the software investment built up over the years. Modular and distributed architecture Each SINAUT Spectrum system consists of individual functional subsystems which are distributed among an optimum number of servers. Shortest reaction times are achieved by assigning time-critical applications and applications requiring a lot of computational power to dedicated servers.

The following is a short overview of our systems and services. Please find detailed information in the internet under: www.ev.siemens.de/en/powersystemscontrol

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Fig. 1: Network Control System SINAUT Spectrum at VEW Energie AG, Bochum, Germany


Energy Management Solutions

Functionality The state-of-the-art functions of SINAUT Spectrum cover the entire performance range of dispatch centers, district control centers, distribution network control centers and combined control centers for municipalities (for more than one type of power) and for suppliers on the deregulated energy market (GenCos, TransCos, DisCos). The functional packages in SINAUT Spectrum: ■ Flexible, fast and uncomplicated ■ ■

■ ■

■

■

■

■

■

■

■

■

■

Source Data Management Clear and easy to use User Interface Data acquisition and preprocessing by Telecontrol Interfaces with distributed system architecture for flexible and redundant configurations Full range of SCADA and enhanced SCADA functions Storing, archiving and subsequent reconstruction of the process data with the Historical Information System Communication applications for data exchange with other systems via various interfaces Multisite operation of control centers for configuring flexible and dynamic system management in multisite systems Optimum distribution of generator power and cost optimized control of the power plants on the network with Power applications Optimization of operation with Scheduling applications for forecasting the system load and planning Fast and comprehensive analysis and optimization of the current network status with Network applications Training Simulator for practical exercises with a realistic network behavior using set scenarios Distribution Management applications for efficient and economical operation of the distribution networks Demand Side Management, e.g. energy demand control for optimal utilization of the energy supply contracts Deregulation applications for optimizing productivity and profitability for energy companies in deregulated markets

Energy Management Solutions from Siemens – a key to success Network control centers have to operate economically and efficiently over long periods. Therefore Siemens is committed to: ■ Designing systems that can incorporate new standards and technologies over time to keep the system current ■ Avoiding dependence on proprietary tools and methods ■ Using accepted and de facto standards ■ Meeting the growing need for information management throughout an energy company The long-term commitments also include: ■ A full product spectrum ■ Complete turnkey projects ■ Complete spectrum of services ■ Active user groups ■ Strong R&D

Available services 1 Siemens offers services for all important areas: ■ Consulting ■ Studies ■ Planning, engineering ■ Project implementation ■ Installation, supervision of installation ■ Commissioning ■ Training ■ Hardware/software maintenance ■ System upgrading ■ System migration ■ IT system integration ■ Control center design

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Fig. 2: Control Center of Stadtwerke Frankenthal, Germany


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Integrated IT Solutions for Energy Companies

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Integrated IT Solutions for Energy Companies Competition due to the deregulation of the energy markets and the privatization of the energy sector in a number of countries force the energy companies worldwide to increase productivity and profitability. To become faster, flexible and more productive, energy companies have to reengineer and improve their business processes. Support of the business processes by integrated IT solutions improves the competitive position of the energy companies. Siemens is in a unique position in the energy company IT market by covering solutions for all IT needs of our customers within one company: network management, generation management, energy trading and the meter related part of customer management, business operation systems (e.g. SAP, Baan), customer information & billing solutions and call center as well as general IT solutions. Combination, parameterization and interfacing of newly implemented and existing products and systems is our goal. Within the whole area of energy and information management, Siemens provides a unique framework of services and IT solutions for energy companies. Seminars and workshops in all areas, from generation scheduling, energy planning over GIS integration up to risk management for energy trading help our customers to empower their employees and to streamline their business. In the area of consulting we help to engineer and justify the business processes as well as design and implement customer-specific energy trading solutions. Our implementation of products and systems fills the gap between financial enterprise resource planning (ERP) systems, customer relation management systems and technical control or information systems. We offer a whole suit of consulting and IT services together with products and systems as complete IT solutions to enable the energy companies to serve their customers best.

Energy companies in deregulated markets

Generation

Segmentation

Generation Management

Reengineering

Transmission

Network Management

Wholesale Trading

Strategy

Distribution

Processes

Retail

Customer Management

Retail Trading

Technology

Employee

Process orientation

Analysis and optimization of business processes

Information flow

Integrated and process oriented information flow IT integration, workflow management, data management

Fig. 3: Utilities in deregulated markets

Maintenance

Business Operations Business Planning

Crew Management Outage Management

Finance & Sales & Control Marketing

Purchasing Human Archive & Supply Resources (EDM)

Billing Meter Management

Customer Information Call Center

Meter

Customer Management

Data WareWorkflow house Management Communication Contract & Risk Management

Energy Trading Sales Forecast

Remote Terminal Unit

Geographical Information System Facilities Management

SCADA/ EMS/DMS

Network Planning

Network Management

Scheduling Applications

Plant Control

Power Applications

Plant Operations

Generation Management Energy Trading

For further information please contact: Fax: ++49-911-433-8122 and visit our homepage under: www.ev.siemens.de

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Fig. 4: IT systems in a utility


Power Network Telecommunication

Introduction Safe, reliable and economical energy supply is also a matter of fast, efficient and reliable transmission of information and data. International operation, automation and computer-controlled optimization of network operations, as well as changing communications requirements and the rapid progress in technology have considerably increased the demands placed on systems and components of communications networks. The same careful planning and organizing of communications networks are as necessary in the power industry as for the generation and distribution of energy itself. Siemens offers a wide range of systems and network elements specifically designed to solve communications problems in this area. All systems and network elements are adapted to one another in such a way that the power industry’s future communications requirements can be satisfied optimally both technically and economically. Siemens is offering advice, planning, production, delivery, installation, operation and training – one source for the customer. Siemens provides expertise and commitment as the complexity of the problem requires. Put your trust in the extensive know-how of our specialists and in the solidity of the internationally proven Siemens communications systems. Flexible network configuration with communications systems and network elements

The gradual transition from analog to digital information networks in the power industry and other privately operated networks requires a great variety of systems and network elements for widely differing uses. Prior to a decision as to which system could be used for the best technical and economical solution, it is first necessary to clarify such requirements as quantity of speech, data and teleprotection channels to be transmitted, length of transmission link, existing transmission media, infrastructure, reliability, etc. Depending on those clarifications the most cost-efficient and best technical solution can be chosen.

All systems and network elements described meet the relevant international recommendations and are designed, developed and manufactured in accordance with the requirements of the quality systems of DIN EN ISO 9001.

As shown in the block diagram below, we are offering systems and network elements for analog transmission as well as systems for digital transmission. The systems and network elements shown in this survey of products have been specially developed for power industry applications and therefore fulfill the requirements with regard to quality and workmanship as well as reliability and security.

1

2

up to 500 km

3

Line trap PLC CC or CVT

4

AKE

Distance protection

SWT F6

50 ... 2400 Bd

5

FWT

64 kbit/s ESB

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Hicom O.F. Dig. current comparison and distance protection

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SWT D

8

Data 50 Bd ... n x 64 kbit/s MUX Speech

9 LFH AKE PLC CC CVT SWT F6 FWT ESB Hicom SWT 2 D MUX LFH O.F.

Coupling unit Power line carrier communication Coupling capacitor Capacitive voltage transformer Teleprotection signaling system for analog transmission links Telecontrol – and data transmission system Power line carrier system ISDN telephone system Teleprotection signaling system for digital transmission links Multiplex system Fiber optic transmission system Optical fiber cable

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Fig. 5: General overview


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1

Power Line Carrier (PLC) Communication

1 Conduit with weather-resistant

13

PLC cable screw connection

12

2 Terminal for coupling capacitor 3 Grounding switch with

11 AKE 100 coupling unit

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For carrier frequency communication via power lines or via communication circuits subject to interference from power lines, the high-frequency currents from and to the PLC terminals must be fed into or tapped from the lines at chosen points without the operating personnel or PLC terminals being exposed to a high-voltage hazard. The PLC terminals are connected to the power line via coupling capacitors or via capacitive voltage transformers and the coupling unit. In order to prevent the PLC currents from flowing to the power switchgear or in other undesired directions (e. g. spur lines), traps (coils) are used, which are rated for the operating and short-circuit currents of the power installation and which involve no significant loss for the power distribution system. The AKE 100 coupling unit described here, together with a high-voltage coupling capacitor, forms a high-pass filter for the required carrier frequencies, whose lower cut-off frequency is determined by the rating of coupling capacitor and the chosen matching ratio. The AKE 100 coupling unit is supplied in four versions and is used for: ■ Phase-to-ground coupling to overhead power lines ■ Phase-to-phase coupling to overhead power lines ■ Phase-to-ground coupling to power cables ■ Phase-to-phase coupling to power cables ■ Intersystem coupling with two phase-to-ground coupling units The coupling units for phase-to-phase coupling are adaptable for use as phaseto-ground coupling units. The versions for phase-to-ground coupling can be retrofitted for phase-to-phase coupling or can be used for intersystem coupling.

switch-rod eye Main ground connection External shock hazard protection 1 or 2-pole coarse voltage arrester Drain and tuning coil Isolating capacitor Isolating transformer Resistor for phase-to-phase coupling (balancing resistor) 11 Gas-type surge arrester (optional extra) 12 PLC cable terminals 13 HF hybrid transformer

9

4 5 6 7 8 9 10

10

1 8

7 6 2

5 4

3

Fig. 6: AKE 100 coupling unit with built-in HF hybrid transformer

A: Phase-to-ground coupling Line trap CC or CVT AKE 100

PLC System

B: Phase-to-phase coupling Line trap CC or CVT AKE 100

PLC System

C: Intersystem coupling Line trap

Line trap CC or CVT

AKE 100

HF hybrid

CC or CVT

AKE 100

PLC System

10 Fig. 7: Coupling modes

Coupling mode

Costs

Attenuation

Reliability

A: Phase-to-ground coupling

Minimum

Greater than B&C

Minimum

B: Phase-to-phase coupling

Twice than A

Minimum

Greater than A

C: Intersystem coupling

Twice than A

Greater than B

Maximum

Fig. 8: Comparison of the coupling modes

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1

ESB 2000i power line carrier system

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PAX/ PABX

64 kbit/s MUX

SDH PDH

3 DEE Communication system e. g. Hicom

So

DATA PAX/ PABX

4

Line trap

64 kbit/s

Coupling capacitor

PMX

Coupling unit

SPEECH

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Remote Service subscriber telephone

2/4-wire E&M

6 Protection relay

Distance protection

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SWT 2000 F6

8 Data Data V.28 up to 2400 Bd or via MODEM

9 Modem, ≤ 19,2 kbits/s

Power system control

ESB 2000i

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Data V.28 up to 2400 Bd

FWT 2000i

Service PC

Fig. 9: ESB 2000i power line carrier system


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ESB 2000i power line carrier system

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Modern PLC systems must not only take into account the specific characteristics of the high-voltage line but must guarantee first and foremost that they will be economically and technically usable in future digital networks. The ESB 2000i digital PLC system meets these requirements through ■ State-of-the-art digital signal processor technology (DSP) ■ User-oriented service features, e. g. – automatic line equalization – automatic frequency control (AFC) – remote supervision/maintenance – programming of parameters by PC ■ Integration of data transmission systems (channel circuits KS 2000 and KS 2000i) ■ Digital interfaces for transmission up to 64 kbit/s ■ Integration of Teleprotection Signalling System SWT2000F6 Use of the ESB 2000i PLC system also enables the full advantages of digital transmission to be exploited when employing the high-voltage line as a transmission medium. The ESB 2000i PLC system also satisfies economic requirements such as low investment costs, reduction of expenditure for maintenance and service and technical requirements with respect to security, availability and reliability.

Modulation

Power amplifier

-Interfacemodules

Digital signal processing

Central control

-Demodulation

Receive selection

Fig. 10: ESB 2000i functional units

Application The ESB 2000i PLC system permits carrier transmission of speech, fax, data, telecontrol and teleprotection signals in the frequency range from 24 kHz to 500 kHz via: ■ Overhead power lines and ■ Cables in high- and medium-voltage systems. The information is transmitted using the single-sideband (SSB) method with suppressed carrier. This method permits: ■ Large ranges due to maximum utilization of the transmitter energy for signal transmission ■ The smallest possible bandwidth and therefore optimum utilization of the spectrum space of the frequency range permitted for the transmission ■ Improved privacy due to carrier suppression

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Fig. 11: ESB 2000i PLC System with 40 W amplifier



Digital PLC-System ESB 2000i for information transmission up to 64 kbit/s

1

ESB 2000i

Increased transmission capacity In comparison to a PLC System with analog interfaces, the digital PLC System combined with an external multiplex system can transmit a multiple of voice and data channels. Using the Multiplex System PMX 2000 with voice compression at 4.8 kbit/s, up to 12 voice channels can be transmitted at an aggregate bitstream of 64 kbit/s. Compared with analog PLC Systems a maximum of 2 voice channels can be transmitted.

Digital transmission from 9.6 to 64 kbit/s

Digital interface X.21/V.11

PLC line unit

HFbandwidth 2.5 to 8 kHz

2

3 Service channel

Digital PLC System ESB 2000 Interlink between digital networks in PDH and SDH design and PLC Networks

4 Central processor

With the international standardized interface X.21 acc. to ITU-T, the PLC System can be connected to a primary multiplexer, e.g. FMX (Flexible Multiplex System). On the transmission side the information is connected via optical or electrical 2 Mbits/s interfaces to the PDH or SDH network. PLC links as integrated part of digital communication networks

SSBmodulator/ demodulator

Service PC network management

Service telephone

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Fig. 12: Basic diagram of the ESB 2000i PLC System for digital transmission

6

Transmission capacity, available interfaces and data rate are significant factors for the selection of systems to be used in modern communication networks. The PLC System ESB 2000i with digital interface together with the Muliplex System PMX 2000, meets the requirements in terms of transmission capacity, interfaces and fast data transmission for a wide range of applications.

19.2 kbit/s

7 32 kbit/s

40 kbit/s

Digital PLC System ESB 2000i with add/drop facility

8 64 kbit/s

The digital PLC System ESB 2000i in combination with the Multiplex System PMX 2000 provides the add/drop function for insertion and drop-out of voice and data channels in intermediate stations.

9 Bandwidth 2.5 kHz

Networking of digital voice communication systems (e.g. Hicom) with ISDN basic access So

Bandwidth 4 (3.75) kHz

Networking of voice communication systems via So-interface, e.g. 2 voice channels with 64 kbits/s and 1 service channel with 64 kbits/s (2B+D), can be utilized with the PLC System ESB 2000i equipped with digital interface together with a multiplex system that provides the So-interface and suitable voice compression method.

Note: A service channel for remote maintenance and for service telephone is provided in addition to the above nominal bit rates.

Bandwidth 5 kHz

Bandwidth 8 (7.5) kHz

Fig. 13: Transmission rates of the digital interface of the PLC system according to the available bandwidth


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SWT 2000 F6 protection signaling system for analog transmission links

The task of power system protection equipment in the event of faults in highvoltage installations is to selectively disconnect the defective part of the system within the shortest possible time. In view of constantly increasing power plant capacities and the ever closer meshing of highvoltage networks, superlative demands are placed on power network protection systems in terms of reliability and availability. Network protection systems featuring absolute selectivity therefore need secure and high-speed transmission systems for the exchange of information between the individual substations. The SWT 2000 system for transmission of protection commands provides optimum security and reliability while simultaneously offering the shortest possible transmission time.

Fig. 14: SWT 2000 F6 teleprotection signal transmission system (stand-alone version)

Application

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The SWT 2000 F6 system is for fast and reliable transmission of one or more protection commands and / or special switching functions in power networks. ■ Protection – Protection commands can be transmitted for the protection of two three-phase systems or one threephase system with individual-phase protection. – High-voltage circuit-breakers can be actuated either in conjunction with selective protection relays or directly. ■ Special switching functions – When the system is used for special switching functions, it is possible to transmit four signals. Each signal is assigned a priority.

Distance protection

Electrical line connection

IF 4 CLE

Optical line connection

PU

Annunciations

OMA

IF 4M PS

Transmission paths

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Depending on the type of supply network, the following transmission paths can be utilized: ■ High and medium-voltage overhead lines ■ High and medium-voltage cables ■ Aerial and buried cables ■ Radio relay links

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Service PC

Alarms

24 ... 60 V dc 110/220 V dc/ac

Fig. 15: Block diagram of the SWT 2000 F6



FWT 2000i telecontrol and data transmission system for analog/digital transmission links

In all areas related to the telemonitoring of systems, automation technology and the control of decentralized equipment, it must be possible to transmit signals and measured values economically and reliably. The new FWT 2000i System for telecontrol and data transmission can be flexibly used to perform the various transmission tasks involved in system management not only in public utilities, railway companies and refineries, but also in the areas of environmental protection and civil defense, as well as in hydrographic and meteorological services. The following characteristics of the FWT 2000i system make it suitable for meeting users’ special requirements: ■ Safe operating method around high-voltage systems ■ High degree of reliability and safety ■ Short process cycle times ■ Easy handling ■ Economical use The FWT 2000i system offers a variety of modules for the widest possible range of transmission tasks. Thanks to the unlimited equipping options of the frame, virtually all system variants necessary for operation can be implemented on a customer-specific basis. Universal for all frequencies and transmission rates up to 2400 Bd The KS 2000i channel unit accommodates a transmitter and receiver assembly. All transmission rates from 50 to 2400 Bd can be set in all frequencies within the 30 Hz raster, including in the frequency raster to ITU-T. Transmission in the superimposed frequency band The FWT 2000i System permits transmission in the frequency range from 300 to 7200 Hz. Modularity The modularity of the KS 2000i channel unit is typified by its integration in various other systems, i.e. its use is not limited to the FWT 2000i system. For instance, the channel unit can be integrated in: ■ The ESB 2000i PLC system ■ The SWT 2000 F6 protection signaling system ■ Telecontrol systems.

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Fig. 16: FWT 2000i telecontrol and data transmission system

Transmitter and receiver as separate modules Separate modules that function only as a receiver or only as a transmitter are available for this operating method. Flexibility By using additional modules the system can be extended for alternative path switching or transmission of the control frequencies of a multistation control system. Fast and easy fault localization A variety of supervisory facilities and automatic fault signaling systems ensure optimum operation and fault-free transmission of data.

Additional benefits In addition to the system features, the FWT 2000i system provides all users with the cost-effective and technical benefits expected and required when this system is used. ■ Economical stocking of spare parts is possible since, from now on, only one module is needed for all rates and frequencies. ■ The system can be placed in service quickly and easily thanks to automatic level adjustment and automatic compensation of distortion. ■ The use of state-of-the-art digital processors and components ensures that the system will have a long service life and a high rate of availability.

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Transmission media Suitable transmission media are underground cables, grounding conductor aerial cables, aerial cables on crossarms of power line towers, PLC/carrier frequency channels via power lines, carrier links, PCM links and Telecom-owned current paths. The overall concept of the FWT 2000i system meets the stringent demands placed on power supply and distribution networks. The FWT 2000i meets the special requirements with regard to reliable operation and electromagnetic compatibility.


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KS 2000i channel unit

1

2

3

4

5

The new KS 2000i channel unit is suitable for transmission of asynchronous or transparent data channels on analog media and as such forms a complete and versatile VFT modem. Both transmitter and receiver are accomodated on only one plug-in card either to be used as a stand-alone unit (separate frame) or to be integrated in an ESB 2000i PLC terminal or in a remote terminal unit (RTU). Frequency shift as well as transmission speed are independently adjustable. With a maximum transmission speed of up to 2400 Bd the VFT channel approaches applications traditionally realized with highspeed modems only. Beside others the KS 2000i channel unit provides the following features: ■ High reliability ■ High flexibility ■ Easy detection of faults ■ Excellent transmission characteristics

6

7 Fig. 17: KS 2000i channel unit

8

9

10

7/12



Fiber optic communication 1 The LFH 2000 system Telecommunication requirements in power utilities

2 Electrical link (CU) Fiber-optic link

3

4 OLE 2 SWT MUX

5 O D F

MDF

LWL

34 Mbit/s

Protection

34 Mbit/s

6

LSA

PABX

Energy management system

Communications network management center

7

4 x 2 Mbit/s

34 Mbit/s

2 Mbit/s

8

4 x 2 Mbit/s Office

9

LAN

Communications room

2 Mbit/s

OLE 34 OLE 34

2 Mbit/s

OLE 8

MUX/CC MUX/CC DSMX

MDF PABX

10

SWT O O D D F F

PABX

34 Mbit/s 4 x 2 Mbit/s

4 x 2 Mbit/s

4 x 2 Mbit/s

Fig. 18: The LFH 2000 fiber optic transmission system – Telecommunication requirements in power utilities


7/13


1

2

3

4

5

LFH 2000 fiber optic transmission system

Flexible network configuration and future communications requirements of private network users, such as power companies, call for universal network elements for transmission in digital communications networks. LFH 2000 has been designed and developed on the basis of extensive experience gained with fiber optic transmission systems in public networks and transmission elements specially developed for such systems. It was tailored to the needs of power companies and other private network users. In its basic version LFH 2000 consists of a 19-inch subrack equipped with an optical line terminating unit TRCV2 and a service channel module. Even in its simplest configuration, LFH 2000 offers various types of interfaces for the transmission of speech and data channels such as: ■ Line interfaces up to 34 Mbit/s ■ So-interface for networking digital telephone systems (e.g. Hicom) ■ QD 2-interface for network management

The incorporation of the SWT 2000 D digital protection data system provides additional functions required for most applications in power companies. The basic version can be optionally equipped with service telephone units, optical line terminating units with higher transmission speeds or with other service channel modules so that the system can be conveniently adapted to the individual transmission requirements. Further network elements may be connected to LFH 2000 via internationally standardized interfaces if the number of required channels and the types of interfaces, i.e. the capacity of the system, have to be extended. Depending on the number and type of the transmission interfaces required, LFH 2000 can be expanded by connecting flexible multiplex systems.

LFH 2000 is provided with internationally standardized interfaces so that transmission systems of other manufacturers which are also equipped with internationally standardized interfaces can communicate with LFH 2000. This also makes it possible to combine LFH 2000 with digital transmission system of other manufacturers. The incorporation of LFH 2000 with the expansion element (e.g. flexible multiplex system) into a network hierarchy with differing transmission rates as currently planned and implemented by private network operator can be easily achieved using the compatible network elements available today. The call for a user-friendly network management can be fulfilled by adding the required hardware and software. LFH 2000 meets the requirements of the power companies and private network operators due to its flexibility, availability of internationally standardized interfaces and compatibility with regard to its incorporation into existing private networks.

6

7

8

9

10

DPU

Digital processor unit

IF4

Interface module for distance protection relays

OM

Optomodule for connection of digital current comparison protection system

PS

Power supply

ST-A

Module for service telephone with DTMF signaling

ST-B

Module for nondialing service telephone

AUX

Service channel unit

AUX 1+1 Service channel unit with protection switching

AUXBUS Bus channel unit TRCV

Optical transceiver

O.F.

Optical fiber

DPU

IF 4 or OM

IF 4 or OM

PS

TRCV 2 or TRCV 8 or TRCV 34

Service telephone ST-A or ST-B

O.F. Alarm and event recorder

Distance protection or digital current comparison

OFC (Fiberoptic cables)

TRCV 2 or TRCV 8 or TRCV 34

O.F.

AUX or AUX 1+1 or AUX BUS

Telecontrol system PABX

Fig. 19: LFH 2000 fiber optic transmission system

7/14



SWT 2000 D protection signaling system for digital communication links

1

In comparison with analog protection signaling, the use of digital transmission links provides noise-free communication. Switching operations, atmospheric conditions and other sources of interference on power lines do not impair secure and reliable transmission of protection signals. The SWT 2000 D system for the transmission of protection signals on digital transmission links, mainly fiber optics, provides optimum security and reliability while simultaneously offering the quickest possible transmission speed.

2

3

Uses The SWT 2000 D system is used for fast and secure transmission of one or several independent binary signals for protection and special switching functions in power networks and/or the transmission of serial protection data. The system is avaliable in versions for the transmission of protection data on separate fibers and on 64 kbit/s PCM channels. As an optimized solution between these two possibilities, the system offers transmission of the protection data in the service channel of an optical line termination system (e. g. OLTS, OLTE 8) which ensures maximum independence of the protection data from voice and data transmission despite the common use of fibers in fiber optic cables.

4

5

Fig. 20: SWT 2000 D for flush panel mounting with integrated TRCV2 optical line equipment

PCM

2 Mbit/s

6

40/60 V dc

7

Applications ■ All types of distance protection

(permissive tripping, blocking, etc.) ■ Direct transfer tripping ■ Special switching functions ■ Digital current comparison protection (differential protection) with optical serial interface ≤ 19.2 kBd (e. g. with 7SD511).

TRCV Digital longitudinal differential protection (7SD51)

O.F. 820 nm n x 64 kbit/s

■ ■

■ ■ ■ ■

bi-directional Up to 2 serial protection data, bi-directional Simultaneous transmission of serial protection data and up to 4 binary protection commands High-performance microcontroller Permanent self-supervision Automatic loop testing Event recorder with real-time clock (readable via hand-held terminal or PC).

Distance protection

OM

O.F.

8

X.21/V.11 G.703

DPU

Features ■ Up to 8 parallel (binary) commands,

O.F.

1300 nm 1500 nm

IF 4 Alternative route

9

IF 4 PS

Service PC

10

24 ... 60 V dc Alarms 110/220 V dc/ac

Fig. 21: Block diagram SWT 2000 D


7/15


Flexible Multiplexer (FMX)

1

2

3

4

Depending on the number and type of the transmission interfaces required, the LFH 2000 optical fiber transmission system can be extended by connecting the flexible multiplex system (FMX). The FMX multiplexer is based on a flexible design which is considerably different from normal PCM systems. For terminal operation, it contains a central unit CUA or for drop/insert function the central unit CUD as well as the withdrawable channels. Thanks to the software-controlled configuration and parametrization of the multiplexers they can be integrated quickly and easily into the network. The 19'' inset has sockets for two central units (CU, CUA, CUD), twelve channel units, a supervision unit and two power supply units. User Interfaces (see Fig. 22)

5

6

7

8

9

10

ISDN Basic access unit I4SO

4x

S0 interface

I4UK4 NTP I4UK4 LTP

4x

UK0 interface, 2B1Q or 4B3T, NT-mode or LT-mode

DSC6-nx64G

6x

n x 64 kbit /s G.703 codirectional or n x 64 kbit /s G.703 contradirectional or centralized clock

DSC2-nx64

2x

X.21or V.24/V.28 bis (switchable)

DSC8x21

8x

X.21/V.11 ≤ 64 kbit/s

DSC4V35 or DSC4V36

4x

V.35 ≤ 64 kbit/s or V.36 ≤ 64 kbit/s

The LFH 2000 System – Overview (see Fig. 23 on page 7/17)

CUA or CUD

Conclusion

DSC8V24

8x

V.24/V.28 < 64 kbit/s

DSC104CO

10 x

64 kbit/s G.703 co-directional

SLB62

6x

2-wire LB subscriber

SLX102

10 x

Exchange, 2-wire

SUB102

10 x

Subscriber, 2-wire

SEM106 or SEM108

10 x

2-wire NF and 2 E&M or 4-wire NF and 2 E&M

The described digital and analog network elements are, of course, only a small selection from the multitude of network elements which Siemens has on hand for the implementation of transmission networks. We have focused on those products which have been specifically developed for the transmission of information in power utilities and which are indispensable for the operation of such companies. It has also been our intention to show the uses for our products and how they can be integrated in transmission networks with varying network elements and network configurations. The great variety of products in the field of digital transmission systems and the different requirements of our customers with regard to the implementation of digital transmission networks make customerspecific planning, advice and selection of network elements an absolute necessity. Detailed descriptions of all products can be sent to you upon request.

CUA or CUD

Central unit, standard, or central unit for add/drop operation

Central unit, standard, or central unit for add/drop operation

Fig. 22: FMX interfaces


Fax: ++ 49 - 89 -7 22-2 44 53 or ++ 49 - 89 -7 22-4 19 82

7/16



1

SDH 155 Mbit/s 2,5 Gbit/s

The LFH 2000 System – Overview

2 EMOS QD2 Network management system EMS Energy management system

2 Mbit/s

34 Mbit/s

34 Mbit/s

SDH 155/622 Mbit/s

3

34 Mbit/s

34 Mbit/s

2 Mbit/s

Remote subscriber

4

External and/or internal exchange PABX

4x2 Mbit/s

4x2 Mbit/s

5 Substation control and protection system

RTU

Data interfaces e.g. X.21, V.24, LAN

Data

V.11

6

Protection

V.11

Data and voice of PLC links Distance protection or digital current comparison protection

Protection

4 x 2 Mbit/s

34 Mbit/s

Speech four-wire + E&M Speech four-wire + E&M V.28 V.28

7

PABX

Data RTU

Service telephone Speech, two-wire

2 Mbit/s

8

2 Mbit/s

9 4 x 2 Mbit/s 4 x 2 Mbit/s

TRCV

SMUQ

PLC n x 64 kbit/s

Service channel

MUX

10

Cross connect

Fig. 23: The LFH 2000 System – Overview


7/17

1

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3

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5

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7

8

9

10

7/18


Metering

Contents

Page

General ............................................... 8/2 Overview ............................................ 8/3 Electricity Meters ............................ 8/4 Gas and Heat Meters ...................... 8/6 Demand Side Management ........... 8/7 Energy Data Acquisition ................. 8/8 Payment Systems .......................... 8/10 Business & Consulting Services 8/11

8

Metering

General 1

The Metering Division provides support for energy supply utilities, with particular emphasis on network and account management. Energy meters are used for measuring the consumption of electricity, gas, heat and water for purposes of billing. In this regard, modern energy meters should be able to handle differing regional tariff structures as well as complex tariffs in industrial applications. Siemens makes a decisive contribution to the increased competitiveness of their customers, leading to tangible improvements in the control of energy flows, in the acquisition and processing of meter data, in meter management and in customer communications. Siemens Metering supplies integrated solutions, from energy metering to billing. From a single meter to a complete billing system. We supply tailored solutions for market sectors as diverse as production, transport, industry, services, retail and residential.

2

3

4

5

Examples:

6

Making energy pay After metering, the data is collected, the bill is sent, and finally, the receipt of payment is recorded. Siemens Metering Division improves efficiency by optimizing business processes.

7

Protecting investment The compatibility of the products and systems provides for subsequent functional enhancements. Their functionality can be adapted to emerging requirements at any time. Take DLMS (DLMS Device Language Message Specification), for example: Siemens co-developed this new common standard which will be the meter reading protocol of the future.

8

9

Environmental certification Siemens supplemented the quality management system with an environmental management system. Siemens Metering has ISO 14001 certification.

10

8/2


Metering

Portfolio 1

2

Billi ng

Page 8/11

Tran spo rt

3 n tio ibu str Di

Re

Energy Generation ce ran u s s eA nu e v

Power t o

4

the P Retailer

t… oin

5

6 g

em

b a ck

7

ma

El e

De

ct r i c it

s

on e y

yM

ri n

yst e m

th

eters

eb

P a y me nt -S

… and w

Customer Needs

nd

d

rs

Si

eM

an

ag

em

en t

Energy Data Acquisition Page 8/10

-& Gas

e et M t a He

8 Page 8/4

9

10

Page 8/7

Page 8/8

Page 8/6

Have a look at our Internet Home Page: www.siemet.com Fig. 1: Portfolio Siemens Metering


8/3

Metering

Electricity meters Introduction For the last hundred years Siemens and Landis & Gyr have been producing highquality electricity meters. In 1971 we were the first manufacturer in the world to produce solid-state meters, securing our position as market leader in this field as well. The latest generation of meters sets new standards in economy and efficiency. E.g. the Dialog range is already equipped to communicate with the equipment and systems of other manufacturers. Area of Applications

Fig. 2: Landis & Gyr Dialog meter

Fig. 3: Ferraris poly-phase meter 7CA54

Fig. 4: Meter for ANSI standards

Fig. 5: High precision meter Z.U

The meters supports all applicable standards worldwide and practically all applications in the field of energy measurement. Fig. 7 provides an general overview about electricity meters and their applications. They are used for residential, commercial, industrial, transmission and generation (grid metering) applications. Requirements Accurate measuring on its own is not enough. A forward-looking meter must be equipped for future modifications and enhancements. Meter reading is another major area where energy supply processes can be considerably simplified. Here, too, Siemens offer specific solutions for reducing operating costs.

Technical data

DIN/IEC

BS

ANSI

Production and transmission

■

Commerce and light industry

■

■

Industry

■

■

Households

■

■

Payment Systems

■

■

■

Fig. 6: Siemens Meters satisfy the various standards around the world.

8/4

8_4


4

08.12.1999, 18:32 Uhr

Metering

Households

Commer- Industry cial, Light Industry

Ferraris

■

■

Electronic

■

■

■

■

Single-phase

■

Poly-phase

■

■

■

■

Direct connection

■

■

■

Transformer connection

■

■

■

■

Active energy

■

■

■

■

■

■

■

■

■

■

■

■

■

■

■

■

■

■

■

Application fields Functions Technology

Measurement

Active+reactive energy Import

■

Import+export

Tariff

1 or 2 rate tariff

■

Multi tariff

Communication

Accuracy

Grid metering

Siemens offers a wide range of energy meters for all fields of application. These tables show the main product range of the Siemens electricity meters. For further information, please refer to the corresponding Siemens address in your country. There you will be informed whether the required meter type is approved in your country.

■

■

■

■

DLMS

■

■

■

■

IEC 60870

■

■

■

■

4

5

6

■ ■

Class 0.5S Class 1.0

■

■

Class 2.0

■

■

■

Additional functions

Prepayment

■

■

■

RC Receiver

■

■

■

Interfaces

Optical

■

■

■

CS

■

■

■

RS232

■

■

■

RS485

■

■

■

Int. Modem

■

■

■

7

■

8

9

10

■ = Options Fig. 7: Overview Electricity meters – functions and applications


2

3

IEC 61107

Class 0.2S

1

8/5

Metering

Gas and heat meters 1 Gas meters for gas suppliers

2

3

4

Adaptive gas meters measure with a high degree of accuracy, their sturdy, modular design makes them expandable and protects them against external interference and manipulation. They can be fitted anywhere and without any wear parts. Each meter is built to provide a service life of around 20 years. Whatever happens, adaptive gas meters will be able to cope with even the most drastic changes. The integrated EN 61107 interface provides for trouble-free data exchange, and the LCD display provides for quick reading. The meters are fully compatible with prepayment systems.

Fig. 9: Adaptive 2000 Domestic gas meter

Adaptive Domestic Gas Meters ■

5

■ ■

6

7

8

9

High accuracy Future proof With integral valve

Heat meters

Nominal flow rate QN [m3/h]

Length [mm]

T = Thread F = Flange

Nominal Pressure

0.75

110

T

to PN25

1.50

110

T

to PN25

0.75

190

T, F

to PN25

1.50

190

T, F

to PN25

3

190

T, F

to PN25

6

260

T, F

to PN40 (F)

10

300

T, F

to PN40 (F)

15

270

F

to PN40

25

300

F

to PN40

The type ULTRAHEAT 2WR4 will provide many years of accurate and reliable service. Even small quantities can be metered and billed with precision. Flow rates are measured via a wear-free ultrasonic technology with no moving parts. This patented system means that the meter will operate reliably, regardless of flow profile, installation conditions and water temperature (Fig. 10 and 11). The meters are approved for use throughout Europe and fulfill the forthcoming CEN requirements by complying with EN 1434. They are system-integration ready thanks to communication units. The meters can be upgraded at any time during service. The complete meter range offers the right solution for any application (Fig. 10).

Fig. 10: The complete range of heat meters

Fig. 8: Ultrasonic Heat Meter Ultraheat 2WR4

Fig. 11: Availability of standard flow tube lengths and flow rates

10

8/6


Metering

Demand Side Mangement with Ripple Control Systems

1

Applications Ripple control allows a electricity supply utility from control center to remotely control certain consumers on the supply network. Consumers with energy storing capabilities, such as room heating systems, hot water storage systems, air conditioning systems or pumping stations, are particularly suitable for load control purposes.

2

3

Operation and background Audio frequency pulses, which can be encoded for all necessary switching commands, are transmitted via radio or the available low and high voltage lines. More than 3700 ripple control systems and 6 billions receivers are daily in use for several decades, at the facilities of more than 1000 customers in approx. 20 countries.

Ripple Control Center

4 Ripple control Transmitter

5

Components The components of a ripple control system include (Fig. 12): ■ command units in the control center, which issues the switching commands and provides for operating parameter selection and control. ■ transmitters, which generate the audio frequency pulses and coupling devices which feed the signals into the network. ■ receivers to decode the ripple control signals in the distribution network. Customer value The installation of a ripple control system pays off especially quickly in the area of load management by minimizing the costs of generation, import and distribution of the energy that is supplied to customers. It allows investments in energy supply facilities to be drastically reduced. Around 7–30% of the investment required to generate one megawatt of energy will produce an equivalent energy saving if invested in ripple control. Ripple control provides a major help for network operators in observing their contracts with energy producers in the deregulated market (optimization of load curves, observation of energy import schedules, improved utilization of supply networks).

6

7

Radio frequency ripple control

8 Ripple control receiver

Fig. 12: Ripple Control Overview

9

Radio frequency ripple control A joint venture between four major utilities in Germany was founded to provide radio frequency ripple control as a service, making the advantages of ripple control available to utilities without their own transmitters. A central computer system and two long-wave transmitters broadcasts customer signals and, at regular intervals, the exact time and date. The transmitters and central computer system operate redundantly and are controlled by the utilities via DATEX-P.


10

8/7

Metering

Energy Data Acquisition (EDA) 1

2

3

Measuring, Metering Managing the energy data

■

To improve logistics and accounts in a deregulate environment energy data acquisition and processing is used in energy data management system. The careful utilization of energy requires meticulous acquisition of all relevant data – and then proper interpretation. Siemens telemetering systems help people in all sectors of energy supply and industry to utilize the available energy sparingly and selectively.

■

High demands on technology

4

5

6

7

EDA Product Overview Components

Metering points form the interface between the individual market players. Measuring accuracy and long-term durability are taken for granted. Logging of load profiles creates the necessary clarity. Depending on the field of application, whether in the high or medium voltage range or in industry, different technologies are required and quality features are becoming increasingly significant. The use of cheap communication channels places high demands on communication systems. High transfer rates, multiple protocol capability and compatibility with a variety of media are a must. The data simply has to be made available for billing and evaluation as quickly as possible.

■

Electronic Polyphase Meters Polyphase Ferraris Meters Electronic High-Precision Polyphase Meters

Measuring metering ■

Local Data Processing and Control ■ ■ ■

Encoders Universal Telemetering Devices Metcom Modems

■ ■

Communication ■

Communication sets with VFT Channels

Central Stations and Software ■

■

Multi-functional, electronic polyphase meters (series ZMB) Electromechanical polyphase meters (type MM 2000) Electronic combimeters with housings for surface (type Z.U/Z.W) mounting or chassis for 19" rack mounting Hand-held terminal for meter reading and ripple-control receiver programming

Local data processing/control

Landis & Gyr® DG C300/ C2000

■ ■ ■ ■ ■

Encoder (type FBC) Universal telemetering device (type FAG) Tariff device (type EKM640) Ripple-Control Receiver METCOM modems

Communication ■

Communication sets with VFT channels and modems

Central station ■

DG C300/C500/C2000

Keeping one step ahead

8

9

Energy Data Acquisition Systems perform complex tasks, and central stations calculate a wide range of values. Whether for billing, statistics, network planning or tariff analysis, Siemens EDA systems are available as single-user or client-server solutions. They are compatible with the equipment of all leading manufacturers and are ready to meet the challenges of the future.

Data post – processing ■

Fig. 13: Siemens EDA systems for billing statistics, network planning, tariff analysis etc.

EDP – Electronic Data Processing

Fig. 14: Overview Energy Data Acquisition

10

8/8


Metering

Production and transmission

Manufacturing industry

1

Light industry and service

2 Z.U/Z.W

3 Metcom

4 FAG

FBC

Datacard

EKM

Communication

5 System platform

6

7

EDP

8

9

10

Fig. 15: High-Precision Polyphase Meters and Universal Telemetering device Landis & Gyr FAG

Fig. 16: ZMB Polyphase Meters with Metcom Modem


Fig. 17: Central station analyses and displays the collected data in graphic or numeric form

8/9

Metering

Payment Systems 1 Payment Systems increase efficiency and simplify account management.

2

3

Secure Revenue Stream With increasing deregulation, this subject is fast becoming an important issue. The customer pays for energy as he uses when convenient for him. The utility achieves cashflow and secures increased liquidity, and eliminates problem payers. Willingness to pay is no longer an issue.

Fig. 18: Buying energy as much as required at the point of sales

Fig. 19: Easy Pay-a simple payment module

Our solutions for different applications Optimization made simple

4

5

No costly customer visits. Fewer timeconsuming customer support issues. The accounting process is considerably simplified. There is no longer any need to cut off and restore supplies to late payers, or to visit customer premise for a change of occupancy. Intelligent communications

6

Keypad Solution

Smart Card Solution

Simple vending of energy with minimal infrastructure

Comprehensive management of the amount of customers who are disproportionately expensive to manage

Secure currency and tariff transfer Capable of vending energy over the internet or from call centre

Reduces cost of meter operation concerning reading and tenancy changes

Control of cash flow and bad debt

Control of cash flow and bad debt

Fig. 20: Our Payment System Solution

Tariff changes can be applied immediately by remote communication. Impending changes can be entered in advance for action at a future date for all customers, or just a selected group. Meter readings at specified times can be recorded and transmitted to the control center by centralized command.

7 Complete system solutions

8

The two-way systems provide the ability to tailor customer service, initiated by routine payments using the customer card. Our keypad systems simply vend energy to end customers. Siemens Metering Division provides everything for a customized solution – from the in-house installation to comprehensive system solutions and services.

9

10

Fig. 21: Cash Power 2000

8/10

Fig. 22: Smart Card System


Metering

Business and Consulting Services General Customer optimized processes and reduce costs the tasks of Business and Consulting Services. In the rapidly changing energy market, concentrating on core business must not mean neglecting business processes. With Siemens Metering Division as your partner, outsourcing means a decisive step towards a cost-effective and customerfriendly future. We provide innovative solutions for existing activities and for the creation of new business opportunities with new technologies and processes while maintaining strict confidentiality.

Consulting Services: Process Analysis, Process Reengineering Warranty

Procurement

Training

Warehouse/Logistic

Parameterisation

Project Management

On-call Repair & Maintenance

Planning/Installation

Contract Repair & Maintenance

Customized Services

Hot Line Support Upgrade & Migration

Lifetime Product Support

1

Integrated Services Meter Management Services

2

Data Management Services Meter & Data Management Services

Exchange

3

Customer Management Services

Refurbishing

Integrated Customer Management Services

Recycling

4

Complementary Services

Financing Services: Leasing, Rental, Project Financing Customer-oriented modules Energy metering: from inventory management, through to recycling ■ Payment systems: from the point of sale to accounting ■ Data management: meter reading and transmission of data ■ Billing: from invoice preparation to data management ■ Customer data management: from the administration to the call centre. Depending on the task, Siemens Metering Division provides assistance in specific areas, or offers complete system solutions and flexible financing – whatever the customer needs. (Fig. 23) ■

Siemens Metering Division applies the three-step DBO concept (Design, Build, Operate) for customer-oriented implementation: Design Improvements begin with a careful analysis of the present situation from the various viewpoints. The goal is to help the customers achieve greater success and to reduce their costs. Depending on requirements, Siemens create a comprehensive solution for a complete or partial concept – whatever the customer needs.

Fig. 23: Portfolio Services

5

6

7

Build

8

Having identified the concept, it then has to be deployed. Siemens provide competent support for the incorporation of services and outsourced business processes into existing business operations.

9

Operate The goal for this on-going partnership is to run the new business processes to the highest standards of quality, guaranteeing maximum profitability.


Have a look at our Internet Home Page: www.siemet.com

8/11

10

Metering

1

2

3

4

5

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7

8

9

10

8/12


Services for Power Transmission and Distribution

1

2

3

4

5

6

7

8

9

10 Contents

Page

Introduction ....................................... 9/2 From Initial Planning to Integrated Solutions ................... 9/3 Financial Solutions .......................... 9/3 Service and Training ....................... 9/4 9/1


9

Services

Introduction 1

2

3

The energy market is changing, and so are the “rules of the game”. The focus of attention is gradually moving away from the old individual power suppliers and coming to rest more and more on what we now call “energy service providers” who can master every aspect of power generation, transmission and distribution. Anyone who wants to make the most of the opportunities offered by a deregulated and liberalized market needs a business partner who can advise and support, who offers an individual service and a high standard of training and who is always available when you need him – twenty-four hours a day.

Your partner

What we have to offer

As a true partner in everything to do with power supplies we offer it all. Siemens Services attend to all the tasks that help you to achieve not only the best possible economy in a competitive world but also reliability of supply, optimum technical performance and safety. Our range of services extends across the board into every area of power transmission and distribution, from analysis, planning and project design throughout the whole lifetime of an installation to its eventual disposal.

This chapter is intended to high-light our truly comprehensive range of services for the energy market. Take a look and see the enormous breadth of what we have to offer – for your products, your systems, your plant and equipment – everything to do with power transmission and distribution.

For further information please contact: Fax: ++ 49 - 91 31- 73 44 49 e-mail: [email protected]

4

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8

9

10 Fig. 1

9/2


Services

From Initial Planning to Integrated Solutions Power System Planning – The first step towards economical solutions The first step towards a new, extended or modified network always is a reliable initial planning. No matter if this step involves network analysis, equipment, plant or system design, or the integration of various network components – we have the right know-how to perform any of these tasks. Our services include counselling, power system calculation, planning and design as well as the analysis of networks of all voltage levels. Our innovative approach and experience of many years allow us to meet all the demands of our customers. To assist us in this task, we developed several high-level simulation programs such as NETOMAC®, the world’s most powerful tool for calculating electromagnetic and electromechanical transient response, and SINCAL® for the study of interconnected networks. We also perform on-site measurements and advise our customers about viable options to improve and optimize their power system. With our AC/DC real-time simulator we determine control and protection settings for HVDC systems, FACTS and power quality equipment. A team of experts will always assist you with the installation and commissioning of these devices on site. Decentralized supplies can be planned-in too There is no doubt that in the future some existing large concentrations of generating capacity will be replaced by a larger number of smaller decentralized units. Such units can be powered by wind, biomass or solar light and will soon be generating between 10 and 15% of all the electricity that is needed. Intelligent systems will provide the control and ensure an optimum energy mix. This will make great demands on the planning and implementation of integrated energy management systems that cover the whole distributed network right up to final consumption. Our partnership with you also means providing generation management, load management, delivery management and communications, with consumers too, integrated into the network itself. For this purpose we employ intelligent supply systems, including subsystems such as the NEXUS

meter management system, the DEMS decentralized energy management system, the SINAUT® Spectrum open network control system and the SICAM® system for substation automation.

1

Project development and construction of large-scale systems Infrastructural and industrial projects call for a broad range of products and services. The demands frequently go beyond the scope of just power transmission and distribution. In such cases, your competent Siemens contact can open up the door to everything we have to offer in terms of power engineering. In international project business, there is nowadays an increasing trend towards involving consulting engineers, general contractors and project developers. Because of the global interconnection of this business it is essential to have an effective communication in place. With our experience over decades we contribute to an efficient project execution of such international projects including external and internal Siemens partners.

2

Fig. 2

3

4

5 Fig. 3

Fit for the energy market – with integrated IT solutions With the ongoing development in information technology IT over the last decade, it is possible to build up integrated IT solutions, designed to solve your problems and help you to optimize your business processes. However, the world of IT is still characterized by so-called island solutions, which should be integrated into an overall system. Our IT solutions cover all your tasks: Network Management, Energy Trading, Customer Management and Business Operations. One good example of our integrated solutions is meter management, where the business process flow from meter reading to consumption billing is efficiently supported. A partner in system administration Whether it be extending a system or simply looking after it properly, as your partner we can also undertake all your system and data management. That could be of great interest for large-scale system administration in connection with power system management, for example. Typical tasks of this kind are the editing of system parameters, regular checking of system security and the addition and editing of mimic diagrams, listings and records. In this area we can provide backup either through on-site service or by means of teleservice.


6

7

Fig. 4

8

Financial Solutions So that none of your projects fall at the hurdle of finance, we can advise you on how to finance them in the most suitable way for you.

9

The international trend: Operator models

10

Project finance is in world-wide demand these days, for major schemes sponsored by both governments and the private sector. It is this that provides the necessary freedom of action for investment. We help you to explore many new avenues of approach – total customized solutions, capital finance from the world‘s money markets – to fit your needs at attractive rates.

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Services

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2

3

Service and Training for Substations, Switchgear and System Components – Customized Concepts Every plant, every installation, every system and every product associated with electricity supplies can gain in value from skilled expert service, whether it be through optimum availability, long service life, economical operation or fast help in the event of a problem. Whatever the task – we have the experts to deal with it. They are on the spot almost immediately after you call and you can rely on them to get the job done properly.

4

Training for any task

Whether it be task planning, status evaluation or damage analysis, we will be happy to arrange expert surveys for you at any time. Such results are an important prerequisite for economical future planning and for skilled repairs or maintenance.

Just as important as good service are good operating staff. Only someone who has been properly trained can recognize early on the need for service attention, plan it properly when it is needed and respond correctly to any operational disturbances that might occur. In order to cover this aspect of demand we offer an extensive range of training programs that have been tailored specifically to the needs of our customers. Various courses, based on theory but practical in nature, are held for small groups of participants.

Arranging for waste disposal When installations, plants or parts of them have come to the end of their useful life, you will have to dispose of them properly and in an environmentally compatible manner. We will be happy to give you full backup and take care for arrangements by disposal experts. On-call service and failure analysis

From a single service to total care

5

Expert surveys for economical answers

You can choose from a truly comprehensive range of services. Whether you want a single-contract relationship with us or a longterm maintenance concept offering optimum availability, we have the right one for you.

Our hotline gives you access to immediate help. One call is enough to get you all the support and backup you need – over the telephone or by specialist staff on-site.

Overall training program As well as the actual training itself, we can also take care of all your training management needs. This means the organization and implementation of individual training activities as a package including all the associated tasks of booking hotels, designing programs and looking after participants from the time they arrive to the time they leave.

Customized maintenance contracts

6

7

8

One way of ensuring that you get the best possible service is to arrange a maintenance contract. Such documents lay down what individual maintenance services will be provided by us – for example, 24-hour on-call availability, coordination of service activities, specific maintenance tasks, fault analysis, etc., etc., etc. The advantage of this for you is that you can tailor the scope of the services to your own individual requirements and so do what is best for you in terms of economy. World-wide service – solving problems on-site

9

10

Residual wear margin

100%

Reference conditioning (after repair)

Reference conditioning (at initial commissioning) Actual conditioning deviation Z0 – Z1 Actual conditioning Z1

It makes no difference where you are: We have a service network and a spares delivery service that span the globe, allowing us to solve your problems quickly, fully and reliably.

Damage limit

Modernize with RETROFIT – at the right price Modernization instead of new investment – this is where RETROFIT comes in. RETROFIT is our economical total concept for looking after the technical side of your installations and for adapting everything to comply with the latest standards. That means greater safety for your employees, and greater reliability for the supplies you provide.

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Lifetime Inspection t1 Inspection t2

Inspection t3

Failure Repair time

Fig. 5: Condition-based maintenance: The right time for action is when costs can be cut and availability can be enhanced.


System Planning

Contents

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Overall Solutions for Electrical Power Supply ............. 10/2

10 Ohne Namen-1

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27.09.1999, 18:04 Uhr

System Planning

1

Overall Solutions for Electrical Power Supply

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3

Integral power system solutions are far more than just a combination of switchgear, transformers, lines or cables, together with equipment for protection, supervision, control, communication and whatever more. Of crucial importance for the quality of power transmission and distribution is the integration of different components in an optimized overall solution in terms of:

■

■

System design and creative system layout, based on the load center requirements and the geographical situation Component layout, according to technical and economic assumptions and standards Operation performance, analyzing and simulation of system behavior under normal and fault conditions Protection design and coordination, matched to the power system.

Siemens System Planning Whether a new system has to be planned or an existing system extended or updated, whether normal or abnormal system

4

Solutions

Tasks System design

5

6

Results

System analysis, system documentation

Load development Cable restructuring Upgrading installations Selecting voltage levels System takeover Defining new transfomer substations System interconnection Connecting power stations Using new protection schemes

Economical solutions for distribution and transmission systems

System calculations, load-flow and short-circuit Uncomplicated and reliable operation

Planning and calculating AC and DC transmission

Minimization of losses

Determining economic alternatives Specifying the configuration of the system

Reduction of the effects, extent and duration of faults

Design of electrical installations Design of protection system, selecting equipment, selective coordination and real-time tests

Component layout

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behavior has to be analyzed or a postfault clarification done, the System Planning Division, certified to DIN ISO 9001, is competent and has the know-how needed to find the right answer. The investigations cover all voltage levels, from high voltage to low voltage, and comprise system studies for long-distance transmission systems and urban power networks, as well as for particular distribution systems in industrial plants and large-scale installations for building centers. In addition the protection design must be optimized for all transmission and distribution systems for highest and efficient power quality. In all these tasks, System Planning works in close cooperation with its customers and other Siemens Groups (Fig. 1).

Generator Transformer Circuit-breaker Overhead line Cable Compensation equipment Equipment for neutral grounding Protection equipment Control equipment HVDC FACTS Grounding

Optimized fault clearance for reduced system black-outs

Customer acceptance tests of protection equipment Priorities in system extension Replacement of old installations, reconstruction, extension or new constructions

Simulation of complete system and secondary equipment Switching operations, layout of overvoltage protection system, insulation coordination Analysis of harmonics, layout of filter circuits, closed-loop and open-loop control circuits for power converters

Extensively standardized system components

Operation performance

Simulation of system dynamics

Voltage quality System perturbations Neutral grounding Fault clearing Overload Overvoltage Selective Tripping Schemes Asymmetry Transient phenomena Reactive power balance Power-station reserve

Layout of power electronic equipment (FACTS)

Compliance with specified performance values

Method of neutral grounding

Short tripping times for reduction of system stresses

Reliability analysis Earthing arrangement and measurement

Safety for persons

Investigation of interference Propagation of ripple-control signals

Economical alternatives

Fig. 1: Tasks, Solutions and Results

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System Planning

The Power Supply System The power supply system is like a pyramid based on the requirements of consumers and the applications and topped by power generation (Fig. 2). The power system is basically tailored to the needs of consumers. Main characteristics are the wide range of power requirements for the individual consumers from a few kW to several MW, the high number of similar network elements, and the widespread supply areas. These characteristics are the reason for the comparatively high specific costs of the distribution system. Thus, standardization of equipment, use of maintenance-free components, and simplified system configuration have to be considered for an economical system layout. The load situation at the LV level determines the most suitable location of public MV/LV substations and consumer connection stations and, to a high degree, the electrical and geographical configuration of the superposed medium-voltage distribution network as well. HV/MV main substations feeding the medium-voltage distribution system should be located as close as possible to the load centers of the medium-voltage distribution areas. The subtransmission system feeding the main substations is configured according to their location and the location of the bulk power substations of the transmission system. The largely interconnected transmission system, e.g. up to 550 kV, balances the daily and seasonal differences between load requirements and different available generation sources.

1 Power generation

2 Transmission system up to 550 kV with HV/HV bulk substations

Transmission function

Subtransmission system up to 145 kV with HV/MV main substations

3

Medium-voltage distribution system up to 36 kV MV/LV transformer public substations Distribution function and consumer connection substations Low-voltage distribution system up to 1 kV. Public supply system or internal installation system

4

Consumer power application industry, commerce, trade, public services, private sector

5 Fig. 2: The Pyramid of Power Supply

6

Load development System analysis

System architecture

7 Network representation

Energy Supply ”reliable and economical“

Network calculation

Basic conditions for system design Industry, trade and commerce as well as public services (transportation and communication systems), but not forgetting the private sector (households), depend highly upon a reliable and adequate energy supply of high quality on highly economical terms. In order to achieve these aims, several aspects must be considered (Fig. 3). International and national standards are the basic fundamentals for system design. The choice of system voltage levels and steps is of decisive importance for economical design and operation. Reliability requires adequate dimensioning of components with regard to currentcarrying capacity, short-circuit stress and other relevant parameters. Although interruptions in supply due to environmental influence or faults in components can

8 Investment planning

Protection analysis

Fig. 3: Aspects of system planning

10

never be avoided completely, it has to be assured that the time of interruption is minimized. This is a question of reserve in the system. Different degrees of reserve can be provided depending on the requirements.

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Protection coordination

27.09.1999, 18:04 Uhr

System Planning

System Planning, a complex activity

1

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System planning and configuration are comparable with architectural work, finding the best technical and economical solution. System planning has therefore to start with a thorough task definition and system analysis of the present status, based on the given quality requirements. Alternative system concepts (system architecture) in several expansion stages ensure the dynamic development of the system, adapted to structure and load requirements of the subposed voltage level. Component design and the infeed from the superposed voltage level have to be considered as well. Technical calculations and economic investigations complete the planning work and are essential for the choice of the solution (Fig. 4). Load Development

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The load analysis and estimation in the distribution system are always a matter of distributed loads in a certain area. In urban and rural areas, natural borders – such as rivers, railway lines or major roads and parks or woodlands – allow the whole supply district to be subdivided into a number of subareas. In large commercial complexes, such as airports or university and hospital centers as well as in industrial areas, the load estimation is based on the individual buildings and workshops. Different methods are used for load estimation, such as annual growth rates for existing public areas, load density for new developing residential areas, installed capacity and simultaneity factor for commercial and industrial supply. Distribution Network configuration for power distribution is a matter of visualization and will not be executed successfully without the geographical information of load and source location for public supply and industrial or large building supply as well. Thus, each distribution system must be planned individually. But, for the basic design, a certain standard configuration has proved optimal in terms of ■ Uncomplicated configuration ■ Ease of operation and ■ Economical installation Low-voltage systems are usually operated as open radial networks. Industrial systems in particular contain facilities for transfer to standby. Meshed operation is usually only

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Protection

intended for special load situations, such as single loads with great fluctuations or welding systems. Medium-voltage systems are primarily governed in their configuration by the locations of the system and consumer stations to be supplied. The most suitable arrangements for public supplies are open-ring systems or line systems to a remote substation. For industrial and building power supply systems, the higher load densities result in shorter distances between substations. This leads for reasons of economy to the spot system with radial-operated transformers. Industrial power supplies differ from public networks inasmuch as they have a high proportion of motor loads and often inplant generation. Depending on the capacity, units will be connected to normal low-voltage level, intermediate low-voltage level or medium-voltage. The technically and economically optimal configuration of distribution systems calls for wide-ranging practical experience from a large number of different projects and must determine switchgear configuration as well.

The increasing demand from consumers in industry and utility systems and in distribution and transmission networks in terms of power quality imposes strong requirements on system protection. Short tripping times, high functionality, communication, fault recording etc. will be provided by state-ofthe-art numerical relays. To come from pure equipment protection to selective and coordinated system protection, the responsible staff have to be well trained. To get the fastest tripping schemes with the highest selectivity, knowledge of the research and development is necessary. For the optimization of protection under difficult system conditions, online simulation like RTDS systems (Real-Time Digital System Simulators) must be available. Tools Besides great experience and know-how Siemens System Planning applies powerful tools to assist the engineers in their highly responsible work. SINCAL

Transmission The design of transmission systems is to a great extent individually tailored to the location of generating plants and bulk substations feeding the subtransmission system. Planning of high-voltage interconnected networks and transmission networks is a complex matter since they operate over several different voltage levels and mostly meshed systems are used. This and the regional and seasonal difference of generation input and consumer demand as well as the many different sizes of lines, cables and transformers, make load-flow distribution complicated and require detailed calculations of system behavior and the operating conditions of power generation during planning work. As well as the actual planning, the work includes numerous investigations, for instance, to determine the configuration of switchgear and various equipment. This also entails detailed studies of the reactive power, voltage stability, insulation coordination, and testing of the dynamic and transient behavior in the network resul-ting from faults. Connection of neighboring transmission systems via AC/ DC coupling, the implementation of HVDC transmission or superposing a new voltage level need comprehensive planning and investigation work (Fig. 5).

(Siemens Network Calculation) for analysis and planning purposes. Any size of system with line and cable routing is simulated, displayed and evaluated with the SINCAL program system. With the help of an integrated database and easy-to-use graphics system, schematic and topological equivalent systems can be digitized or converted to other systems. NETOMAC (Network Torsion Machine Control) is a program for simulation and optimization of electrical systems which consist of network, machines and closed-loop and openloop control equipment. Two modes of time simulation, instantaneous value mode and stability mode, can be used separately or in combination. The program serves for ■ Simulation of electromechanical and magnetic phenomena ■ Special load-flow calculations ■ Frequency-range analysis ■ Analysis of eigenvalues ■ Simulation of torsional systems ■ Parameter identification ■ Reduction of passive systems ■ Optimization


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System Planning

DISCHU

Technical standards, Reliability requirements

Task definitions, System analysis of present status

Expansion project Load development

Superposed voltage level Infeed

System architecture Alternative system concepts for stages Component design Technical/economical calculations and evaluations

Simulation and testing of numerical protection relays.

Weak point determination Immediate action

1

CTDIM is a program for protective current transformer dimensioning. Main task is technical and economical optimization.

Subposed voltage level Load structure

Protectivecoordination Method of neutral grounding

2

PRIMUS works out the most suitable voltage for a DC transmission project together with the most important electrical data and the costs.

3

SECOND is used to calculate the electrical characteristics and costs of a given AC transmission project.

4

FELD permits calculation of electrical and magnetic fields which occur during operation and fault conditions in the environment of one, two and three-phase systems (e.g. overhead lines and railway lines) in a twodimensional way.

Proposal for system layout Fig. 4: Steps for network planning

LEIKA

Tasks Load development and power plant schedules Voltage steps and transformer substation sizes Installation type and configuration Voltage-control and reactive-power compensation Load-flow control and stability criteria Dynamic and transient behavior System management (normal and faulted)

permits calculation of the electrical characteristics of overhead lines and cables.

Fig. 5: Planning tasks for interconnected transmission system

is for calculating the potential fields of grounding installations. KABEIN is used for calculating the inductive interference to which telecommunication lines and pipelines are subjected by the operating currents or fault currents of high-voltage overhead lines or cables at any levels of exposure.

(Distance Protection Grading) calculates the setting values of the impedance for the three steps and for the overreach zones (automatic reclosing and signal comparison) of distance protection equipment in any kind of meshed network.

(Computer-Aided Protective Grading) indicates grading paths and grading diagrams, checks the interaction of the current-time characteristics with regard to selectivity and generates setting tables for the protection equipment.

5

ACFilt (Filter-circuit design) is for dealing efficiently with harmonic compensation.

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is used for calculating harmonic voltages and currents in electrical systems.

CUSS

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SUNICO


Ohne Namen-1

7

HADICA

DISTAL

6

TERRA

calculates how to make optimum use of power stations. It indicates the best choice from among the available power units and the best way of dividing up the system load among the individual units used.

Existing system Planned

5

System Planning

1

2

Power Generation

G

∆u, ∆f, ∆φ

…

Positive and Zero Sequence Components

…

AC/DC Systems

Digital Sequence Controllers

3 1…6

8 Test Stations

7

8

Protection

Custom Power

Measuring, Protection and Control

…

4 HVDC/FACTS

5

=1

6

Signal Generation and Recording

Simulator Interfaces

Real-Time Computer Simulation

=1

RTDS

Signal Acquisition System

NETOMAC, EMTDC, EMTP

Playback Computer Simulation

Since 1996 Fig. 6: Advanced AC/DC Real-Time Simulator facilities – Overview

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Advanced AC/DC real-time simulation

Measurements

The development and testing of measuring, protection and control equipment of large power supply installations need to take place under real system conditions. Siemens System Planning utilizes a realtime simulator based on a modular principle so that different layouts and structures of the projects can be dealt with flexibly. In the simulator, there are 8 test stations which enable parallel work to be carried out. Six of them are specially designed for testing large power converters such as HVDC and FACTS units. Station 7 has special interfaces for testing system protection schemes. Custom power station 8 is used for Advanced Power Electronic Applications such as SIPCON (Siemens Power Conditioner). In addition to the classic type of simulator with physical elements, realtime injection of transient signals from digital simulations is also possible, e.g. with NETOMAC or RTDS, so that computer and analog simulation complement each other.

Sometimes only field measurements can provide an accurate picture of the actual situation and will be conducted for acquisition of data, clarification of disturbances and verification of functions.

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Instruction and Training Training matched to the particular needs of our customers, acquainting them with installations, methods of planning and use of software tools will be provided. Customers need today also well trained protection staff who are able to handle modern numerical relays in parallel with older installed static and mechanical ones. Siemens System Planning provides the right training for protection design and coordination. All the training courses can be held worldwide and also in Siemens Trainings Centers.

For further information please contact: Fax: ++ 49 - 91 31-73 44 45 e-mail: [email protected]


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Conversion Factors and Tables

Cross-sectional conductor areas to Metric and US Standards

Temperature

Metric crosssectional areas acc. to IEC

American wire gauge

Crosssectional conductor area

Equivalent Metric CSA

[mm2]

[mm2]

°F

Length °C Non-metric system

AWG or MCM

320° 305°

SI system

1 mil

0.0254 mm

1 in

2.54 cm = 25.4 mm

1 ft

30.48 cm = 0.305 m

1 yd

0.914 m

140°

1 mile

1.609 km = 1609 m

130°

SI system 1 mm

39.37 mil

1 cm

0.394 in

160° 150°

290° 275°

0.75

260°

17 16

245°

120°

230°

110°

1m

3.281 ft = 39.370 in = 1.094 yd

2.080

15 14

212°

100°

1 km

0.621 mile = 1.094 yd

2.620

13

200°

3.310

12

4.170 5.260

11 10

6.630 8.370

9 8

155°

70°

Non-metric system

10.550

7

140°

60°

1 in2

1.310 1.50

2.50 4.00 6.00

10.00 16.00 25.00 35.00 50.00 70.00 95.00 120.00 150.00 185.00 240.00 300.00 400.00 500.00 625.00

Non-metric system

19 AWG 18

0.653 0.832 1.040 1.650

13.300 16.770

6

21.150

4 3 2

42.410

1 1/0

85.030 107.200 126.640 152.000 202.710 253.350 304.000 354.710 405.350 506.710

Area

80° 170°

125°

5

26.670 33.630 53.480 67.430

90° 185°

50°

110° 40° 95°

65°

6.452 cm2 = 654.16 mm2

1

ft2

0.093 m2 = 929 cm2

1

yd2

0.836 m2

1 acre

4046.9 m2

1 mile2

2.59 km2

30°

SI system

20°

1 mm2

0.00155 in2

1cm2

0.155 in2

80°

2/0

SI system

Non-metric system

3/0

50°

10°

1 m2

4/0 250 MCM 300

10.76 ft2 = 1550 in2 = 1.196 yd2

32°

0°

1 km2

0.366 mile2

400 500 600 700 800 1000


20° –10° 5° –10°

–20°

–25°

–30°

–40°

–40°


Volume

Volume rate of flow

Non-metric system

SI system

1 in3

16.387 cm3

ft3

dm3

1

1 yd3

28.317

= 0.028

0.765 m3

1 fl. oz.

29.574

1 quart

0.946 dm3 = 0.946 l

1 pint

0.473

1

= 0.473 l

ft3/min

SI system

SI system

3.785 l/s

1 gallon/min 0.227 1 ft3/s

cm3

dm3

Non-metric system 1 gallon/s

m3

Pressure

m3/h

= 227 l/h

101.941 m3/h 1.699

Non-metric system

3.785 dm3 = 3.785 l

1 l/s

0.264 gallon/s

1 barrel

158,987 dm3 = 1.589 m3 = 159 l

1 l/h

0.0044 gallon/min

1 m3/h

4.405 gallon/min = 0.589 ft3/min = 0.0098 ft3/s

Non-metric system 0.061 in3 = 0.034 fl. oz.

Force

1 dm3 =1l

61.024 in3 = 0.035 ft3 = 1.057 quart = 2.114 pint = 0.264 gallon

Non-metric system 1 lbf

4.448 N

1 m3

0.629 barrel

1 kgf

9.807 N

1 tonf

9.964 kN

Velocity

SI system

Non-metric system

SI system

1 ft/s

0.305 m/s = 1.097 km/h

1 mile/h

0.447 m/s = 1.609 km/h

SI system

Non-metric system

Non-metric system

1N

0.225 lbf = 0.102 kgf

1 kN

0.100 tonf

Non-metric system

SI system

3.281 ft/s = 2.237 mile/h

1 lbf in

0.113 Nm = 0.012 kgf m

0.911 ft/s = 0.621 mile/h

1 lbf ft

1.356 Nm = 0.138 kgf m

SI system 1 Nm

28.35 g

1 lb

0.454 kg = 453.6 g

SI system

Non-metric system 8.851 lbf in = 0.738 lbf ft (= 0.102 kgf m)

1 lbf/in2

0.069 bar = 0.070 kgf/cm2

1

tonf/ft2

1.072 bar = 1.093 kgf/cm2

1

tonf/in2

154.443 bar = 157.488 kgf/cm2

2

Numerical value equation: J = GD = Wr 2

4

Non-metric system

Non-metric system 1 lbf ft2

0.035 oz

1 kg

2.205 lb = 35.27 oz 1.102 sh ton = 2205 lb

SI system 1 kg

m2

Non-metric system

SI system

29.53 in Hg = 14.504 psi = 2088.54 lbf/ft2 = 14.504 lbf/in2 = 0.932 tonf/ft2 = 6.457 x 10-3 tonf/in2 (= 1.02 kgf/cm2)

Energy, work, heat Non-metric system

SI system

1 hp h

0.746 kWh = 2.684 x 106 J = 2.737 x 105 kgf m

1 ft lbf

0.138 kgf m

1 Btu

1.055 kJ = 1055.06 J (= 0.252 kcal)

SI system

Non-metric system

1 kWh

1.341 hp h = 2.655 kgf m = 3.6 x 105 J

1J

3.725 x 10-7 hp h = 0.738 ft lbf = 9.478 x 10-4 Btu (= 2.388 x 10-4 kcal)

1 kgf m

3.653 x 10-6 hp h = 7.233 ft lbf

Moment of inertia J.

0.907 t = 907.2 kg

1g 1t

4.788 x 10-4 bar = 4.882 x 10-4 kgf/cm2

SI system

1 oz 1 sh ton

0.069 bar

1 lbf/ft2

Torque, moment of force

1 km/h

Non-metric system

1 psi

SI system

1 m/s

Mass, weight

0.034 bar

1 bar = 105 pa = 102 kpa

1 cm3

SI system

1 in HG

m3/h

1 gallon

SI system

Non-metric system

SI system

0.04214 kg m2 Non-metric system 23.73 lb ft2



Power

Examples for decimal multiples and submultiples of metric units

Non-metric system

SI system

1 hp

0.746 kW = 745.70 W = 76.040 kgf m/s (= 1.014 PS)

1 ft lbf/s

1.356 W (= 0.138 kgf in/s)

1 kcal/h

1.163 W

1 Btu/h

0.293 W

1 km2 = 1000 000 m2; 1 m2 = 10 000 cm2; 1 cm2 = 100 mm2 1 m3 = 1000 000 cm3; 1 cm3 = 1000 mm3

Non-metric system

SI system

1 km = 1000 m; 1 m = 100 cm = 1000 mm

1 t = 1000 kg; 1 kg = 1000 g 1 kW = 1000 W

1 kW

1.341 hp = 101.972 kgf m/s (= 1.36 PS)

1W

0.738 ft lbf/s = 0.86 kcal/h = 3.412 Btu (= 0.102 kgf m/s)

Specific steam consumption Non-metric system 1 lb/hp h

0.608 kg/kWh Non-metric system

SI system 1 kg/kWh

SI system

1.644 lb/hp h

Temperature Non-metric system °F

°C

°F

K

5 9 5 9

°F

K

°F

(ϑF – 32) = ϑC ϑF + 255.37 = T Non-metric system

SI system °C

SI system

9 5 9 5

ϑC + 32 = ϑF ϑ T – 459.67 = ϑF

Note: Quantity

Symbol Unit

Fahrenheit temperature

ϑF*

°F

Celsius (Centigrade) temperature

ϑC*

°C

Thermodynamic temperature

T

K (Kelvin)

* The letter t may be used instead of ϑ


Contacts and Internet Addresses

General: Siemens AG www.siemens.de Power Transmission and Distribution (EV) www.ev.siemens.de/en/ Sales Locations Worldwide (EV) www.ev.siemens.de/en/pages/salesloc.htm International Business Development www.ev.siemens.de/en/pages/internat.htm

Technical: Power Engineering Guides Transmission and Distribution www.ev.siemens.de/en/pegtd Industrial Applications www.ev.siemens.de/en/peg97 Decentralized Energy Supply Systems

Gas-insulated Switchgear for Substations (GIS) Fax: ++49 - 91 31 - 7 3 44 98 e-mail: [email protected] www.ev.siemens.de/en/pages/gas-ins1.htm Gas-insulated Transmission Lines (GIL) Fax: ++49 - 91 31 - 73 44 98 e-mail: [email protected] www.ev.siemens.de/en/pages/gas-insu.htm Overhead Powerlines (OHL) Fax: ++49 - 91 31 - 73 35 44 e-mail: heinz-juergen.theymann@erls04. siemens.de High Voltage Direct Current Transmission (HVDC) Fax: ++49 - 91 31 - 73 45 52 e-mail: [email protected] www.ev.siemens.de/en/pages/hvdcinst.htm

e-mail: [email protected]

1

Power Transmission Systems

Fax: ++49 - 91 31-73 46 72 e-mail: [email protected] www.ev.siemens.de/en/pages/powersys.htm

2

High Voltage

www.ev.siemens.de/en/highvoltage Air Insulated Outdoor Substations (AIS) Fax: ++49 - 91 31-73 18 58 e-mail: [email protected] www.ev.siemens.de/en/pages/air-ins0.htm Circuit-Breakers Fax: ++49 - 3 03 86 - 2 58 67 www.ev.siemens.de/en//pages/high-vol.htm Surge Arresters Fax: ++49 - 3 03 86 - 2 67 21 e-mail: [email protected] www.ev.siemens.de/en/arrester

Primary Distribution Switchgear Fax: ++49 - 91 31 - 73 46 39 www.ev.siemens.de/en/pages/primaryd.htm Secondary Distribution Switchgear and Transformer Substations Fax: ++49 - 91 31 - 73 46 36 www.ev.siemens.de/en/secondar.htm

6

Protection and Substation Control

www.ev.siemens.de/en/secondarysystems www.powerquality.de Energy Management

www.ev.siemens.de/en/ powersystemscontrol

Power Network Telecommunication Fax: ++49 - 89 - 7 22 - 2 44 53 or ++49 - 89 - 7 22 - 4 19 82

8

Medium Voltage Devices Fax: ++49 - 91 31 - 73 46 54 www.ev.siemens.de/en/componen.htm Low Voltage Switchboards

Sivacon Fax: ++49 - 3 41 - 4 47 04 00 www.ad.siemens.de www.ad.siemens.de/cd/frameset/ e_f_sicube.htm

Metering

www.siemet.com

9

Industrial Load Center Fax: ++49 - 91 31 - 73 15 73

4

Power Transformers Fax: ++49 - 9 11 - 4 34 21 47 www.ev.siemens.de/en/powertransformers

Integrated IT Solutions Fax: ++49 - 9 11 - 4 33 - 81 22

Medium Voltage

www.ev.siemens.de/en/mediumvoltage www.ev.siemens.de/en/pages/decentra.htm

Transformers

Distribution Transformers Fax: ++49 - 70 21 - 50 85 48 www.ev.siemens.de/en/ distributiontransformers

7

Power Compensation Fax: ++49 - 91 31 - 73 45 54

3

5

Services

Fax: ++49 - 91 31 - 73 44 49 e-mail: udo.weber.erls04.siemens.de www.ev.siemens.de/en/services

10

System Planning

Fax: ++49 - 91 31 - 73 44 45 e-mail: [email protected] www.ev.siemens.de/en/systemplanning


Contacts and Internet Addresses

Subject to the “General Conditions of Supply and Delivery for Products and Services of the Electrical and Electronics Industry”. The technical data, dimensions and weights are subject to change unless otherwise stated on the individual pages of this catalog. The illustrations are for reference only.


Power to the

Power Transmission and Distribution Group P. O. Box 32 20 D- 91050 Erlangen

Siemens Aktiengesellschaft

Subject to change without prior notice

Order No. E50001-U700-A68-X-7600 Printed in Germany Dispo-Stelle 11900 TH 268-990061 200123 KG 89910.

Siemens Power Engineering Guide

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