What is the Scope of the IEC 61850 Series?

The seven IEC 61850 CDVs published the other day (7-4, 7-4n and 7-4nn) use all the same Scope which starts:

Excerpt from:

Communication networks and systems for power utility automation – Part 7-4: Basic communication structure – Compatible logical node classes and data object classes – Core

-------------

1.1 General

This part of IEC 61850 specifies the information model of devices and functions generally related to common use regarding applications in systems for power utility automation. In particular, it specifies the compatible logical node names and data object names for communication between intelligent electronic devices (IED). This includes the relationship between logical nodes and data objects.

...

This standard and its direct counterparts (7-4, 7-4n and 7-4nn) are applicable to describe device

models and functions for:

• substation and feeder equipment,
• substation-to-substation information exchange,
• substation-to-control centre information exchange,
• power plant-to-control centre information exchange,
• information exchange for distributed generation,
• information exchange for distributed energy resources,
• information exchange for metering,
• information exchanged for hydro power plants, or
• information exchange for wind generation plants.

--------------

The main title of all parts of the series IEC 61850 is: 

Communication networks and systems for power utility automation 

This title is some how an indication of the scope.

IEC 61850 can be used everywhere as follows:

Communication networks and systems for power utility automation

The narrow scope to power utilities is sometimes used by people that do not like the IEC 61850 series ... or do not want to let people outside the power utilities to apply it ... 

But the crucial content of the many different parts is applicable in most automation domains ... where ever electric power is found - buildings, factories, ... 

A lot of Logical Nodes, e.g., STMP (Supervision of Temperatures) are useful for transformers, bearings, tanks, ... 

Lessons learned:

1. The various parts of IEC 61850 are applicable far beyond of the written scope - if you like it or not.
2. Often the discussion related to the scope is aimed to tell you, that IEC 61850 is not applicable outside power utilities (or substations) - trust me: it is applicable far beyond.

By the way, the discussion of scopes could be ridiculous: IEC 60870-5-104  defines:

"This part of IEC 60870 applies to telecontrol equipment and systems with coded bit serial data transmission for monitoring and controlling geographically widespread processes. It defines a telecontrol companion standard that enables interoperability among compatible telecontrol equipment"

IEC 60870-5-104 does not have substation automation (usually not a widespread area) in its scope - BUT, you know 104 is used as the communication inside many substations! Ok ... why not. But then also IEC 61850 can be used for telecontrol ... see IEC 61850-80-1, ...
In the wind power industry it was discussed some 20 years ago: IEC 61850 is not applicable for wind turbines, because wind turbines are not substations ... hahaha

Enjoy IEC 61850!

IEC 61850 in Cyber Secure Environments - New Comprehensive Seminar

Due to my family situation (nursing my beloved wife from 2017 to 2022) I had to slow down my training activities. This year I was asked by several senior experts if it would be possible to resume the training.

As a result of discussions with friends of mine, we updated our previous course program and offer a brand new 5-day comprehensive public seminar for Automation, Protection, Monitoring, Engineering, Configuration (SCL), SCADA, Smart Grids, RTU, Gateways, … cyber physical security in electrical systems of any industrial plant … it is available for you and your people.

The reason for the update: We want to do more than teaching the theory of IEC 6850 and demonstrate single IEDs … we want to let our practice talk for your practice. The new training will start in March 2026. Taking the experience with many crucial applications of IEC 61850 into account we offer a new program for a 5-day course conducted by four (4) real experts.

09.-13. March 2026, Karlsruhe (Germany)
21.-25. September 2026, Karlsruhe (Germany)

Click HERE for more details on dates, location, and registration information.

Object Modeling in the late 1980s - Too Early!

One of the crucial aspects of the standard series IEC 61850 is about object modeling ... first versions have been published in the year 2004 ... guess you agree!

Did you know that object modeling for process automation was already defined to some degree in the late 1980s for the standard ISO/IEC 9506-6 (MMS Companion Standard for Process Control) - published in the year 1994? Maybe you are surprised ... you may even have been born after that time ... 

The other day I have documented the following example of supervision of rate change of a process measurement:

On the bottom the MMS Named Variable C_PVRCPAP is shown. The semantic (setting for a specific event) is equivalent to the "Temperature rate alarm trigger level setting" of the LN class STMP in IEC 61850-7-4 Ed2.1. The definition in MMS part 6 is generic and applies to any measurement.

I would say that the MMS companion standard ISO/IEC 9506-6 was some 30 years too early published ... mainly due to the fact that many engineers did not understand abstract object modeling. 

History repeats itself, which is good because most people don't pay attention the first time anyway.

And today? Hope you have a better understanding! In case you need help ... let me know.

The semantic of the huge amount of signals in IEC 61850 or the few in the old ISO/IEC 9506-6 make the difference compared to most protocols like IEC 60870-5-104 and ... 

IXXAT (HMS) Offers New POWERFUL Smart Grid Gateways for IEC 61850, IEC 60870-5, Profibus and more

Under the IXXAT brand, HMS delivers connectivity solutions for embedded control, energy, safety and automotive testing.
The new and very powerful IIoT gateways from HMS allow industrial equipment to communicate with power grids based on IEC 60870-5-104 and IEC 61850. In addition they also include Modbus TCP Client/Server and Modbus RTU Master/Slave


IXXAT SG-gateways...

• enable easy remote control and management of electrical systems
• allow to log and display application data and energy consumption
• provide IEC 61850 client/server and IEC 60870-5-104 server support
• have in-built Modbus TCP Client/Server and Modbus RTU Master/Slave interfaces
• provide connectivity for CAN Bus, I/O, M-Bus, PROFIBUS, PROFINET and EtherNet/IP based devices

Click HERE for more details in English
Hier klicken für Details in Deutsch

Final Call for IEC 61850 Training Courses in May 2017 in Karlsruhe (Germany)

The following two training courses are just one (two) weeks away:

02.-05. May 2017, Karlsruhe/Germany:


Click HERE for details - and register as soon as possible.

09.-12. Mai 2017, Karlsruhe/Deutschland
HIER klicken - für Details zum Training in Deutsch

Dubai (UAE): NEW IEC 61850 Seminar for Protection, Control, and Generation

You are invited to register for one of the world leading IEC 61850 Seminars for Protection, Control, and Generation to be conducted by

FMTP, Al-Ojaimi, and NettedAutomation 
in Dubai (UAE) at the Sheraton Dubai Mall of the Emirates
11-13 July 2017

With the focus on protection and control in HV/MV substations, power generation (PV, Wind, DER, Hydro), distribution systems using Client/Server, GOOSE, SV, SCADA and SCL Language covering:

• IEC 61850 / IEC 61400-25 Introduction (Edition 1, 2, and 2.1) and experience after more than 10 years in operation. Where are we today?
• Return of experience, applications and practical demonstrations:
• Protection and Control in Substation Automation
• Engineering and Configuration
• Maintenance
• Monitoring and SCADA system
• Specification of the IEC 61850 protection and control system.
• Through the practical demonstrations, you will learn:
• To handle IEC 61850 relay protections from different vendors and their software tools; to be able to efficiently manage flexibility in engineering and interoperability.
• To use the state of the art IEC 61850 testing tools and equipment to efficiently detect the technical problems and work-out their solutions.
• To understand SCL files, setup clients and servers for MMS communication to SCADA and RTU Systems
• All the presentations are supported by practical examples or demonstrations.

Who should attend?

• Protection and Electrical Engineers (protection, control, engineering, SCADA, asset managers)
• System integrators
• Product managers of vendors
• R&D engineers
• Maintenance personnel
• Experts responsible for network infrastructure

Click HERE for program and registration information.
Click HERE for other training opportunities.

HMS Smart Grid Gateways Are Now IXXAT SG Gateways

The HMS Smart Grid Gateways (supporting a wide range of standards like IEC 60870-5-104, IEC 61850, Modbus TCp/IP, ...) are now marketed by HMS under the HMS brand IXXAT Energy SG Gateways.
IXXAT SG-gateways... 

• enable easy remote control and management of electrical systems
• allow to log and display application data and energy consumption
• provide IEC61850 client/server (publisher/subscriber) and IEC60870-5-104 client/server support
• have in-built Modbus TCP client and Modbus RTU Master interfaces
• provide connectivity for I/O, M-Bus, PROFIBUS, PROFINET and EtherNet/IP based devices

Click HERE for more details [EN]
Click HERE for more details [DE]

Case Study - IEC 61850 Application for a Transmission Substation in Ghana

A lot of discussions about the benefits of using IEC 61850 have happened in the past and are still going on ... and will go on also in 2017 and beyond.

A nice paper has been presented some three years ago:

Case Study: IEC 61850 Application for a Transmission Substation in Ghana

"One of the benefits of implementing IEC 61850 is minimizing or even eliminating the copper field wiring used to exchange protection and control data between intelligent electronic devices (IEDs) across a substation. Conversely, implementing IEC 61850 has introduced commissioning, testing, and maintenance complexity that can be alleviated with proper training, documentation, and testing plans. The design and implementation of the Kintampo, Ghana, transmission substation required redundant protection and control functions distributed among the IEDs and a robust communications network to implement IEC 61850 protocols. ...
As the acceptance of IEC 61850 communications by utilities grows, this type of large-scale project will grow as well. ...
A system solution that is repeatable, pre-engineered, pretested, and designed to specifications is extremely important because it provides the user with a standardized solution that can be implemented across the system, minimizing different designs."

Click HERE for the 10 page paper [pdf]

Want to Understand one of the Largest Machines - The Interconnected European Electric Power Grid?

The Interconnected European Electric Power Grid is one of the biggest machines built by humans. It has been developed over a period of about some 130 years. It is a miracle that it is still working very stable and more or less uninterrupted form many years.

The challenge for the future is this: How to keep the power flowing, the grass green and the sky blue. I met with a retired - but still very active - power engineer yesterday. We discussed how more information technologies can be used to support a very reliable automation system to provide 24x7 power flow all over in Europe. We have figured out that one of the key challenges in the discussions is to find the correct language in our discussions. I mean: When I talk about preventing any "remote control command", what does the recipient of that term understand? We figured out that we have discussed this term for years - but did have a different understanding in mind!

Fortunately we solved our disconnect and were happy that we have the same understanding. We will use a new (or just another) terms to make sure that other people will understand what we want to say.

A "remote control command" an mean:

1. Switch on the electric heater of heat storage system  or
2. Allow the local controller of the heat storage system to draw electric power when the local controller sees a need to heat the storage.

In the first case the electric power will immediately flow. In the second, it may or may not - depending on the local situation. Not all heater will start immediately at the same time to heat.

In case we use the term "remote control command" for the first application only, we will not be understood by many people. Because - I guess - most people would say: In both use cases we send a "remote control command" to the remote system.

What is the real underlying difference of the two use cases? The first one has a direct impact on the power flow, while in the second there is a local control system involved to decide what to do. Let´s assume we have 1000 heaters of a total power of 10 MW. In the first use case we have an immediate power flow rate of 10 MW per a few seconds. In the second case it is a stochastic situation where some may immediately draw the power others may draw power one hour later ...

Finally: If we would have smart systems, then the local controller would be situationell aware of the condition of the power system: if the frequency or voltage would be below specific set-points, then they would not draw power at all ...

If you would like to learn more about the huge machine "Interconnected Electric Power Delivery System":

Click HERE to watch a video [with English translation] which discusses some basics of the complexity ... enjoy.
Click HERE for the version in German.
Click HERE for more options.

Proxy and Gateway Approach of IEC 61850

A Proxy Server in the sense of IEC 61850 exposes the very same information models of many IEDs through a Server that uses the same Logical Device/Logical Node names (references) as in the IEDs that are “mirrored” or “proxied”.

There is no difference in the meaning and syntax between the models in the various IED Servers and the Proxy Server.

The general gateway approach is quite different. I a gateway we are free to manage information like:

1. Translate data from legacy protocols such as IEC 60870-5-103, IEC 60870-5-104, IEEE 1815 (DNP3), IEC 61158-6 (Modbus), etc. into IEC 61850 data model
2. Add data local to the IED hosting the Proxy/Gateway
3. Rename logical devices coming from IED level into logical device server
4. Rearrange/Rename logical nodes coming from IED level into logical device of the Proxy/Gateway server
5. Merge of two or more information objects coming from two or more different logical nodes at IED level into one logical node of the Proxy/Gateway server
6. Split of information objects coming from one logical node at IED level into two or more logical nodes of the Proxy/Gateway server where each logical node contains a subset of the information objects of the original logical node
7. Transform a generic information object (e.g. GGIO, GAPC, etc.) at IED level into a semantically defined information object of the Proxy/Gateway server
8. Convert a specific information object (e.g. MMTN) at IED level into another semantically defined information object (e.g. MMXU) of the Proxy/Gateway server
9. Adapt the scale, information encoding and dead band configuration between the IED data object and the data object in the Proxy/Gateway server
10. Logical (e.g. and, or, if/else, grouping of indications, etc.) and arithmetic (e.g. multiplication, division, addition, subtraction, etc.) transformations between one or more data objects at IED level and one or more data objects of the Proxy/Gateway server

Real IEDs may have gateway and proxy functions.

Click HERE for very simple and easy to use proxies and/or gateways for IEC 61850, IEC 60870-5-104, Modbus, Profibus, Profinet, … offered by HMS. These can be understood as Micro-RTU …

Substation to Control Center Communication: IEC 61850-90-2 TR Approved

The draft Technical Report for Substation to Control Center Communication has been approved by 100 %:

IEC 61850-90-2 TR:
Communication networks and systems for power utility automation - Part 90-2: Using IEC 61850 for the communication between substations and control centres

The final Technical Report will be published in December 2015. It provides a comprehensive overview of the different aspects that need to be considered while using IEC 61850 for information exchange between substations and control or maintenance centres or other system level applications. In particular, this technical report:

• defines use cases and communication requirements that require an information exchange between substations and control or maintenance centres
• describes the usage of the configuration language of IEC 61850‑6
• gives guidelines for the selection of communication services and architectures compatible with IEC 61850
• describes the engineering workflow
• introduces the use of a Proxy/Gateway concept
• describes the links regarding the Specific Communication Service Mapping (SCSM)

The wait for the application of IEC 61850 for information exchange between substations and control centers is over – starting in 2016, there is no excuse any more.

The scope of the TR is quite limited: Substation (only!) to control centers. The future energy delivery system (in which power is one aspect only) will build a hierarchy of aggregated information systems. There will be several layers of information management systems. This is required because of the use of IEC 61850 from power distribution all the way up to the transmission system operator. Information needs to be aggregated because of the sheer unlimited amount of information generated and consumed in the system.

It is likely that the TR 90-2 will be used for other vertical information flows between aggregation points and higher level systems. A subset of the TR 90-2 may be used for information exchange between a control center and a wind power plant.

The restricted scope in the TR 61850-90-2 is just toner on paper – like in almost all IEC 61850 parts. A server in the sense of IEC 61850 can expose any data from any application. IEC 61850 relies on ISO 9506 (MMS – Manufacturing Message Specification). As the name says: MMS (and IEC 61850) can be used for manufacturing and many other domains.

The main scope of IEC 61850 is constrained by the title: “… for power utility automation”. From a technical point of view we could leave only “… automation”:

“Communication networks and systems for automation” – BUT this would never be accepted by the IEC officials. Automation as such is not the scope of IEC TC 57.

MMS is not restricted to “Manufacturing” and IEC 61850 is not restricted to “power utility automation”.

Draft IEC 61850-90-2 for Substation to Control Center Communication published

The substation (or power plant or …) to control center communication is historically based on hundreds of protocols. Among those you will find also protocols like IEC 60870-5-101, IEC 60870-5-104 or DNP3. The original scope of IEC 61850 was (politically) restricted to substations. From a technical point of view it was expected from the very beginning of the work on IEC 61850 that it could be used also for this and many other use-cases.

After several years of work on the official document it is now available for final vote:

57/1578/DTR (164 pages):
IEC 61850-90-2 TR Ed.1
Communication networks and systems for power utility automation –
Part 90-2: Using IEC 61850 for the communication between substations and control centres

The voting ends on 2015-07-24

This document is very important for the communication with control centers. It covers crucial aspects:

1. Information modeling (proxy/gateway),
2. Information models (use of existing models and extensions)
3. Configuration language and engineering,
4. Information exchange services (redundancy, …)
5. Security aspects

for the following use-cases:

1. Telecontrol
2. Synchrophasor
3. Disturbance
4. Counting
5. Power Quality
6. Asset
7. Parameter configuration

The document contains many examples that help to understand the different use-cases.

This document closes one crucial gap in the information exchange of many different systems, e.g., substations, power plants, hierarchical control centers, with control centers.

The most crucial aspect is the application and extension of SCL (System Configuration Language – IEC 61850-6).

Several useful extensions are defined, e.g., the link between a proxy/gateway model and the original model. To support end to end testing through the Proxy/Gateway functional links between the data objects in the Proxy/Gateway server and the original source of information in a substation IED can be expressed as the following example shows:

<LN lnClass="MMXU" lnType="MMXU" inst="1">
   <Private type="eTr-IEC61850-90-2">
      <eTr-IEC61850-90-2:ProxyOf externalScl="Substation" iedName="IED2" ldInst="MEAS"
      lnClass="MMXU" lnInst="1"/>
   </Private>
</LN>

Links can be created on each level of the data model using the element:

eTr-IEC61850-90-2:ProxyOf

This new part contributes to the vision of a SINGLE seamless information exchange solution for the whole domain of power delivery (generation, transmission, distribution, use).

VHPready Signal MMXU1.TotW.instMag – versus IOA 113

Signals configured in IEC 61850 and configured in IEC 60870-5-104 look quite different.

The following figure shows the same signal (Current electric Power – Aktuell erzeugte elektrische Leistung) in IEC 61850 (left) and IEC 60870-5-104 (right):

The IEC 61850 model exposes the value, quaity and timestamp as well as the semantic (TotalWatt). The total watt of what? Of the “Current electric Power – Aktuell erzeigte elektrische Leistung” as described in the DC (description of the signal).

On the other side we have the information object address (IOA = 113) that carries the same value in IEC 60870-5-104. What does the value 3456 mean? No idea in IEC 60870-5-104. You have to know upfront what 113 means. IEC 61850 stores the meaning in the device (model).

In the above case we see also the IOA=113 in the description (DC) of the IEC 61850 model. It is a text string attached to the DC attribute.

Draft TR IEC 61850-90-2 Substation to Control Center Communication published

The Draft IEC Technical Report: IEC TR 61850-90-2 – Use of IEC 61850 for the communication between substations and control centres

has been published under 57/1507/DC dated 2014-09-26

This technical report provides a comprehensive overview of the matters that need to be
considered in order to use IEC 61850 for information exchange between substations and control or maintenance systems.

Is Security really a big Issue in the Power Industry?

It all depends on to whom you listen. I have discussed the security issue quite often. Hope that some people have listened to me. ;-)

These days you can see a lot of intensified discussions related to the use of DNP3 and especially the application at the control center (or master) side of the communication channel. One IED talks usually to one master station – but: One master station may talk to many many IEDs. DNP3 master stations are centralized components in SCADA systems used in many industries: power, gas, oil, water, waste water, … in general automation.

One of the crucial issues is that it seems quite easy to send a specific message from a control center (master) to the substation to put the slave (RTU) into a infinite loop condition (blocking further information sharing) or a spontaneous message from a substation to the control center to put the master into infinite a loop condition (blocking further information sharing). In both cases the devices must be shut down and restarted.

Click HERE to read one of the latest discussions.

I experienced recently the following: an IEC 61850 Server sent a report message with a value derived from a DataSet member of type FCDA to a client (in a gateway for a big control system, DCS). The client (client application) stopped working properly … just did not react anymore. As a result the client did not only “refuse” to work with this server – it also stopped communicating with other servers it was connected to.

Hm, by reporting just a value from a FCDA member (LN XX FC=ST DO=Pos DA=stVal) instead from a FCD member (LN XX FC=ST DO=Pos  with three DA components: stVal, q and t) the client (client application) gives up to work … what a surprise. I was really surprised!

One solution to overcome this situation could be to require more conformance tests of clients (and servers!). That would help a lot.

BUT at the end of the day you may run into similar issues even if the client has been successfully conformance tested and certified: The clients and servers implementing IEC 61850 will support a subset of the features the standard defines. Independent of a certificate it would be more important to get a document that lists all the restrictions and specialties of a client or a server. If you know that a client crashes when you report a value from a FCDA member of a DataSet, then you could (at least) work around that problem by just configuring FCD members!

Figuring out that the use of a FCDA member causes a gateway to crash may take days of analysis and discussions … and is produces a lot of frustration before, during and after such a process.

Lesson learned: Clients, Server, Publisher and Subscriber have to come not only with a certificate but also with comprehensive documentation.

Dear Utility user: ask for sufficient documentation! We could help you to analyze the documentation to figure out …

IEC 61850 – Brief Report from first day at Hannover Messe 2013

The Hannover Messe has opened today (Monday, 08 April 2013). Some 6,800 exhibitors demonstrate their industrial products from industrial fieldbusses and PLCs to Power Generation and Power System Automation and Protection.

I am personally involved (as a Missionary for IEC 61850, IEC 61400-25, IEC 60870-5-104, DNP3, Modbus, …) in helping interested people at the booth of TQ Systems, Beck IPC and SystemCorp to get a brief introduction of IEC 61850, answering questions and helping them to navigate trough the above standards … mainly: How to get from standards to market-ready products!

There was a lot of interest in the solutions the three companies could provide. Many people just stopped at the booth and were excited to see how easy it is these days to get their IEDs and systems to speak the above standard communication languages!

In case you are visiting the Hannover Messe this week, please come by at booth C45/1 in hall 13.

Download the information package I am giving away at the Hanover Messe this week [pdf, 4.3 MB].

Some impressions:

Building up the booth

… does it fit Detlef? Yes!

… smart people to install smart devices:

… Wow ! It is all working according to IEC 61850 … it’s REAL !

… ruggedized IEC 61850 gateway to Modbus:

TQ Systems HMI with IEC 61850 Client:

Beck IPC Products:

Any question … when you see this price for a special RTU?

The com.tom also supports DNP3, IEC 61850, Modbus, …

Are RTUs dead?

Which definition of RTUs do you mean? Do you mean Reach The Universe? Yes, these RTUs will live forever. Let me know what you mean by RTU.

When we talk about RTUs, we should differentiate between functions, I/Os and processor platform. In the past (some 10 years ago) an RTU was more or less well defined by its functions, I/O wires/terminals and platforms. Many of them are still in use and a lot more will be installed in the years to come.

Today we have many many more functions (those we know well, and those we could think of), hardwired I/Os, serial I/Os (Ethernet, ...), hierarchies of I/Os (or RTUs or just IEDs), and many more very powerful platforms.

Whenever we talk about an RTU, we should list the functions it implements, hardwired I/Os, serial I/Os (Ethernet, ...), hierarchies of I/Os (or RTUs or just IEDs), and the powerful platform. I have seen yesterday a substation ruggedized box with an 8 port Ethernet switch, some 20 I/O wired terminals, with IEC 61850 and other protocols, and programmable applications (C/C++, IEC 61131-3 CoDeSys, simple web PLC). Is this box an RTU, a bay controller, a PLC, a gateway, a substation computer, (condition) monitoring device, an Ethernet Switch? Its a bit of everything!

In my experience utility people use a new name for the "interface" to a substation: Substation Gateway.

In any case we should describe what we mean by a term (e.g., RTU), and should describe any box independent of its name.

"Names are sound and smoke", it says in Goethe's Faust. To make sure this is not the case, companies are putting a lot of money on name inventors. The name RTU was invented some 20+ years ago - a good name so far. We can keep the name - but have to define what we mean.

What do you think about this interpretation: RTU = Reach The Universe (of a substation or power plant or ...). That is broad enough to cover everything.

We have tried many times to find a name for IEC 61850 - we failed so far. We should not try anymore to find a name. A single name would mis-lead. If we talk about IEC 61850 we have to clearly describe what we mean!! Just saying: My device conforms to IEC 61850 doesn't mean anything. What does IEC 61850 Edition 2 mean? Nothing!! There is NO IEC 61850 Edition 2 at all! What? See some discussion:

A. http://blog.iec61850.com/2012/08/iec-61850-edition-1-2-or-3-and-uml.html
B. http://blog.iec61850.com/2012/07/current-series-iec-61850-comprises-19.html
C. http://blog.iec61850.com/2010/03/what-is-edition-1-and-edition-2-of-iec.html

The issue is that the semantic is carried by a name. The semantic MUST be defined by somebody. If many definitions exist then we have to be very careful. Ask always what people mean by RTU, IEC 61850 Edition 2, Fizzlipuzzli, ... You belief to know what RTU and IEC 61850 Edition 2 mean. Are you sure? And you agree, that you do not know what Fizzlipuzzli means (except a few people that know me). I don't know what Fizzlipuzli means either. ;-) ... it is something nobody knows. I use it for a function or a device to make sure that nobody associates it with something real he/she knows.

During the first meetings of the IEC 61400-25 (IEC 61850 extensions for wind turbines) we had a serious discussion on "Reports" ... we could not reach an agreement. Because I was discussing the IEC 61850 Report(ing Model). The other person discussed a Report from a turbine containing 10 minute statistical values of wind speed and power produced etc. That's the reason lawyers first define the terms they use in a contract!!

IEC 61850 at the Remote Monitoring and Control Conference, Denver (CO), September 18-19

Looking for the latest on Remote Monitoring and Control?
Check the program of the Remote Monitoring and Control Conference, Denver (CO), September 18-19, 2012

The Remote Monitoring and Control Conference has released its 2012 show brochure. Included in the brochure are presentation descriptions, the show's full schedule, conference workshop information (on DNP3, IEC 61850, IEC 62351 Security, …), exhibitors, co-located event profiles, registration details and information on booking your room at the show hotel.

Click Here to View the Brochure [pdf, 4 MB]

If you are automating, remotely monitoring and controlling your oil & gas, water/wastewater, utility/T&D, telecom and transportation infrastructure equipment and systems, this is a must attend event.

Please note that NettedAutomation GmbH will have an exhibition booth in cooperation with SystemCorp (vendor of IEC 61850 Stack/API) and Beck IPC. The latest products for IEC 61850 (like IEDs, Gateways to/from DNP3, Modbus, IEC 60870-5-101/104, …) will be presented.

FINSENY – European Consortium of 35 Organizations supports IEC 61850 and IEC 61400-25

Have you heard about FINSENY before? I didn’t know about these activities. What is it? Another European project – yes, but one that seems to build on existing standards like IEC 61850, IEC 61968/70, IEC 61400-25, IEC 62351, … IEC 60870-5.

FINSENY – Future Internet for Smart Energy (2011 – 2015)

FINSENY project: 35 organizations from the ICT and energy sectors team-up to identify the ICT requirements of Smart Energy Systems. This will lead to the definition of new solutions and standards, verified in a large scale pan-European Smart Energy trial … As part of the FI-PPP programme, FINSENY will analyse energy-specific requirements, develop solutions to address these requirements, and prepare for a Smart Energy trial in phase two of the programme.

Click HERE for the list of the 35 organizations.

Fortunately the work done so far refers to IEC TC 57 and TC 88 standards!

“ … existing standards which are worldwide considered and recognized like the IEC TC57 standards for Communication networks and systems for power utility automation (IEC 61850) and System interfaces for distribution management (IEC 61968) will be taken into account when defining the architecture, data models and communication relationships as well as existing telecommunication standards supporting the Future …”

Click HERE for a statement on standards.

A first list of consolidated ICT Requirements recommends: “To ensure interoperability the communication should rely on well-known and frequently used standards like IEC 61850, IEC 61968/61970 (CIM), or IEC 60870-5-101/104 (Telecontrol) and others. Also to be respected are specialized communication standards like - IEC 61400-25-4 for wind turbines …”

Click HERE for the requirements document [pdf, 262 pages]

A very detailed description of typical use-cases in power distribution has been written: “Distribution Network Building Block”: “ … Advanced ICT solutions that could provide Future Internet and the economies of scale that could be reached are essential for the development of the Smart Distribution Network. This deliverable presents a Reference Model for the Distributed Network Scenario and selects and describes a set of building blocks (UC) that should be representative enough for a further analysis of ICT requirements of smart DN solutions.”.

Click HERE for the Distribution Network Building Block [pdf, 98 pages]

I was a bit surprised when I read in that document about the communication with SCADA systems:

“SCADA System updates real time information from the RTU by means of continuous polling. The RTU is monitoring continuously Power Equipment through its Analog and Digital Inputs. When a change occurs is some of the inputs, the RTU takes note of it in order to send it in the next request from the SCADA System SCADA System requests every 2 seconds for any change of state or measurements detected in the RTU. When a request of state or measurement change is received, RTU sends all these changes to the SCADA System …”

Hm, this seems a bit … ok, smart people will develop smart(er) devices – the IEDs (Intelligent Electronic Devices) – that will help to reduce the sheer unlimited amount of data to be exchanged continuously every 2 seconds. The project expects millions of devices to communicate with. Suppose 100 signals to be exchanged every 2 seconds from 100.000 devices: 5.000.000 signals per second … IEDs (RTUs, Data Managers, Data Aggregators, Gateways, …) with IEC 61850 will send information only if it is needed!! – on an event like a state change or limit violation.

Exchanging millions of signals per second means we need a high bandwidth – good for vendors that sell “bandwidth”! That is the question, how can more active power flow through the copper cable? Same may accomplish it the smart way with the reactive power compensation that can be done smart by inverters – smart electricians may solve this by just putting a bigger cable into the ground.

Click HERE for some discussion of polling versus spontaneous reporting.

The document lists also Monitoring and Control of Inverter Functions (Connect / Disconnect to/from grid, Adjust Maximum Generation Level, Adjust Power Factor, ... Scheduled Actions based on time, temperature, power pricing … VAr modes for VAr support from PV/Storage inverters (Modes PV1…PV5) … Advanced functions (Watt/Frequency or Watt/Voltage mode, advanced schedules, low voltage
fault ride through (FRT), separate Watt and VAr management, harmonic cancellation) …

The FINSENY papers are worth to read and study.

Distribution Company Vector’s Ten-Years Plan for IEC 61850

Vector Limited is the electric power distribution company in the Auckland (New Zealand) area. The company publishes every year an Asset Management Plan (AMP) – informing the public and others what the company is planning to do with their assets. The current plan covers a ten year planning period from 1 April 2011 to 31 March 2021.

One goal of the current AMP is to demonstrate innovation and efficiency improvements. What does this mean related to IEC 61850? A lot in the past and in the future:

• Vector’s substation automation system is based on resilient optical
  Ethernet local area network running IEC 61850 compliant IEDs.
• Vector’s current standard for internal and external communication systems is IEC 61850 standard. DNP3 is also used as an interim solution.
• At present over 50% of Vector’s primary substation are equipped with IEC 61850 compliant IEDs.
• Vector has been running an annual RTU replacement programme for a number of years, and is currently replacing approximately 10 RTUs per region per annum. To replace conventional RTUs, two approved solutions have been used, traditional RTUs with a migration path to IEC 61850, and fully compliant IEC 61850 solutions.
• …

Click HERE for the current plan (2011-2021) [PDF, 10 MB]