ffwd automation special issue - ABB Groupnew.abb.com/.../magazines-downloads/ffwd-3-14-grid-automation.pdf · 02 abb.co.uk/ffwd Substation automation special issue From the Editor

How the process bus is transforming substation automation systems 8Switchgear for the smart grid age 10De-risking substation automation projects 14Cyber security is now a ‘must have’ 22

Leading the substation automation revolution 6

ffwdFocus on substation

automation special issue

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Substation automation special issue02 abb.co.uk/ffwd

From the Editor

Stephen TrotterDivision Head of ABB Power Systems UK & Ireland

ffwd substation automation special issue 3/14 • The customer newsletter of ABB Power Products and Power Systems • Subscription Newsletter available as printed or electronic copy. Subscribe online at abb.co.uk/ffwd • Contact and feedback [email protected] • Publisher ABB Limited, Power Systems Division, Outlon Road, Stone, Staffordshire ST15 0RS. Phone 01785 825 050

08 Digital grid

ffwd 3 |14

Dear Reader,Substations are key components in the

UK power grid. They facilitate the efficient transmission and distribution of electrical energy from an increasingly complex variety of conventional and renewable sources. They play a vital role in terms of monitoring and controlling power flows and provide the interconnection between generating facilities, transmission and distribution networks and end consumers.

The most familiar physical aspect of substations is their large hardware, such as switchgear and transformers. But there is an equally vital aspect, the substation automation systems that make their control and monitoring possible in real time and help maximize availability, efficiency, reliability, safety and data integration. Or to put it another way, substation automation is the ‘brains’ behind the muscle.

So I am very pleased to introduce this special issue of ffwd that focuses on the wide variety of substation automation products, systems and services that represent the culmination of ABB’s 25 years of experience at the forefront of substation automation technology. This leadership is perfectly illustrated by the central role that ABB has taken in the development and implementation of the IEC 61850 standard with our range of Relion IEDs. You can read how we are now taking this to the next level in the form of digital grid solutions.

I would particularly like to highlight the feature on our SVF (system verification facility) at Stone. This has enabled ABB to develop a unique capability in transportable commissioning that effectively de-risks substation automation projects. You can also read about major projects in the rail and renewable energy sectors. Taking a broader view, I recommend the articles on WAMS (wide area monitoring systems) technology and cyber security.

Substation automation special issue

ABB Power ProductsPower Products are the key components for transmitting and distributing electricity. The division incorporates ABB’s manufacturing network for transformers, switchgear, circuit breakers, cables and associated equipment. It also offers all the services needed to ensure products’ performance and extend their lifespan.

ABB Power SystemsPower Systems offers turnkey systems and services for power transmission and distribution grids and for power plants. Substations and substation automation systems are key areas. Additional highlights include flexible alternating current transmission systems (FACTS), high-voltage direct current (HVDC) systems and network management systems. In power generation, Power Systems offers the instrumentation, control and electrification of power plants.

abb.co.uk/ffwd Substation automation special issue

Content

03

22 Cyber security10 UniGear Digital18 From wired to

wireless

Portfolio04 ABB’s world of substation automation solutions

IEC 6185006 IEC 61850 is the one and only standard

New products08 Digital grid – latest developments in the application of

IEC 61850-9-2 10 UniGear Digital11 Relion 611 and 615

Arc flash protection12 REA offers protection at the speed of light

System verification14 Stone’s System Verification Facility is even bigger

and better

Portable relay rooms16 PRRs de-risk major projects

Utility communications18 From wired to wireless, ABB has it covered

Smart grids20 WAMS21 Ventyx and the great IT/OT convergence

Cyber security22 From nice to have to must have

Service24 Ensuring total peace of mind

Project news26 LUL puts Relion 620 to the test27 Breaking the mould at Pen Y Cymoedd wind

energy project


Portfolio

04

Substation automation product and service portfolio

ProtectionProtection is used to detect power system faults and other abnormal conditions. It also protects human life and valuable equipment. In the home, this protection comes in the form of fuses in plugs, and MCBs (miniature circuit breakers) in the consumer unit. There are also RCDs (residual current devices) that detect an earth fault, tripping the circuit before any serious harm occurs. The protection used on power networks is essentially the same, just on a much larger and more sophisticated scale. The quality of a protection scheme tends to be measured in terms of its reliability, speed and selectivity: – a reliable protection relay operates

correctly when there is a power system fault, but doesn’t make an incorrect operation when no fault is present

In today’s increasingly competitive world any loss of power means a loss in profitability. Utility networks have a duty to keep the lights on, and their performance is regulated by measures such as Customer Minutes Lost/Customer Interruptions. Equally, industrial networks demand continuity and security of power supply to keep their processes running. A halted process can soon result in massive losses. For example, if an oil refinery loses its supply, it can be two weeks before it is back up and running. Substation automation schemes play a vital role in keeping power interruptions to a minimum.

ABB’s world of substation automation solutions

– speed is the minimum operating time to clear a fault – to avoid damaging equipment and causing system instability

– selectivity means only disconnecting the faulted section of the network or plant, preserving continuity for the rest of the supply or system

Main and back-up protectionIn general, main and back-up protection is applied. Main protection operates every time a fault is detected. Back-up protection is set to operate should the main protection fail to operate.

OvercurrentOvercurrent is most the basic form of protection and is used at all voltage levels.To achieve selectivity, the protection is graded according to time and/or current


Portfolio

05

Customer training session

(higher fault current = faster operating time, lower fault current = slower operating time). If circuits are in parallel, or if there are multiple sources, the direction of the current needs to be considered, so directional overcurrent protection is used.

DifferentialDifferential (unit) protection is applied to lines, transformers, motors, generators and bus-bars. This is absolutely discriminative/selective protection, but it requires com-munication either via copper pilots or other more advanced forms such as telephone circuits or optical fibres.

DistanceDistance (non-unit) protection discriminates between faults by measuring the imped-ance of the line. The line generally has a constant impedance (independent of cur-rent and voltage levels). It doesn’t require communications but can use them to help increase speed, or selectivity/security.

SignallingTeleprotection signalling can be used in conjunction with distance protection to provide increased selectivity and faster tripping times, using communications infrastructure such as pilot wires or SDH (synchronous digital hierarchy)/PDH (plesiochronous digital hierarchy) networks. Intertripping uses similar communications channels to pass trip signals from one substation to another to ensure that both ends of a faulty circuit are disconnected from the healthy power system.

LoadsheddingWhen generation capacity cannot support the load then the balance between genera-tion and load needs to be addressed. The indication that generation is not matching the load is a drop in voltage and/or fre-quency. Loadshedding schemes are used to disconnect less important loads to help redress the balance. Of course, measuring power in and out would also indicate the loss of balance.

ABB’s total support for Substation Automation A track record of over 25 years in global substation automation has established ABB as a proven and reliable solution provider. We have the resources to create cost-effective integrated solutions as well as supplying stand-alone products for coordinated protection, signalling and

control for any transmission and distribution application. Our customers are mainly electrical utili-ties, transmission, distribution and genera-tion companies as well as the transport, manufacturing and processing industries and data centres. We also work in close cooperation with channel partners such as OEMs (original equipment manufacturers), EPCs (engineering procurement and con-struction contractors) and main contrac-tors, EPCs and main contractors.

Comprehensive scopeABB’s comprehensive scope of supply includes: – solutions for efficient control,

protection, automation and monitoring of new and existing substations of any type, size and topology

– IEC 61850-compliant solutions – portfolio of interoperable

systems, products and tools

– full system integration and verification

– consulting and system design – optimization

– protection schemes for generators, busbars, lines, transformers, shunt reactors, capacitors and motors as well as station protection systems with decentralized structure and functional integration

– service and support in all project phases:

– consulting, power system studies, disturbance analysis, relay setting calculations, CT (current transformer)/VT (voltage transformer) calculations

– system design and engineering, project management, assembly, testing, commissioning, training and maintenance

– main contracting for turnkey installations as well as upgrades of existing substation automation systems.

TrainingTraining is vital in helping our customers to improve their understanding of how to use their individual equipment or system, and how to operate their entire power distribution and transmission processes most efficiently.

Furthermore, training provides: – improved efficiency in process

operation – faster and safer operational

decision making – improved knowledge in adapting

products to specific requirements – one-to-one contact with ABB’s

fully trained and experienced instructors.

Depending on specific requirements, training is provided by ABB in the UK and/or the ABB universities in Vaasa (Finland), Västerås (Sweden) and Baden (Switzerland).


IEC 61850 – the first and only global standard for substation automation

IEC 61850

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About the standardIEC 61850 essentially defines standardized data models and sets, communication mechanisms and the system configuration language (SCL) in order to achieve a number of goals: – interoperability of system

components and software tools – free allocation of functions as

well as choice of different system architectures

– reuse of system configuration data – understanding of the system

description and functionality

There are many thousands of (SA) substation automation systems installed worldwide. But until quite recently, there was no overall standard for the serial communications in substation automation, so the majority of these systems have been based on proprietary standards. This meant that each system was either limited to using components from a single supplier, or complex and costly protocol conversions had to be applied.

Naturally, power utilities and major industrial power users want to safeguard their investment in substation automation equipment. This has resulted in a growing demand for flexible, future-proof systems able to cope with changing requirements, philosophies and technologies. In the early years of the 21st cen-tury, the industry responded by developing and releasing a new standard, IEC 61850 ‘Communication Networks and Systems in Substations’ which is the first and only global standard that considers all the communication needs within substations.

Ibrahim Cobanoglu, ABB UK Sales and Marketing manager for Substation Automation, outlines the importance of IEC 61850

ABB’s System Verification Centre (SVC) in Baden, Switzerland


IEC 61850

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The Relion family of relays

The standard is future-oriented, taking into consideration that developments in communication technology move faster than developments in the functionality of substation automation, protection and control equipment.

ABB – leading the way in IEC 61850ABB has pioneered the development and implementation of IEC 61850 through a number of initiatives: – continuous engagement in the

elaboration and validation of the standard

– consistent implementation of IEC 61850 as a key technology in products, systems and tools for best possible system integration

– efficient introduction of systems based on the standard with modularized solutions for station control and monitoring as well as bay control and protection

– guaranteed system openness for future hardware and functional extensions through fully standard-compliant documentation

– development of state-of-the-art tools for efficient design, engineering, assembly, testing and commissioning, as well as maintenance of substation automation systems

– integration of third-party devices and systems in ‘multi-vendor’ systems

– quality assurance by ABB’s in-house System Verification Centre (SVC) in Baden, Switzerland – the world’s only vendor test centre with official qualification by UCA International, an independent user organization for IEC 61850.

Native implementationEven before IEC 61850 was launched, ABB had committed to a ‘native implementation’ philosophy, so that the standard would be fully implemented in new product developments. In a typical IEC 61850 native design, the functionality of the IED must consider the entire process, including specification and evaluation, system and device engineering, system commissioning, and operations and maintenance. An IEC 61850 native IED should provide: – a full set of protection and control

data to SA systems, and to other IEDs and third-party tools in compliance with the defined data models and logical nodes (LNs) to achieve a high level of interoperability

– fast communication and application performance, which is critical when using generic object oriented substation events (GOOSE) peer-to-

peer communication for distributed protection algorithms, and complex station and bay control interlocking schemes over Ethernet in the substation bus

– adherence to data modelling and substation configuration language (SCL) information available for system engineering, device configuration, diagnostics and commissioning tools

– ease of adaptation and be future-proofed against evolving technologies enabled by Ethernet and IEC 61850, for example, utilizing IEC 61850-9-2 sampled values and microsecond-level time synchronization accuracy via IEEE 1588.

ABB’s Relion protection and control product family was one of the first to under-go the IEC 61850 transformation. The prod-ucts required a completely new platform architecture that would integrate commu-nication services and data representation into the core protection and control appli-cations. This development was carried out in parallel with the development of the IEC 61850 standard to ensure that the future ABB Relion family was designed from the very beginning to support IEC 61850.


New products

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Energizing the digital grid Danny Lyonette, Business Development Manager for ABB’s UK Network Management business, outlines how the impact of the process bus is now transforming the design of substation automation systems.

The majority of substation automation projects to date have concentrated on the IEC 61850-8.1 station bus. However, there is now a growing focus on the IEC 61850-9-2 process bus that enables current and voltage measurements to be transmitted to protection and control devices via a fibre-optic communication network, resulting in significantly reduced copper cabling and increased safety.

The process bus also supports the standardised integration of non-conventional instrument transformers (NCITs), bringing performance improvements and further reductions in cost and space requirements. NCITs also improve safety because they eliminate the risk of voltage hazards, which can arise in conventional instrument transformer circuits.

2012 saw the first fully compliant commercial installation of IEC 61850-9-2 process bus technology. This was installed for the Australian utility, Powerlink, to provide advanced automation functions to enhance availability and grid reliability at Loganlea, a key substation serving south-east Queensland, a fast growing region of Australia.

Australia’s Loganlea substation was the world’s first fully compliant commercial installation of IEC 61850-9-2 process bus technology


New products

09

The drive for the digital grid has received new impetus with the recent launch of ABB’s latest portfolio of hardware and software solutions, designed to advance the digitization of substation automation for improved security and grid reliability. These include the SAM600, a stand-alone merging unit, and SDM600, a system data management software solution, along with the Relion 670 series 2.0 IED, the newest member of ABB’s family of protection and control devices, and the RTU520, the latest Remote Terminal Unit to join the RTU500 family of network monitoring and control devices. Built on the international substation automation standard IEC 61850-9-2, the solutions bring significant advantages in terms of interoperability and ease of configuration, as well as addressing the security requirements of multi-access substation automation systems.

SAM600 – stand alone merging unitThe SAM600 merging unit is an enabler for digital substations that integrates conven-tional instrument transformers into modern, IEC 61850-9-2 process bus substation automation, protection and control sys-tems. It allows stepwise upgrades toward full-system digitization with minimal disrup-tion to substation operations. As electrical signals are digitized at source, risks associ-ated with service and maintenance activities are significantly reduced and operational safety is improved. Digital technology has already revo-lutionized communications across utility networks, and now the same techniques are being applied within the substation to enable robust, fast and responsive mes-saging over Ethernet and fibre optic chan-nels. But existing sensors aren’t built for this digital world and replacing them is expen-sive and unnecessary when SAM600 can bridge between the worlds of digital and analogue signalling.

Strict adherence to the IEC 61850 stan-dard results in future-proof installations that take advantage of enhanced tool suites for engineering and testing, such as ABB’s IET600 system configuration tool and ITT600 SA Explorer for simple and efficient testing.

SDM600 data management softwareSDM600 acts as a cybernetic office man-ager, managing the network and keeping a watchful eye on those using it. The software checks the credentials of every cyberspace traveller; restricting visi-tor access to the approved systems and equipment, it logs IED disturbances using IEC 61850-8-1 then creates comprehen-sive status reports to help spot trends in use, and it tracks software and firmware on every IED to ensure updates are properly distributed. All this is managed through a unified user experience, and one which can cascade updates to other SDM600 installations, so the biggest network can be comprehensively managed from a single interface.

Relion 670 series 2.0Part of ABB’s established Relion family of protection and control devices, the Relion 670 series 2.0 provides faster performance

with improved accuracy that its predeces-sors. In addition to its unique monitoring functions for protection and control in trans-mission systems, the product has been certified by independent laboratories and is fully compliant with both editions of the IEC 61850 standard.

RTU520 – Remote Terminal UnitThe new RTU520 product line offers an easy and cost-efficient solution for distribution monitoring and control. The DIN rail input/ output modules can be flexibly connected to meet a wide range of application requirements. ABB’s RTU500 series also provides a comprehensive switch portfolio in the field of Ethernet communication, which enables customers to mix different types of media like fibre optic and two-wire copper cables (SHDSL – symmetrical high-speed digital subscriber line) in one network.

SAM600 module

10 abb.co.uk/ffwd Substation automation special issue

New products

UniGear Digital concept is ready for the smart grid ageABB has launched a new Unigear Digital concept for the well-established UniGear line of medium voltage switchgear, taking it to the next level, ready for the smart grid age.

UniGear Digital is based on ABB’s well-proven ZS1 switchgear

An innovative solution combining pro-tection, control, measurement and digital communication, the UniGear Digital panels are designed to enable a safe, flexible, eco-efficient and smart electrical network that can deliver power reliably and efficiently. The difference to earlier models is that state-of-the-art digital current and voltage sensors are integrated into each panel, alongside ABB’s multifunctional Relion IEDs (Intelligent Electronic Devices), which ensure compat-ibility with the IEC 61850 digital communi-cation protocol. This combination is designed to per-form a central role in medium voltage smart grids, with the Relion 615 range providing the backbone of the UniGear Digital com-munication concept.

Save timeBecause it packages switching and com-munication functions together, the new gen-eration of switchgear offers a 30 percent shorter delivery time together with easier purchasing, engineering, installation and commissioning. In one move, the digital offer has removed a whole raft of complexity, with its associ-ated long lead times, risk and cost. Using IED connectivity packages, it’s quick and easy to connect the digital switchgear to a customer’s SCADA (supervisory control and data acquisition) system. Furthermore, because UniGear Digital’s interface is based on the Relion range, switchgear operators are able to adapt readily to the user-friendly human machine interface (HMI).

Better operational performanceFrom an operational perspective, the digital switchgear represents increased substation availability and equipment safety. The new UniGear Digital panels meet the highest requirements for peer-to-peer GOOSE (Generic Object Oriented Substa-tion Event) communication, which is faster than systems that use the traditional hard-wired approach. Constant supervision of peer-to-peer communication links between panels ensure that switchgear trips quickly and reliably following an event. The IEC 61850-9-2 LE process bus is also used by IEDs for transmitting sampled measured values (SMVs). UniGear Digi-tal uses it for sharing busbar voltages, for example. Remote connection via an Ethernet inter-face means that it is possible to reconfig-ure an IED or carry out monitoring remotely, avoiding the need for a site visit.

Future proofingAs demand grows, the new digital panels can be plugged in to extend and upgrade substations ready to be part of a smart grid, using the concept of interoperability under the IEC 61850 standard. This means that UniGear Digital is built for flexibility, scal-ability, modification and expansion without the need for complex additional wiring.

AvailabilityWhile the UniGear range includes switch-gear for single level, double level and dou-ble Busbar solutions, the UniGear Digital concept is currently available exclusively as an option for the popular UniGear ZS1 up to 17.5 kV, which has applications in utili-ties, industry, marine, transport and infra-structure settings. ABB plans to extend the digital concept to the entire UniGear portfolio as demand for smart grid-ready technology grows.

11abb.co.uk/ffwd Substation automation special issue

New products

Relion 611 series for power distribution applications

ABB’s new Relion® 611 series has been developed to offer a cost effective IEC 61850 solution for the protection and control needs of utility and industrial power systems as well as power distribution systems in medium voltage networks. The preconfigured functionality, offered as application specific standard configurations enables reduced engineering needs and faster commissioning.

IEC 61850 control and protection is built in with Relion relays

There are three units in the new series:

REF611 – Feeder Protection and Control – for the protection, control, measurement and supervision of utility substations and industrial power systems.

REM611 – Motor Protection and Control – for the protection, control, measurement and supervision of asynchronous motors in manufacturing and process industries.

REB611 – Busbar and Multipurpose Differential Protection and Control – 3 Phase high impedance based protection, control and supervision of single busbar applica-tions within utility substations and industrial power systems.

ABB has extended its market-leading Relion 615 protection and control series with its latest release 5.0 including the REV615, a dedicated capacitor bank protection and control relay. REV615 is ideal for the protection, control, measurement and supervision of capacitor banks used for compensation of reactive power, in both utility and industrial power distribution systems.

New Relion® 615 series 5.0 now includes capacitor bank protection

In addition to the new REV615, the 615 series 5.0 has received significant functionality enhancements, making it ideal for line differential applications with an in-zone transformer, introducing advanced fault location of short circuits and earth faults, and increasing the number of variants with sensor-based phase current and voltage measurement, to mention a few. Minimizing the effects of an arc fault

by adding high-speed outputs is another highlight. To maximize the benefit of substation-level Ethernet communication, the 615 series 5.0 now offers compliance with IEC 61850-9-2 LE with its process bus solution enabling sampled values to be shared in addition to fast GOOSE between devices, therefore providing faster performance. This also offers improved accuracy by also introducing compliance with the IEEE 1588 standard allowing high-accuracy time synchronization essential to process bus application requirements.The 615 product series 5.0 is characterized by a compact and withdrawable-unit case design and has been designed to unleash the full potential of the IEC 61850 standard for communication and interoperability of substation automation devices. As a member of the Relion product family, the 615 series IEDs (intelligent electronic device) share the same HMI look and feel as other Relion series IEDs, thus minimizing human errors and further enhancing safety.


Arc flash protection

Ian Hodkinson, Business Development Manager for ABB’s Distribution Automation Business, explains how the innovative REA fast arc flash detection system using fibre-optic sensors cuts typical relay operating times to less than 2.5 ms – far faster than conventional relay technology.

Arc flash protection at the speed of light

Above: Family of REA arc protection relays with fibre optic sensor | Below: A long unclad fibre optic sensor can absorb light throughout its length

01


Arc flash protection

Ultra-fast detection and clearing of arc flash faults is essential in controlling arc flash hazards, particularly in power distribution systems in the oil and gas industry, as well as many other industrial and utility applications. Reducing the arcing time through faster detection is the most practical means of lowering incident energy levels and improving workplace safety.

The energy released in an arc flash inci-dent is directly proportional to arcing time. Even a few milliseconds improvement may shift hazard levels and PPE (personal pro-tective equipment) requirements to lower categories. For arcing times of 40 ms or less there is typically no personal injury or switchgear damage, while arcing times of 500 ms or more will cause serious person-al injury and major damage to switchgear, even if the switchgear is rated for internal arc containment. Arc flash is not a new phenomenon, but interest and concern about the dan-gers associated with arc flash events have increased dramatically in recent years. This is largely due to new guidelines and stan-dards put forward by the various interna-tional trade and safety bodies such as the Institute of Electrical and Electronic Engi-neers (IEEE) and the US Occupational Safety and Health Administration (OSHA).

Dedicated arc flash protectionAn arcing fault instantaneously releases large amounts of radiant light and thermal energy. This intense light is used in com-bination with fault current detection by arc flash detection relays to achieve faster operating times than is possible with con-ventional relaying alone. Arc flash detection systems are stand-alone protection systems and do not need to be coordinated with existing protection systems as they operate far faster and only in the event of arc faults. Therefore, it is not necessary to delay tripping for coordina-tion with other protection. Arc flash relays have been around since the early 1990s. However, first generation arc flash protection used only single-point lens sensors. In this type of system, one or more lens sensors are located in each high-voltage compartment where a poten-tial arc flash might occur.

From around 2000 onwards, ABB intro-duced the new generation REA series of arc flash detection relays. This system allows the use of a radically different type of light sensor: a long unclad fibre-optic sensor that can absorb light throughout its length and can be combined with single sensors for separate compartments.

REA fibre-optic sensor benefitsThere are several advantages to the REA’s fibre-optic sensor technology. First, it dra-matically reduces the cost of installation. A single optical fibre sensor can be as long as 60 metres, typically covering the same protection zone associated with convention-al bus differential protection, but at much lower cost than lens sensors. Second, any concerns about shadows from internal structures that might block the direct exposure to an arc flash are eliminated.

The main distribution substation at Total’s Lindsey Oil Refinery features ABB’s REA arc flash protection relays

Third, if the fibre sensor is configured in a loop, it can provide regular self-checking of the sensor’s integrity and continuity, and generate an alarm if a problem is detected. In normal operation, both light and overcurrent must be present simultaneously for tripping to occur. Detection of an intense light alone will not result in a trip unless the system is intentionally set to operate that way (which is not recommended). Over-current settings allow different cur-rent threshold levels for phase and ground fault currents. High-speed insulated gate bipolar transistors (IGBTs) are used to pro-vide two fully trip-rated outputs rather than relatively slow conventional dry contacts. The overall tripping time is just 2.5 ms. Many thousands of REA systems uti-lizing long fibre-optic sensor technology have been installed worldwide. And there have been at least two documented cases where the REA concept has prevented seri-ous damage to medium voltage switchgear following an arc flash incident. Optical arc flash relays are ideally suited to modern vacuum and SF6 breaker tech-nologies where the fault interruption takes place inside a sealed container. However, with proper precautions, an optical relay may also be applied to air magnetic breakers.


System verification

The outstanding success of the showcase System Verification Facility (SVF) at Stone has recently seen a further million pound investment in the expansion and upgrading of this unique site for the UK, as Andy Osiecki, ABB’s General Manager – Power Systems Network Management UK, explains.

Unique facility ‘de-risks’ substation automation projects

A high level of factory testing avoids the need for significant work on-site

Andy Osiecki


System verification

Customers can witness their schemes being tested in real-life conditions

and rectification on site. So delivering the protection and control systems virtually ready to go ensures a fast and smooth commissioning process that effectively de-risks the project.

Drivers for expansionThere were two main drivers for the expansion of the SVS. First we simply needed much greater capacity. In 2006, the largest FAT of its type ever carried out saw the SVF packed with 60 cubicles of protection and control equipment destined for National Grid’s new indoor 275 kV GIS (gas insulated switchgear) substation at Stalybridge, near Manchester. Following the expansion, the SVS was able to accommodate comfortably over 120 cubicles for Connah’s Quay – ABB’s largest ever substation project. The second driver was that the IEC 61850 standard, which places a major emphasis on the role of the IEDs, is essentially the default choice for the majority of our substation projects. The SVS is playing a key part in ensuring customer acceptance of ABB’s innovative Relion® family of IEDs developed specifically to implement the core values of the new standard through full native compliance.

The trend to PRRsAn important new trend in the industry, which further reinforces the strategic significance of the SVF, is the move towards

The establishment of the SVF in 2006 represented an important change in ABB’s philosophy for carrying out the vital factory acceptance test (FAT) procedures for substation protection and control systems. So rather than carrying out limited representative pre site tests, we decided, in close consultation with our customers, to establish a rigorous test regime that replicates the actual installed arrangement as closely as possible and effectively ‘transports’ much of the final commissioning elements from site to the earlier verification stage. This ‘transportable commissioning’ approach means using the same IEDs (intelligent electronic devices) that will be deployed and uploading them with project specific settings and configurations. Furthermore, instead of hooking up the IEDs and relays to a network of switches, relays and lamps selected to simulate the substation plant, the computer-controlled SVS (system verification system) is linked to ABB’s own engineered modules that simulate the behaviour of substation plant such as circuit breakers, disconnectors and earthing switches. Not only do we duplicate the whole substation within the SVF, these automated, self- monitoring, fully repeatable test sequences establish the correct interaction with the protection and control panels. Over a period of time we have established a library of test routines to cover all potential situations.

Transportable commissioning – the factor of tenThe SVF has emerged as a key differentiator for ABB as customers particularly value the capability to come to Stone to witness their protection and control schemes being tested in real-life conditions. And we have shown that this approach can help drive down overall costs. There is a simple rule of thumb that applies. If an issue discovered at the FAT stage costs say £10 to rectify then it will almost certainly cost £100 to fix on site. The transportable commissioning approach can reduce site based snagging and rework by a factor of ten and this is a powerful argument for this value added approach through extensive SVF testing.

Fast and smooth commissioningA further major benefit of the SVF is that reducing the need for outages on site is a key priority for many customers, especially in the utilities. A high level of factory testing avoids the need for significant fault finding

portable relay rooms (PRRs). These fully containerised relay rooms bring together all the vital protection and control cubicles and accessories in a fully tested factory-assembled package that creates what is virtually a ‘plug and play’ solution.

Engineering and service resourceThere is more to the SVF than carrying out FATs. It is also a vital resource that enables us to develop our engineering and service capabilities using setups that duplicate real-life scenarios. It provides trainees with ‘hands-on’ experience in safe, fully controlled conditions.

Total confidenceThe facility is modelled on ABB’s System Verification Centre in Baden, Switzerland, which is qual i f ied for IEC 61850 by UCA International. It represents a very significant investment by ABB, not only in the equipment but also in building the team of highly skilled and experienced test engineers who run the FATs. We believe that the investment will continue to generate significant payback by enabling customers to reduce their on site commissioning and fault finding costs, minimise outages and establish total confidence that their protection and control scheme will function exactly as designed in any operational scenario.


Portable relay rooms

The System Verification Facility at Stone has played a vital role in the development of ABB’s transportable commissioning philosophy, embodied in a new generation of portable relay rooms (PRRs). Andy Osiecki, ABB’s General Manager – Power Systems Network Management UK, outlines two major current projects.

Transportable commissioning

01 Crossrail will see ABB’s first UK deployment of SMOS Light switchgear | 02 Steve Wright and Bill Henry of Network Rail with Stewart Dawson of UK Power Networks Services and ABB’s Stephen Trotter | 03 Portable relay rooms

01 03

02


Portable relay rooms

Crossrail successLondon’s new Crossrail link will see the first UK deployment of ABB’s unique Structure Mounted Outdoor Switchgear (SMOS) Light modular substation switchgear. It will form the heart of turnkey packages for three new traction substations that also include PRRs housing IEC61850 protection and control equipment. Crossrail is among the most significant infrastructure projects ever undertaken in the UK, with a total investment approaching £15 billion. From improving journey times across London, to easing congestion and offering better connections, Crossrail will change the way people travel around the capital. The route will run over 100 km through including new tunnels under central London. To support Crossrail, Network Rail is upgrading its power infrastructure. The three new ABB traction substations will provide the 25 kV (kilovolt) supply for the western, surface sections of the route. The PRRs will include the first Network Rail installation of ABB RTU560 and REF620 IEDs (intelligent electronic devices). The PRRs will be assembled, configured and tested at our SVS. The benefit from Network Rail’s perspective is that this high level of factory testing effectively de-risks the project, as the PRRs will be delivered to site ready to ‘plug and play’.

On track for rail electrificationABB and UK Power Networks Services have joined forces in a consortium to deliver a turnkey project for the creation of 30 new traction power substations (25-0-25 kV) for Network Rail’s Great Western Electrification Programme. Worth in the order of £100 million split 50:50, the project will mean that journeys on the Great Western railway will be more reliable, greener and smoother for passengers, as well as quieter for people living near the railway. The heart of the GWEP substations will also be provided by SMOS Light switchgear. The turnkey substation solution will be completed with ABB’s protection and control systems developed to suit Network Rail’s Rationalised Autotransformer Scheme (RATS). This is a sophisticated method of deploying the IEC 61850 standard designed to achieve a lower-cost substation solution. Protection and control equipment will be installed in a portable, fully-containerised Auxiliary Equipment Enclosure (AEE).

The key benefit of transportable commissioning is that the majority of the work to configure and commission the substation automation equipment is carried under controlled factory conditions. Not only does this enable the highest possible level of quality control, the commissioning engineer is on hand in the factory to help facilitate planning for the on site installation. There is still work to be done on site, but the risks of unexpected eventualities are significantly reduced.

Rather than having to take apart a fully working and tested system, possibly disturbing wiring and settings and then reassembling it on site, the next logical step in the de-risking process has been the creation of portable relay rooms. These bring together all the protection and control systems within a containerized, transportable unit. This enables the complete system to be built at the factory, configured, tested and largely commissioned at the SVF and then despatched to site as effectively a ‘plug and play’ solution, with no need to disturb any wiring. As well as reducing the amount of on-site commissioning work, using PRRs can help to reduce the level of disruption during delivery and installation and minimize the need for outages. A PRR is a substantial unit, weighing up to 15 tonnes, so pre-delivery planning is a key safety aspect of the project to enable the site manager to prepare how it will be delivered and offloaded safely and efficiently.

SMOS Light reduces construction, testing and commissioning time


Utility communications

Abdul Wahid, ABB’s Business Development Manager – Communication Networks, outlines the full spectrum of utility communications technologies.

The importance of the single bit

Communications networks are the backbone of electrical utilities, providing structure to the grid and enabling communication with remote equipment.

Many transmission networks have now migrated to fibre-optic communications, with an optical ground wire carrying gigabytes of data in a loop configuration for redundancy. But older, and remote, installations still use power line carrier (PLC) installations which offer robust, and economical, communications where latency is more important than bandwidth. Modern substation automation equip-ment harvests huge quantities of informa-tion on the status of the grid, tracking temperatures and environmental factors as well as the main operational data, and for that information to be usefully analyzed it has to be transported over the commu-nications network. But the most important message carried over the network will be a single bit – the command to activate a circuit breaker, or connect a relay, following a fault condition – and that bit must take precedence over all other communications, something every component in the network has to understand. The combination of quantity; in status updates and operational data, and quality; the command messages which must be delivered in milliseconds, makes

communication over transmission networks a highly-specialized field, and one for which ABB has developed a wide variety of technologies.

Optical network solutionsWide bandwidth, high bit rate and immunity to electrical interference make optical fibres the most important communications medium today. Our product range includes the latest optical access and backbone equipment, which not only meets today’s requirements, but can also handle new applications and capacities that will be required in future, thanks to features such as WDM (wavelength division multiplexing). Optical communication is the best solution for private digital networks and remains economically viable even when only a few channels are required. ABB supplies optical equipment for all levels of the power grid, ranging from access up to transmission solutions, including relatively modest but critical data volumes from harsh HV (high voltage)/MV (medium voltage) switchgear environments to the backbone communications system.

Power line carrier (PLC) solutions An existing PLC network represents a considerable investment made by a power utility over a period of many years. It is therefore rarely feasible to replace it wholesale with a broadband system, and PLC is still the most cost-effective solution

for power utility installations where low volumes of data and protection signals need to be transmitted over long distances. As the leading supplier of PLC and teleprotection systems, ABB has the experience, know-how, and resources to engineer the best possible communication solution, however complex the application. With transmission capacities up to 256 kbit/s, digital PLC links can also serve as a backup to increase the availability of important operational data and voice channels normally provided by other communication technologies.

Microwave radio – an attractive option in difficult terrainOur microwave radio products include digital transmission equipment for a wide range of frequency bands and transmission rates. It is not restricted to power line routes and can, in certain circumstances, offer an alternative to cable-based systems, especially in difficult terrain.

Telephone exchangeReliable voice communication is an essential tool for power system operators. We offer telephone communications via traditional analogue and digital public and private lines designed to support a number of specialized ancillary services that enable the user to control and operate the system faster, securely, and more conveniently.

02

01


Utility communications

Data Centre

Fibre/PTP

2.4/5/8/3.65 GHz

900 MHz

HAN (ZigBee)

HAN

Energy Storage DeviceSubstation

Feeders

Wireless Solutions for Distribution NetworksDistribution Automation, also referred to as ‘Active Distribution Networks’ or ‘Advanced Distribution Networks’ is driven by the increasing amount of Distributed Generation (DG) as well as the tighter requirements on reliability and power quality requirements coming from regulators and customers. As a result, wireless communication plays an increasingly important role in deployment of advanced distribution grid applications. ABB’s l icensed wireless distribution communication portfolio together with an open system concept and state-of- the-art technologies, allows us to tailor a wireless communication network according to specific requirements and application needs.

Tropos networks using open industry standardThe foundation for ABB’s Tropos networks is field-proven technology that includes Tropos outdoor and mobile routers; the patented Tropos Mesh OS built from the ground-up for large scale, mission-critical outdoor network deployments; point-to-multipoint base stations and subscriber units; and Tropos Control, a carrier-class wireless network management system.Tropos networks are implemented by installing wireless broadband mesh routers throughout the coverage area. These units typically mount on street lights, utility poles, traffic signal poles and other mounting locations approximately 30 feet above ground level.

Tropos mesh routers combine the indus-try’s most sophisticated mesh networking intelligence, designed from the ground up to optimize throughput in a dynamic, metro-scale outdoor network, with purpose-built hardware that is ruggedized and weather-ized to withstand extreme weather condi-tions. Each router includes one or more open-standards-based radios optimized for outdoor use.

01 An ABB AFS675 Ethernet communication switch

02 An ABB Tropos network router03 ABB Tropos network grid architecture

03


Smart Grids

Constantin Popescu-Cirstucescu, ABB Substation Automation Technology Manager, outlines how WAMS technology extends the scope of network management system.

WAMS – providing a broader outlook for the smart grids of the future

Wide Area Monitoring Systems enlarge the area that networks can see

complexity of power networks presents significant stability issues for power systems. As grids get even more heavily loaded by sudden bulk power transfers, systems become very vulnerable and even minor equipment failures can result in cascade tripping and, eventually, blackouts. Real time wide area monitoring of electricity flows is essential to provide early warning of potential network stresses, enabling them to operate closer to their full capacity while maintaining security of supply. ABB’s PSGuard WAMS technology uses GPS satellite signals to ensure that the phasor measurement units (PMUs), which monitor the condition of the power

grid, are synchronised with an accuracy of one millisecond. This enables system dynamics, such as frequency, voltage and power oscillations, to be observed in real time, regardless of the large geographical distances between measurement points - providing valuable early warning of potential network stresses.

Precise, synchronised measurementsLarge power outages are usually the result of multiple system failures that happen within minutes, and sometimes in seconds. The monitoring and control systems of individual utilities gather information from sensors within their own grid, and then evaluate

Network management is a prerequisite for any smart grid of the future. These grids will have to incorporate and manage centralized and distributed power generation, intermittent sources of renewable energy like wind and solar power, allow consumers to become producers and export their excess power, enable multi-directional power flow from many different sources, and integrate real-time pricing and load management data. ABB has long been in the vanguard of smart grid development, and we are involved in numerous projects all over the world to evolve existing power networks into smarter networks. These technologies collect, transmit, store, analyze and reliably communicate critical data from thousands of data points across power networks and over large geographical areas. Large-scale integration of renewable resources, regulation of two-way distribution grids, long-distance transmission, and incorporation of electric cars and charging facilities would be impossible without these technologies. W ide a rea mon i to r ing sys tems (WAMS) improve performance of network management systems by enlarging the area the systems can see. Satellite communications can quickly access information from neighboring grids, and use it to prevent the development of widespread faults.

Phasors provide stunning accuracyThe constant growth in competition, cross border trading activities and the increasing


this information to determine whether their system is operating to deliver the power to meet demand conditions. When things go wrong, the system either reacts automatically to take contingency actions, or displays information that allows system operators to take action. The PSGuard system gathers and analyses system data in milliseconds, compared with every two to five seconds in conventional network control systems. This means emerging network problems, like shifts in frequency, can be documented and even predicted because precise and synchronised measurements can be taken consistently across the grid. Operators can also detect emerging problems in a neighbouring grid before they build up, allowing them to take preventative action.

WAMS configurationA typical wide area measurement system or WAMS, is bui l t up on a re l iable communication system connecting power stations, network control centres and substations. The GPS satellite system is used for timing accuracy and a number

Smart Grids

of PMUs, such as ABB’s latest IEC 61850 complaint Relion RES 670, are deployed across the power network. PSGuard offers a modular and scaleable WAMs structure incorporating a number of functions such as: – phase angle monitoring – voltage stability monitoring – line thermal monitoring – event driven data archiving – power oscillation monitoring – power damping monitoring – SCADA/EMS (energy management

system) integration – communication gateway – for

real-time exchange of information between utilities

ABB currently has nine major WAMs deployments in operation. These include:

APG (Austria) – Since 2005 PSGuard has been monitoring the vital 220 kV double lines between Vienna and Ternitz substations with phase angle monitoring and line thermal monitoring.

HEP (Croatia) – Since 2003 14 PMus have been helping enhance the stability of transmission system and optimize utilization of transmission capacity.

Swissgrid (Switzerland) – Connections with from major European utilities allow monitoring of dynamics across Europe as well as providing a monitoring and early warning system for the loading of the critical north- south corridor of the Swiss transmission grid.

EGAT (Thailand) – The first WAMS in Asia was deployed in 2005 to monitor the stability of heavily loaded 230 kV transmission lines between the southern and central region of Thailand. It features Power Oscillation Monitoring to detect power swings.

The great OT/IT convergence

At the convergence point of OT/IT is the distribution management system (DMS). The DMS is what local grid operators use to manage the day-to-day operations of their networks. Advanced applications include:

– outage management to identify faults on the system and manage work crews’ response

– automated switching to re-connect customers during storms

– automated controls to optimize the grid in real time to improve reliability, reduce losses, and improve grid efficiency.

Investments in distribution technologies are leveraging OT/IT integration, commu-

nications, and advanced applications to improve grid reliability and efficiency. But, there are two other areas where utilities are making smart grid investments – util-ity analytics and distributed energy resourc-es (DERs). The first harnesses the explo-sion of meter and grid data that utilities now have from smart metering, commu-nications, and sensor investments. The second includes both renewables like roof-top solar and conventional backup gen-erators. Market analysts forecast utility analytics as the fastest growing smart grid technology area and many utilities have DER pilot programs in place. Leading the way in this OT/IT conver-gence is Ventyx, the software business inside ABB.

Many smart grid projects to date across the world have focused on the distribution level of the grid and with good reason. There are far more assets on distribution grids and most outages occur at a local level, while major blackouts remain relatively rare. For utilities, distribution grid management is now a key smart grid investment area that can improve system reliability and efficiency. One area of particular interest lies in combining operational technology (OT) and information technology (IT) to improve the operation of the distribution grid.


Cyber security

Ibrahim Cobanoglu, ABB UK Sales and Marketing manager for Substation Automation, explains why cyber security is now a vital consideration.

Cyber security – now a ‘must have’

In the past, cyber security for substation automation systems was not really regarded as an issue, or perhaps only as a ‘nice to have’. However, security threats to the grid are now a very hot topic in the media. And it is easy to understand why. The grid we know today already relies on a wide variety of digital devices and computerized controls to keep the lights on. The smart grids of the future will be even more interconnected. And the combination of those systems with public communications infrastructure creates the potential for unauthorized access.

Cyber security is a vital consideration


Cyber security

If we accept that cyber security is now a ‘must have’, then how can we protect our systems effectively against the array of hackers and criminals who might cause mischief for the grid? Security is primarily about people, pro-cesses and technologies working together to prevent an attack. It is not just technol-ogy, or a set of procedures, and it is not a one-time investment. Security is by nature a dynamic and ever-changing process. It is never ‘done.’ An important distinction that should be made with regard to security in utility sys-tems is the relationship between security and reliability. These two objectives are not always aligned. For example, the increas-ing amount of data flowing out of substa-tions back to utility control centres is highly useful for managing reliability but it pres-ents additional challenges from a security perspective. Modern ‘routable’ communication pro-tocols are seen as vulnerable, and with the proliferation of intelligent electronic devices (IEDs), the utility’s exposure to cyber attack seems to grow by the day. However, a return to older ‘serial’ protocols would not al low the bandwidth required to run advanced applications like wide-area moni-toring, and would also not offer nearly as much as much as IP (internet protocol) communications in the way of security tools to harden utility systems. Ultimately, though, reliability and security are on the same team. If a security breach allows an intruder to disrupt the utility’s operations and cause a blackout, then clearly reliability has also been compromised. Today of course, utility systems have not only grown more extensive and more numerous, they have also forged connections between one another and with remote facilities like substations. In addition, interoperability of utility systems has emerged as a priority, as demonstrated for example by the rapid adoption of open communication standards like IEC 61850. Vendors must therefore ensure their security measures do not come at the expense of interoperability.

Three key cyber security categoriesFor substation automation, the cyber security requirements can be grouped in three main categories of:

Group 1 – Basic Security Requirements:

– secure system architecture such as different security zones

– protect the electronic security perimeter

– improve robustness and hardening

– authentication and authorization (user account management)

– auditability and logging (user activity logging)

– antivirus protection

Group 2 – Enhanced Security Requirements:

– patch management – application white listing – secure communication from

outside the system using https, VPN (virtual private network)

– intrusion detection and protection systems

Group 3 – Security in protocols/comply with the latest standards e.g. IEC 62351:

– DNP (distributed network protocol) 3.0/IEC 60870-5-104 secure authentication based on IEC 62351

– central user account management

– certificate handling

ABB has identified cyber security as a key requirement and we are committed to providing products, systems and services that clearly address this issue. We take a systematic approach to cyber security through our operations on a global level. For instance, we have established the Power Systems Security Council to keep track of global needs and requirements concerning cyber security. The mandate of the council is to ensure that products and solutions used in power systems meet the expectations of our customers.

Besides continuously adapting security requirements to keep up with hanging demands, the Security Council drives

proactive R&D efforts to address emerging trends, and ensures fast and efficient security improvements. We also recognize the importance of cyber security standards and we are an active member in several industry initiatives, including IEEE and IEC. This involvement ensures that the specific needs of our customers are considered in the development of new standards and that ABB remains abreast of new developments. It also enables us to incorporate new standards into our products and systems, helping our customers to comply with new regulation as it comes into force.

To ensure reliability and availability of electricity, ABB has developed the SDM600 as a data manager for the whole system. It checks the credentials of cyberspace visitors on behalf of network equipment, it logs IED disturbances to produce comprehensive reports, and it tracks software versions to ensure everything is kept up to date, all with a unified interface for comprehensive management.

We have also established a strategic partnership with the well-known cyber security company Industrial Defender to provide in-depth monitoring, enhanced management, and protection for utility operations networks that can complement the SDM600 Data Manager platform.

Ultimately, cyber security is about much more than having a firewall and anti-virus protection. It is really a state of mind.

Security is by nature a dynamic and evolving process


Service

Russell Kinder, ABB’s Engineering and Business Growth Manager, provides an overview of a service portfolio designed to ensure total peace of mind throughout the life of a substation automation project, from commissioning through routine maintenance and on to life extension. ABB’s substation automation team works in close cooperation with the group’s global service organization to deliver seamless support services, including detailed SLAs (service level agreements), fast response and the provision of strategic spares.

Comprehensive service support

Clionet® – Data CareABB has introduced an advanced data-sharing and backup service – Clionet® – Data Care – that secures technical docu-mentation of protection and control relays throughout their entire life cycle. This is a web-based service that provides our cus-tomers with a structured storing space for technical documentation, such as relay configuration files, disturbance recordings, technical solutions, drawings and other doc-uments. Special features such as access to documents for multiple users, service-related alarm email notifications and news updates from ABB make Clionet – Data Care a unique choice for utility and indus-try customers.


Service

Extension, Upgrades and Retrofits ABB offers a range of services to evolve or upgrade to the next generation of hardware and software from old generation control equipment. This covers both ABB and oth-er manufacturers, exchange of worn parts or outdated equipment components while maintaining original plant and equipment configuration.

Maintenance Planned maintenance reduces downtime and maximizes the performance of your equipment through remote services and field services.

ReplacementWe can provide the ideal new products to replace obsolete equipment from ABB or other manufacturers in any phase of the life cycle.

Strategic spares and consumablesThe ABB life cycle management model ensures spare part availability throughout the life cycle of our substation automation products. Our extensive spare part portfolio covers the installed base from older product versions to the latest versions, and in the majority of cases spare parts will be despatched with 24 hours of receiving an order.

As an integral part of SLAs for individual customers we also maintain stocks of strategic spares for immediate availability. At the very highest level we even offer ‘hot spares’ that are installed in our own test rigs, fully configured and updated to ensure the fastest possible response.

Engineering and consultingWe strive to help customers identify opportunities and solutions to improve the performance of their system. We ensure that technical support for all our substation automation products is readily available across a very wide range of product families that are in active, classic or limited life cycle phases. Typical examples of our consulting services are: – on-site support – relay and terminal configurations

Installation and commissioningABB’s installation and commissioning service plays an essential role in ensuring that the substation automation equipment: – is correctly assembled and

connected – has the proper ratings – is correctly configured and set up

RepairsABB provides protection repair services globally for all active equipment and also very extensively for older products. The common assumption is that it is not profitable to repair faulty electronic devices. This, however, is not entirely true. The high quality and affordable pricing of ABB repair services make repairing a worthwhile alternative to a new device.

Service level agreementsABB provides f lexible service level agreements (SLAs) tai lored to meet customer’s specific operational needs. The agreement will detail response times – there are cases where we will have an engineer on site in a matter of hours – as well as other critical aspects such as remote support and telephone helplines. Ultimately, the SLA approach is the surest way for our customers to have complete peace of mind.

ABB delivers seamless support service


Project news

Relion IEC 61850 compliant IEDs get on track with London Underground

The Relion IEDs will be installed at six substations currently under refurbishment for the SSR (Sub-Surface Railway) Upgrade Package 3B project to ensure the reliability and continuity of the uprated power supplies essential for the smooth running of London Underground’s new generation rolling stock.

The Relion 620 IEDs are compliant with the very latest IEC 61850 standards and offer dual communications redundancy, sending data simultaneously using PRP (parallel redundancy protocol), HSR (high- availability Seamless Redundancy) and legacy protocols such as Modbus. This means they are compatible with existing network management systems (NMS) as well as having the capacity and compliance for future developments under the IEC 61850 standard.

Compact designThe Relion 620 design also features

an increased number of binary inputs and outputs, which means they can handle additional signals and alarms: a distinct advantage over alternative compact products. The compact design is also withdrawable, so should the need arise, they can be replaced within a few minutes,

The SSR network consists of the Circle, District, Hammersmith & City and Metropolitan lines and the upgrade will provide new air-conditioned rolling stock, new signalling, modified depots and stations to accommodate the new longer trains and a new control centre. The upgrade will increase capacity and reduce journey times. Benefits will be delivered by 2018.

REF620 IEDsUnder the contract to protect six

switchboards, a total of 64 REF620 IEDs will be installed for the protection of feeders and 16 REB611 busbar IEDs will be installed to deliver differential zoned busbar protection. The order for the REB611s is also notable as it is ABB’s first UK reference project for this type of busbar device. As an integral part of the project, ABB will provide training to ensure the smooth integration of the Relion IEDs into the new switchboards.

Relion 620 series IEDs will be installed

unlike comparable products, which are modular and would take several hours to replace. This can significantly reduce potential downtime.

Another operational benefit is that engineers can access the REF620 via a web interface for remote access to settings and data. ABB has also engineered out batteries, meaning that the IEDs are essentially maintenance-free.


Project news

Pen Y Cymoedd wind energy project breaks the mould

ABB is currently creating the grid connection for the largest capacity onshore wind farm in England and Wales. The project for the Pen Y Cymoedd wind farm in South Wales will connect the 76-turbine, 228 MW wind farm being developed by Vattenfall to the 400 kV transmission grid and is set to enter operation in 2016.

The site of the Pen Y Cymoedd wind farm

The scope of ABB’s work includes the construction and supply of equipment in two substations linked by 9.2 km of underground AC cable. A mould breaking aspect of the project is that it is the first time in the UK that ABB is supplying state-of-the-art control equipment to ensure that the wind farm will meet the rigorous power quality standards designated by National Grid’s grid code. This will be achieved by ABB’s PCS 6000 STATCOM unit, which will support the stability of grid voltage by providing variable reactive power in response to voltage transients that result from natural variation in the wind.

The STATCOM unit wil l effectively integrate all the wind turbine strings so that they behave as one large generator, able to respond instantly to National Grid requests to vary output or modify power factor.

The STATCOM unit will form part of the equipment to be installed at the hillside Pen Y Cymoedd substation, which will

control the wind farm’s output and step up the voltage from 33 to 132 kV. The substation will also house 132 kV switchgear and Relion IEC 61850 protection and control equipment. At the other end of the cable link is the Rhigos 400 kV substation, for which ABB will also supply the equipment, including 132/400 kV transformers, switchgear and protection and control equipment.

Control of the substations wil l be provided by ABB’s MicroSCADA control system. This will be a particularly complex implementation due to the variety of remote interfaces required, including National Grid as well as Vattenfall’s own control centres in the Netherlands and Sweden.

The combination of STATCOM and Relion protection and control systems at Pen Y Cymoedd is already established as an important reference and model for future wind farm connection projects in the UK.

ABB has created a new app for the Apple iPad to help its customers fully understand its substations portfolio. The app contains details on all of ABB’s substations products and how they fit within a substation layout. The ABB Substations APP includes details about GIS and AIS switchgear, transformers, protection and control equipment, as well as a myriad of other equipment. It lets users explore our substations solutions within an interactive 360˚ virtual landscape, with the ability to zoom in on particular products or installations to learn about technical details. Acting as a dedicated product catalogue, the app will be available soon via iTunes. www.abb.com

Our substation portfolio at your fingertips?

Definitely.

ABB LtdTel. +44 (0)1785 825 050Fax. +44 (0)1785 819 019 E-mail. [email protected]

Documents

ffwd automation special issue - ABB Groupnew.abb.com/.../magazines-downloads/ffwd-3-14-grid-automation.pdf · 02 abb.co.uk/ffwd Substation automation special issue From the Editor