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Smart Grid Watch

  • Shalin Shah 09/05/2017

    How Can Utilities and Society Benefit from Distributed Energy Resources?

    Source: The Energy Collective


    There are a lot of people who believe that distributed energy resources (DERs) are a fundamental threat to the utilities. This recent briefing report in The Economist is a case in point. However, we just hosted our second annual customer summit last week in Philadelphia with hundreds of thought leaders from the utility, regulatory, and technology industries to discuss the evolving 21st-century energy landscape. At the Summit, we explored business strategies around the growing distributed energy market and digitalization. During the opening day, we had thought leaders from two of the most dynamic states in the U.S. experiencing a lot of changes, and opportunities, in their energy systems and markets, namely New York and California.


    From New York, we had a former regulator who shared perspectives from the New York REV (Reforming Energy Vision) experience, while from California, we had a senior executive from the state’s largest investor owned utility, sharing perspectives from the California experience. Moreover, we closed the opening day with an industry panel with thought leaders who further enriched the discussions by providing perspectives from academia (MIT), and technology solutions providers point of views (Google Nest, NRG Station A, and Stem).


    Everyone understands that a utility’s core asset is the grid (i.e., utilities own the network) and the more things that are connected to the network, the more the network is used, the more value the grid can provide. Yes, it may be hard in utilities’ current business model structure to see that value returned to the owners of the grid, but it can be achieved if utilities do a few things differently. Utilities have to build the system differently for two-way intermittent variables and flows. Utilities have to deal with a lot of volatility in voltage, fluctuations in frequency, and the reduced reconfiguration and operational flexibility that all happens when you start putting more DERs onto the system.


    How should utilities be approaching these changes? By embracing agility in energy!


    By integrating intelligent technology at every level of its business model, including infrastructure and basic operations, efficiency and cost savings, and broader business model transformation through new products and services.


    1. Modernizing Infrastructure and Improving Operations: It may be easy to overlook the importance of modernizing existing power infrastructure, but the bottom line is that we cannot rebuild our power grid from scratch. We have to rely on intelligent technologies to improve the systems we have in place, improve power quality and security, and enable consumers to have a role in their power usage. All of our technologies from field automation devices to software integration and planning services give utilities unprecedented levels of control over their operations through both improved hardware and digital technologies.
    2. Enhancing Efficiency and Cost Savings: Focusing on digital technology drives efficiencies across a utility’s business by increasing the opportunity to integrate new renewable generation and distributed energies into their system. More importantly, intelligent management of grid assets can drive significant value through operational efficiencies with solutions, such as FLISR, GIS, OMS, and DMS.
    3. Driving Utility Transformation: The value to a utility goes far beyond basic operational enhancements or efficiency, ultimately leading to major change to the business value for the utility, typically reflected in the form of new products and services that are outside of the traditional utility model with solutions, such as DERMS and DRMS. The underlying premise of electric rates just about everywhere in the country is that the biggest value received is the electron, but nowadays at many customers’ homes, they get a lot of different products (e.g., solar PVs, EVs, etc.) from the grid than just the electron. Arguably, customers’ most valuable product nowadays is being able to put the excess electron onto the grid without having to call the utility to do so. It is also pretty convenient to be able to charge EVs any time. Consumers also get the benefit of the grid when their solar system goes down or when generation is way down due to the weather. These benefits start need to being reflected in the rates that many utilities charge their customers. If a customer cannot have access to and see the benefits and costs that they receive from the grid, then they are not going to make the right choices for themselves or for the grid as a whole.


    The goal is to give DERs the opportunity to provide that grid service that utilities otherwise would not get and put them into the toolkit as a viable energy alternative.

  • Shalin Shah 09/05/2017

    Consumer enablement: the future is now

    CAISO Duck Curve


    Source: Utility Dive


    Twenty years ago, everyone had a telephone connected to the outside world by a copper wire. Monthly bills were divided into charges for long distance and local calls. Now we pay for the speed of our data streaming. Yesterday’s telecoms are gone and a similar transition is happening in the energy space.


    In the near future, consumers will not be paying per electron consumed; they will be paying utilities for infrastructure maintenance and energy services. Utilities are exploring new business models and diversifying their revenue streams by charging for services that extend beyond traditional electron delivery.



    At the same time, utilities must also develop a foundational technology strategy to enable seamless interaction with consumers who are embracing the transformational promise of distributed energy resources (DER). DER growth challenges utilities, as they are now responsible for both managing power coming onto the grid while maintaining a reliable and stable network which may require limiting DERs.


    Utility demand response programs are a great example of an energy service that is applying new generations of artificial intelligence to manage loads available for time shifting such as heating and cooling loads, electric vehicle charging stations, swimming pool pumps, and smart appliances. Innovative utilities are working to improve grid efficiency through new offerings such as employing smarter devices piloted by enlightened consumers who are interested in improving their lifestyle, helping the environment and reducing their energy bills.


    Generation, transmission, and distribution are all being affected by the fundamental changes taking place in the utility industry. Consumer demand is leading the development of new ways to buy and use power. New software technology will need to be deployed within a utility to support the digital transformation that is giving rise to the era of customer enablement.


    Defining customer enablement

    As consumers turn their homes into miniature power plants they are transformed into “prosumers,” a breed of enabled producers/consumers who understand the concepts and financial incentives behind smart inverters, energy storage, and EV charging stations. Putting power generation in the hands of the people has released the genie from the traditional utility business bottle.


    “DER are typically owned by consumers not the utilities,” says Zack Derich, a senior product manager for Siemens. “The relationship with the utility that most people have is getting a bill in the mail and paying it. Changing that relationship is a new challenge for the utilities.”


    As more consumers invest in DER, visibility and management control becomes a vital concern for the utilities. The digital technology used for facilitating the fundamental shift in the utility/consumer paradigm is just emerging, with leaders, such as Siemens, offering tailored solutions based on the utilities specific needs.


    Ken Geisler, vice president of strategy and solutions for Siemens says, “With the right technology in place, you can intelligently manage two way flows on the lines while providing consumer enablement functionality. You’re building a flexible platform the utilities can build services on well into the future.”


    Why customer enablement is important to utilities

    In areas of the country with a high level of solar penetration, which includes California and especially Hawaii, grid operators are already wrestling with “Duck Curves” and “Nessie Curves” — colored lines on the load graph showing it rising in the morning, plummeting in the afternoon as solar arrays flood the grid with power, then rapidly shooting up as the sun sets and solar is no longer available.


    CAISO Duck Curve


    New Jersey has been a quiet and early leader in solar with more than a gigawatt of installed capacity. The pace of adding DER in the Garden State has amped up as commercial operators are taking advantage of affordable land in the southern half of the state and building solar farms, which adds an exponential impact to the effects of homeowners installing PV on their roofs. DER is rapidly expanding across the U.S. motivating all utilities to develop strong digital technology strategies to address new operational challenges.


    These developments are in some areas providing relief on costly distribution system upgrades, but in other areas are testing the limits of distribution infrastructure that was originally designed for the one-way flow of power. The challenges are compounded by fast moving clouds, sudden showers, and the threat of back feeding an abundance of uncontrollable energy onto an overwhelmed grid.


    Enhanced interaction with consumers combined with a two-way power and data exchange does offer promise to an industry looking for new ways to monetize. Geisler says, “We’re talking about taking a step toward a more complete services position where the utilities are selling comfort in your home by installing and maintaining systems such as the HVAC and the water heater.”


    What kind of technological support is needed?

    In the future, utilities, aggregators, and consumers may team up to fold in the cumulative effects of photovoltaic, electric vehicles, smart meters, and semi self-contained microgrids to form virtual power plants (VPP). The VPP concept connects millions of DER generating stations, which could be built on a cloud-based control center that interfaces to the billions of interconnected device loads linked through the Internet of Things. A holistic digital technology vision of the future.


    While the concept above sounds like something from the future, the work is underway and the technology foundation is available. Software solutions such as Advanced Distribution Management Systems (ADMS) and Distributed Energy Management Systems (DERMS) are already available and installed in a number of leading utilities to provide visibility, network management, and economic optimization of DERs on the grid. Geisler says, “In a business model sense, the utility is becoming an integrator of DER while providing the consumer with connectivity.”


    How Siemens can add value

    Siemens is currently developing the next generation of software that will facilitate an efficient and seamless transition toward wider use of DER including PSS SINCAL, a leading distribution planning software,  Spectrum Power™ platform products such as ADMS and DERMS, Energy IP applications such as Advanced Analytics and Meter Data Management, and substation automation through SICAM. These solutions allow for the aggregation of power from a variety of sources including traditional generation, while also opening up real time management and market integration.


    Siemens Integrated DER Portfolio

    Siemens Integrated DER Portfolio


    Derich says, “We’re talking about aggregating rooftop solar so a whole neighborhood acts as one, and then managing the aggregation by coordinating them to function as a virtual power plant that can participate in energy markets.”


    Siemens is already recognized as a worldwide leader in the energy management field, commanding a wide range of expertise in areas such as distribution planning, microgrid management, and utility software control. Scaling up more robust and dynamic energy management systems is a logical, market-driven step. “We are always seeking to be responsive to what our customers need,” says Geisler. “They are being pushed by technology that’s already in the field. We’re interested in this because our customers are interested.”



    Like the telecom industry before them, utilities are moving toward a new way of doing business. Consumers are becoming enabled to use their residences as smart consumers and producers of power. This change of balance is already affecting the grid in geographic areas where there’s a high penetration of solar power.


    Evolving to a service-based relationship between consumers and utilities will help the utilities by opening up new markets for goods and services. If utilities act now to develop a holistic, flexible, and scalable digitalization strategy, consumers and utilities will achieve both economic and clean power benefits well into the future.


    Learn more about leveraging Siemens’ extensive portfolio of digital grid solutions today.

  • Shalin Shah 09/05/2017

    A Tale of Two Power Outages: A Guide for Utilities to Do More With Less Using an Advanced Distribution Management System

    advanced distribution management system


    Source: Microgrid Knowledge


    Today’s distribution grid is characterized by evolving complexity. More and more resources are being added to the grid creating cost, reliability, and safety challenges. How can utilities better manage this complexity, especially at a time when they are being asked to do more with fewer resources? Advanced Distribution Management System (ADMS) software offers a one-stop shop to make it easier for utility management of distribution networks.


    A tale of two power outages

    This is the story of what happens on Main Street, USA when a power outage occurs – with and without an ADMS in place at the utility control center.


    Tale 1: The same old story

    A tree falls on a distribution line, knocking out power not only on Main Street, but also to a 50-square mile radius of surrounding rural area. The utility does not know where the tree limb came down – or even that it’s a fallen line causing the outage. It only knows that the call center is inundated with customer outage calls.

    They finally see the fallen tree. Fixing the line will take more time since the crew needs to call for more assistance. Back in the office, the operations personnel are evaluating maps and trying to determine if a plan can be generated to reconfigure the grid network to redirect some of the customers while repairs are being made. However, lacking real-time network telemetry data, they must rely on historical data that may be days or even months old.The utility sends out crews which begin the long process of patrolling the network. The crews are working with limited information – only what they learned from the outage calls – as they try to locate the source of the problem. The guesswork could take hours.


    Finally, the line is repaired, but the amount of time it took will reflect poorly in the utility’s annual performance review at the public utilities commission. Financial penalties are possible, on top of the expense incurred in sending multiple trucks to the scene for switching. Add to that the burden on utility staffing because of the time it took for the fault to be repaired.


    Tale 2: The alternative

    Now the same utility has deployed Siemens ADMS software at their control center to better manage growing grid complexity through data visualization to improve operational efficiencies and safety and to enable distributed energy resources (DERs) – all of which improve grid reliability in the face of natural disasters and other threats that could disrupt the flow of power, such as a tree knocking out a power line or an overabundance of solar power causing an overload.


    Immediately after the tree falls and the power goes out, the ADMS system becomes aware of the outage from a social media post and/or telemeterry data from SCADA. (Photo: Siemens)


    Immediately after the tree falls and the power goes out, the ADMS system becomes aware of the outage from a social media post and/or telemeterry data from SCADA. The ADMS notifies the control center operator by indicating the problem on the system dashboard through an alarm. Due to the software’s ability to narrow the location of the outage based on information from grid devices and evaluate the surrounding network’s available capacity, the ADMS system can automatically plan and execute a switching scheme to reroute power using alternative feeder lines. Within seconds, power is restored to all of the customers beyond Main Street. Only the customers that are affected by the small section of network that the tree damaged are out of power. The outage has been isolated and the self-healing grid functionality within ADMS has done its job to minimize the outage footprint in seconds.


    Prescriptive analytics automatically determines next steps & helps restore power within seconds

    Ingesting data at high speed and volume from monitoring devices on the electrical distribution grid is the first step. Next, the ADMS adds real-time situational data from the distribution network to inform real-time decisions made by network operators. This could include data, such as renewable generation capacity or social media information. Finally, the ADMS software applies prescriptive analytics based on utility business rules to automatically determine the best steps for a utility operator to isolate the problem and resolve it. The goal is to capture value quickly by ensuring electricity service to as many consumers as possible. The ADMS software planned and executed a switching scheme to reroute power using alternative feeder lines. Within seconds, power was restored to all of the customers beyond Main Street. The outage is now isolated and crews are assigned out to repair.


    Utilities must plan to implement scalable and flexible software technology to enable future capabilities while maintaining reliable, safe, and efficient grids.


    In conclusion

    As DERs continue to grow and regulatory requirements change, utilities are faced with more distribution grid management challenges than ever before. Utilities must plan to implement scalable and flexible software technology to enable future capabilities while maintaining reliable, safe, and efficient grids.


    Download a complimentary whitepaper on “Managing Evolving Complexity on the Electric Distribution Network,” and learn how utilities are doing more with less by using Siemens Spectrum Power Advanced Distribution Management System.

  • Harald Mayer 29/03/2017

    Siemens Customer Support Center: Unterstützung wenn man sie braucht

    Das Siemens Customer Support Center ist verantwortlich für alle Kundenanfragen im Bereich Energieübertragung und –verteilung; von Standardanfragen bis hin zu komplexen technischen Fragen aller Kundengruppen von Energy Management.


    Kundensegmente wie beispielweise Energieversorger und Industriekunden werden durch gut ausgebildetes Personal betreut. Dieser kostenlose Service wird 24/7 angeboten. Die Erfolgsfaktoren sind das über Jahrzehnte aufgebaute Know How im Bereich der Nieder-, Mittel- und Hochspannung.


    Um Kunden bestmöglich zu unterstützen, ist das Customer Support Center als dreistufiges System aufgebaut.


    Auf der ersten Ebene werden alle Anfragen aufgenommen, klassifiziert und die prozesskonforme und schnellstmögliche Weiterleitung an Fachexperten in der zweiten Ebene sichergestellt.


    Die meisten Anfragen werden auf der zweiten Ebene beantwortet. Falls nötig, werden Experten aus einer dritten Ebene aus den Entwicklungsabteilungen mit eingebunden.


    Dank der 24/7 Verfügbarkeit ist sichergestellt, dass der Kunde schnellstmöglich Unterstützung erhält. Für kritische Fälle oder Expertensupport während der Nacht wird empfohlen einen Rufbereitschaftsvertrag mit dem CSC abzuschließen. Dieser Vertrag beinhaltet z.B. zugesicherte Reaktionszeiten in Notfällen.


    Der Kunde bekommt eine eigene Telefonnummer über die er im Customer Support Center als Vertragskunde identifiziert wird. Bei Anruf erhält er die vertraglich zugesicherte Leistung; von der technischen Unterstützung per Telefon bis hin zum Einsatz eines Servicetechnikers vor Ort.


    Die Fehlervermeidung kann u.a. durch den Einsatz von Fernüberwachungssoftware unterstützt werden. Diese erkennt Trends welche auf die Entstehung eines Anlagenfehlers hinweisen. Dadurch können Maßnahmen rechtzeitig ergriffen werden bevor es zu einer Störung kommt.


    Weitere Informationen zum CSC finden Sie hier.


    Haben Sie Fragen? Bitte kontaktieren Sie uns um direkt mit unseren Experten in Kontakt zu treten.


    Sie können sich gerne für unseren Newsletter registrieren.

  • Harald Mayer 29/03/2017

    Siemens Customer Support Center: Support when you need it

    The Siemens Customer Support Center is in charge of all customer inquiries in the area of power transmission and power distribution technology. The requests range from standard inquiries up to complex technical questions.


    Customer segments such as utilities, transmission companies and industrial customers are served by well trained support agents. This free of charge service is offered 24/7. The key success factor is know-how based on decades of experience in low, medium and high voltage equipment.


    In order to serve customers in the best possible way, the Customer Support Center is built up  in three support levels:


    The first level takes up all inquiries, classifies them and ensures a proper routing to the experts in the second level.


    Most inquiries are solved on the second level.  If further support is needed, development departments (3rd level) are engaged where the most critical issues are solved.


    Due to the 24/7 availability the client gets support as soon as possible. If a customer requires guaranteed prompt support, by phone or even on-site around the clock, it is recommended to sign an on-call-duty contract with the CSC, that includes e.g. contractually agreed reaction times. This ensures an immediate action in case of an emergency and peace of mind for the customer.


    The client has a separate phone line where he is identified and gets the contractually defined support which covers technical support by phone or even on-site engagement in order to solve the client´s problem.


    To detect upcoming failures before they may cause serious damage, the Customer Support Center offers in addition remote monitoring. The CSC is connected to the customer´s assets via remote monitoring software and monitors their condition 24/7.


    Learn more about the CSC from Siemens Customer Services.


    Questions, please comment below or contact us to get directly in touch with our experts.


    Subscribe to the Energy Management Services Newsletter.

  • Harald Mayer 29/03/2017

    Assetguard MVC: Siemens hält ihre Leistungsschalter einsatzbereit

    Mittelspannungsleistungsschalter kommen nicht täglich zum Einsatz. Wenn sie benötigt werden, müssen sie allerdings absolut zuverlässig funktionieren um negative Folgen sowohl für den Betreiber, als auch die Infrastruktur selbst zu vermeiden. Wenn Leistungsschalter nicht regelmäßig gewartet werden, oder besonders harten Umweltbedingungen ausgesetzt sind, kann deren Mechanik eine erhöhte Störanfälligkeit entwickeln, die in seltenen Fällen zum Ausfall führt.


    Durch die automatisierte Überwachung von Mittelspannungsleistungschaltern kann deren Zuverlässigkeit erhöht und der Wartungsaufwand gleichzeitig reduziert werden. Die herkömmliche, regelmäßige Durchführung von Messungen kann nicht annähernd die Sicherheit einer lückenlosen Überwachung durch Assetguard gewährleisten. Assetguard MVC überwacht die Hilfskreisspannung, die Einschaltspule und die Auslöserspulenströme.


    Das Verhalten während der Schaltvorgänge wird präzise gemessen, aufgezeichnet und im internen Speicher archiviert. Die Datendiagnose erfolgt durch den Vergleich der erfassten Daten mit den kundenseitig vorgegebenen Schwellwerten, so dass Abweichungen frühzeitig erkannt werden können. So lässt sich z.B. abnormes Verhalten der Spulen erkennen, Wartungsbedarf im mechanischen Antrieb ermitteln, der Verschleißzustand (Störlichtbogen I2t) der Kontakte beurteilen und Betriebsstörungen aufgrund von Betriebsspannungsproblemen feststellen.


    Dank frühzeitiger Alarmierung im Falle einer Funktionsstörung kann der Betreiber zielgerichtete Wartungsmaßnahmen veranlassen, bevor der Schalter Schaden nimmt, und eventuell hohe Folgekosten entstehen. 


    Mit einem einzigen Assetguard MVC-Einschub lassen sich bis zu 12 Leistungsschalter überwachen. Für größere Systeme werden MVC-Master mit Slave-Einheiten eingesetzt, mit der sich jeweils bis zu 60 weitere Leistungsschalter zusätzlich überwachen lassen.


    Alle funktionalen Komponenten sind als Einschub in einem gemeinsamen, robusten Gehäuse untergebracht (Stromversorgung, Datenerfassungstechnik und Datenspeicher, Glasfaser- Kommunikationstechnik und Webserver).


    Assetguard MVC kann an unterschiedliche Bedarfe angepasst werden:

    • Integration in SCADA-Systeme (optional),
    • Spulenmonitoring und Redundanzkanalfunktionen
    • Einstellung der Digitalfilter-Grenzfrequenz entsprechend der Umgebungsbedingungen.
    • Optionale externe Sensoren auf Anfrage (z.B. zur Temperatur- oder Feuchtigkeitsmessung, zur Überwachung von SF6-Gas, zur Transformatorenüberwachung (Einzelgas-DGA (H2), IEC-Temperaturabschätzung und DGA-Sensor SITRAM H2Guard Einzelgas)


    Die erweiterte MVC-Version bietet zusätzliche Softwarefunktionen wie beispielsweise Spulenstrom-Trenddiagramme und Plotter mit Zoom-Funktionalität. Auch der Export der erfassten Daten in Excel-Format ist möglich.


    Siemens plant, installiert und nimmt die komplette Ausstattung in Betrieb.


    Zusätzlich bieten Siemens seinen Kunden:

    • 24/7 Kundenbetreuung
    • Analyse der Überwachungsdaten durch Experten und
    • Schulungen vor Ort für Betrieb und Wartung des Assetguard MVC.


    Weitere Informationen zu Assetguard MVC finden Sie hier.


    Haben Sie Fragen? Bitte kontaktieren Sie uns um direkt mit unseren Experten in Kontakt zu treten.


    Sie können sich gerne für unseren Newsletter registrieren.

  • Harald Mayer 29/03/2017

    Keeping Circuit Breakers Ready to Respond: Assetguard MVC

    Medium-voltage circuit breakers aren’t called into action every day. However, when they are needed, they absolutely must work reliably, to prevent impacts to customers or utility assets. If these devices are not maintained and tested regularly, or if they endure harsh conditions or traumatic events, their mechanical parts become prone to sticking or failure.


    Automated monitoring of medium-voltage circuit breakers helps safeguard overall system reliability while reducing maintenance costs. Assetguard MVC from Siemens monitors the behavior of circuit breakers during tripping and closing operations, as well as wear on arcing contacts. Both the basic and extended versions provide guaranteed monitoring of auxiliary circuit voltage, as well as closing and tripping coil currents. The traditional approach of taking periodic manual measurements cannot be equal to this level of timeliness and certainty.


    Precise measurements are gathered during each switching operation, and data is recorded in internal memory. New test results are compared to prior data to check for anomalies. For instance, Assetguard MVC can detect defects in coil behavior, or incorrect operation due to operating voltage problems. The system can give information useful to address the maintenance to mechanical or electrical aspects.


    Assetguard MVC transmits timely alerts of circuit breakers that either have failed or might be about to fail. This allows system operators to dispatch targeted maintenance teams before costly outages or damage occurs.


    Each Assetguard MVC unit can monitor up to 12 circuit breakers. For larger power systems, a master unit can host several slave units. A master-slave system can monitor up to 60 circuit breakers.


    The rugged housing for a central node unit integrates a power supply, data acquisition, fiber optic communication, data storage and a web server; as well as an external current transducer sensor. A combination of hardware and digital filters provide superior noise immunity performances.


    Assetguard MVC can be customized in many ways:

    • Optional SCADA integration, coils monitoring and channel redundancy
    • Custom digital inputs
    • Cutoff frequencies of digital filters can be configured for any environment
    • Optional external sensors can be integrated in the system to monitor humidity or temperature, SF6 gas and key transformer conditions
    • Basic transformer condition monitoring can be easily integrated: Single-Gas DGA (H2), IEC Thermal Estimation and DGA sensor SITRAM H2Guard single-gas
    • Extended Assetguard MVC offers additional software functionalities, such as coil current waveforms history, and plotter with zoom.
    • Data acquisitions can be instantly exported in spreadsheet format.

    Siemens provides design, installation and commissioning of Assetguard MVC at the substation.


    We also offer:

    • Customer support
    • Expert analysis of monitoring data
    • On-site training in Assetguard MVC operation and maintenance


    Learn more about Assetguard MVC from Siemens Customer Services.


    Questions, please comment below or contact us to get directly in touch with our experts.


    Subscribe to the Energy Management Services Newsletter.


  • Harald Mayer 29/03/2017

    SVEPPI Prüflabor: Die Testumgebung für Anlagen der Übertragungs- und Verteiltechnik

    Anlagen der Energietechnik sind beträchtlichem Verschleiß und Abnutzung ausgesetzt – deshalb müssen sie robust genug sein um extreme klimatische Bedingungen und Wettereinflüsse, aber auch Veränderungen der Lastflüsse auszugleichen. Die gründliche Prüfung von Anlagen und Komponenten ist entscheidend für die Sicherstellung von Widerstandsfähigkeit und Verfügbarkeit dieser Anlagen.


    Seit 2008 führt Siemens im SVEPPI Prüflabor (in der Nähe von Venedig, Italien) dielektrische, thermische und mechanische Belastungsprüfungen durch. Diese Prüfungen stellen sicher, dass Transformatoren, Schaltanlagen und andere elektrische Infrastruktur die geltenden Normen von IEC (International Electrotechnical Commission) und der EU einhalten.


    Die Prüfgeräte des SVEPPI Labors sind in der Lage elektrodynamische Belastungen bis zu 80kA einphasig (mit Stromspitzen von 200kA) oder bis zu 50kA dreiphasig (mit Stromspitzen von 135kA) zu simulieren.


    Im SVEPPI Labor werden vor allem Verteiltransformatoren (mit bis zu 10/15 MVA), Mittelspannungsleistungsschalter und -schaltanlagen (bis zu 24 kV), 16kA Stromwandlerpole und Trennschalter mit Kurzschlußstrom bis 80kA, sowie Isolatoren für Hochspannungsfreileitungen getestet.


    Über die technischen Möglichkeiten hinaus, ist das SVEPPI Prüflabor auch für seine Flexibilität, Geschwindigkeit und Wettbewerbsfähigkeit bekannt. Die technologische Ausstattung entspricht den neuesten Standards und lässt sich schnell an neue Ideen von Produktdesignern anpassen.


    Ein neuer Fokus des SVEPPI Prüflabors liegt auf der Prüfung von Anlagen hinsichtlich Monitoring und Diagnostik. Letztlich hilft dies die Betriebseffizienz von Schaltanlagen in Echtzeit zu prüfen und Einschätzungen bezüglich der Restlebensdauer zu treffen.


    Das SVEPPI Prüflabor unterstützt außerdem die angewandte Wissenschaft – einschließlich der Prüfung von Komponenten für den Einsatz in der Energieerzeugung durch Kernfusion, oder um den Herstellungsprozess zu verbessern.


    Weitere Informationen zu SVEPPI finden Sie hier.


    Haben Sie Fragen? Bitte kontaktieren Sie uns um direkt mit unseren Experten in Kontakt zu treten.


    Sie können sich gerne für unseren Newsletter registrieren.

  • Harald Mayer 29/03/2017

    SVEPPI Laboratory: Siemens puts distribution assets to the test

    Power distribution assets endure considerable wear and tear — so they must be robust enough to withstand harsh climates and severe weather events, as well as ongoing and sudden grid challenges. Thorough testing of assets and components is a critical part of ensuring resilience and reliability.


    Since 2008 at the SVEPPI Laboratory (located just outside Venice, Italy), Siemens has been conducting dielectric, thermal and mechanical performance tests of substation devices and components. These tests certify that transformers, switchgear and other key types of power equipment conform to International Electrotechnical Commission and EU standards. 


    Testing equipment at SVEPPI can apply electrodynamic stresses up to 80 kA in single-phase (with current peak over 200 kA), or up to 50 kA in three-phase (with current peak of 135 kA).


    The types of equipment tested at SVEPPI primarily include distribution transformers (up to 10/15 MVA), medium voltage circuit breakers and switchgear (up to 24 kV), 16 kA pole of current transformers and disconnectors with short time current up to 80 kA, and short chains of insulators for overhead high voltage transmission lines.


    But beyond its technical capabilities, SVEPPI is also notable for flexibility, speed and competitiveness in testing. Technology at the laboratory keeps pace with fast-changing test requirements, and can adapt quickly to new ideas from product designers or partners.


    A newer focus of work at SVEPPI is testing related to monitoring and diagnostics for transmission and distribution assets. Ultimately, this helps make it easier to verify the operating efficiency of substations in real time, and to update estimates of remaining useful life.


    SVEPPI also supports applied research — including testing components used in nuclear fusion experiments, or helping to improve manufacturing processes.


    Learn more about SVEPPI. Download the brochure


    Subscribe to the Energy Management Services Newsletter


    Questions? Please contact us to get directly in touch with our experts.