click for a larger map
TRANSCRIPT
Click for a larger map
Caprivi Link Interconnector A 350 kV HVDC Light® system stabilizes two weak networks in Namibia and enables power trading in the expansive region of southern Africa.
The Namibian transmission system operator, NamPower, chose the HVDC Light® system to electrically connect the northeastern part of the country to central Namibia, a distance of 950 km. ABB was contracted to build the 350 kV, 300 MW transmission link between Zambezi, close to the Zambian border in the region of Caprivi, and Gerus in the central part of the country. The two networks are very weak and the HVDC Light® technology helps to stabilizes them.
Gerus substation in the central part of Namibia. Click for larger image
Zambezi substation in the Caprivi region. Click for larger image.
The HVDC Light® system is part of a greater scheme that includes a 950 km long DC overhead line, an upgrade of an existing AC overhead line from Gerus to Auas to 400 kV, the extension of the Gerus and Auas substations, and a new AC substation in Zambezi.
The Caprivi Link Interconnector, connecting electricity grids in Namibia and Zambia, ensures reliable power transfer capability between the east and west of the Southern African Power Pool (SAPP). It is also the first electrical connection between the Caprivi region of Namibia and the rest of the country, and is able to supply power to the region if normal supplies from Zambia are disrupted. Even larger islanded parts of the Namibian and Zambian grids can be supplied by the DC link, which maintains frequency control and thereby avoids power outages.
ABB was responsible for system engineering including design, supply and installation of the two
converter stations and earth electrodes.
This project extends the voltage rating for HVDC Light® to 350 kV and marks the first time the technology is used for overhead transmission.
Main dataCommissioning year: 2010Power rating: 300 MWNo. of poles: 1AC voltage: Gerus: 400 kV
Zambezi: 330 kVDC voltage: 350 kV Length of overhead DC line: 950 km Main reason for choosing HVDC: Long distance, weak networks
BorWin1 The world's most remote offshore wind farm cluster is connected to the German grid by a 400 MW HVDC Light® transmission system.
The German utility TenneT Offshore GmbH , formerly known as transpower stromübertragungs gmbh and E.ON Netz GmbH, awarded a contract to ABB to supply the power transmission that deliver power from the world’s most remote offshore wind farm into the German grid.
The BARD Offshore 1 wind farm is developed by BARD Engineering GmbH. It will consist of 80 wind generators of 5 MW located about 130 km from the coast in the North Sea. The generators feeds power into a 36 kV AC cable system which is transformed to 154 kV for the HVDC Light®offshore station. The receiving station is located at Diele, 75 km from the coast, where the power is injected into the German 380 kV grid.
The HVDC Light converter on the BorWin alpha platform with some wind turbines. Photo taken in July 2010.
ABB was responsible for system engineering including design, supply and installation of the offshore converter, sea and land cable systems and the onshore converter.
The cables were laid underwater and underground, thus minimizing environmental impact.
The BARD Offshore wind farm is scheduled to
be in operation in 2012.
Main dataCommissioning year: 2011Power rating: 400 MW No of circuits: 1AC Voltage: 170 kV (Platform BorWin alpha),
380 kV (Diele)DC Voltage: ±150 kVLength of DC underground cable: 2 x 75 kmLength of DC submarine cable: 2 x 125 km Main reason for choosing HVDC Light: Length of land and sea cables.
The NorNed HVDC link The 580 kilometer-long NorNed link is the longest submarine high-voltage cable in the world.
In December 2004, ABB received the go-ahead to proceed with the NorNed project, an HVDC transmission link connecting the power grids of Norway and The Netherlands. The ABB scope was the two converter stations and the cable system for the major portion of the cable route.
Eemshaven converter station, the Netherlands. Click for larger image.
Feda converter station, Norway. Click for larger image.
The contract was originally awarded to ABB in 2000, but restructuring in the power utility sector caused the project to be delayed. The contract is with the two state-owned power grid companies TenneT in The Netherlands and in Statnett, Norway. The interconnection, which is based on market coupling, has lead to power trading between the two countries and increase the reliability of electricity supply.
Valve hall at Eemshaven station. Click for larger image.
To reduce cable costs and cable losses NorNed has two fully insulated DC cables in spite that it is a monopolar link. This makes the current small and the cable losses low but requires a higher converter voltage (see simplified single line diagram).
Main dataCommissioning year: 2008Power rating: 700 MW No of poles: 1 ( midpoint grounded in Eemshaven)AC Voltage: 300 kV (Feda), 400 kV (Eemshaven)DC Voltage: ± 450 kV Length of DC submarine cables: 2 x 580 km Main reason for choosing HVDC: Length of sea cable and non-synchronous AC
systems
/w EPDw ULLTE0N
View this HVDC project in Google Earth!
Estlink HVDC Light link The Estlink HVDC Light link is one of the EU priority projects for the Trans-European Network.
Estlink is owned by a special purpose company: Nordic Energy Link AS. This company is owned by five Baltic and Finnish utilities: Eesti Energia, Latvenergo, Lietuvos Energija, Helsingin Energia and Pohjolan Voima. The link crosses the Gulf of Finland and connect to substations near Tallinn and Helsinki.
Harku station
The whole link is underground or underwater by high-tech extruded (oil-free) HVDC Light cables; there are no overhead lines.
Estlink is the latest part of the Baltic ring. It allows for power exchange between the Baltic countries (Estonia, Latvia and Lithuania) and the Nordel grid.
ABB received the contract for the entire HVDC Light link: converter stations and DC cables. The whole project was completed in 19 months.
Main dataCommissioning year: 2006Power rating: 350 MW No of circuits: 1AC Voltage: 330 kV (Estonia), 400 kV (Finland)DC Voltage: ±150 kV Length of DC underground cable: 2 x 31 kmLength of DC submarine cable: 2 x 74 km Main reason for choosing HVDC Light: Length of land cable, sea crossing and non-
synchronous AC systems
/w EPDw ULLTE0N
Sitemap Login A A
A ABB in India
Home About us
Products & services
News Center
Careers
Investor Relations
ABB Group
Industries and utilities
Power T&D Solutions
HVDC
HVDC References
ABB HVDC Reference Projects in Asia
Three Gorges - Changzhou
View this HVDC project in Google Earth!
Three Gorges - Changzhou HVDC Transmission The first of two HVDC power links to connect Three Gorges and eastern China.
ABB has built two HVDC converter stations for the first 3,000 MW ±500 kV high-voltage direct current power link to transmit electricity from the Three Gorges hydropower plant in central China to the
coastal city of Shanghai and surrounding area. The transmission is owned by State Grid Corporation. The 850-kilometer power link came into commercial operation in 2003.
Valve hall in Zhengping Longquan Converter Station
The Three Gorges HVDC link more than triples the amount of power currently delivered from central China to the coast, from 1,200 megawatts (MW) to 4,200 MW. In 2004 ABB was awarded the converter stations for the second 3,000 MW HVDC transmission to Shanghai.
ABB's HVDC technology promotes more efficient use of energy resources by transmitting large power loads over long distances with low losses. The link helps to meet the growing demand for power in fast developing Shanghai, China's leading industrial and commercial center.
One HVDC converter station is located at Longquan, approximately 50 kilometers from the Three Gorges power plant, and the other, Zhengping, in the city of Changzhou, approximately 80 kilometers northwest of Shanghai.
Main dataCommissioning year: 2002 Pole 1, 2003 BipolePower rating: 3 000 MWNo. of poles: 2AC voltage: 500 kV (both ends)DC voltage: ±500 kV Length of overhead DC line: 890 km Main reason for choosing HVDC: Long distance, network stability, low losses,
environmental concerns
OK
View this HVDC project in Google Earth!
Power from shore: ABB technologies at Troll A platform The first offshore HVDC Light project transmits power to Statoil's Troll A gas production platform in the North Sea.
In 2002 ABB was awarded the first project in the world for offshore transmission with HVDC from Statoil, Norway (ABB press release). This project is called Troll A Precompression Electrical Drive System (Statoil's press release). The tests on the Drive System were successfully completed in February 2005. The project combines the HVDC Light® technology and the ABB VHV Motor (Very High Voltage Motor), which is cable-wound. It consists of two transmissions, each with the rated power of 40 MW on the mechanical shaft of the VHV Motor. The inverter station on the platform is directly connected to the motor thus no transformer is needed.
The rectifier at Kollsnes (onshore station) is connected through a standard power transformer to an existing 132 kV network with a breaker. From rectifier approximately 70 km HVDC Light cable connects the rectifier with the Inverter placed on the Troll A platform. One line diagram.
The land station at Kollsnes.Click to see larger images!
The Troll platform module. Click to see larger images!
The AC side of the inverter is connected to the VHV Motor via a breaker and AC cables. The VHV Motor's outgoing shaft is directly coupled to a gearbox that deliver the right number of revolutions. The VHV Motor is governed by the HVDC Light® control system MACH 2TM.
Compared to conventional systems, HVDC Light saves weight and reduces the space the system takes up on the platform.
Main dataCommissioning year: 2005Power rating: 84 MWNo of circuits 2AC Voltage: 132 kV (Kollsnes), 56 kV (Troll)DC Voltage: ±60 kV Length of DC submarine cables: 4 x 70 km Main reason for choosing HVDC Light: Environment, long submarine cable distance,
compactness of converter on platform
View this HVDC project in Google Earth!
Sylmar Replacement Project The Sylmar East station was upgraded from 1,100 MW to 3,100 MW in 2004.
The Sylmar Converter Station’s mercury arc valves sustained damage during the January 1994 Northridge earthquake. The mercury arc valves are furthermore nearing the end of their designed life. In 1999 the Sylmar Partners ( Los Angeles Department of Water and Power (LADWP), Southern California Edison (SCE), and the Cities of Glendale, Burbank, and Pasadena ) decided to build a 500 kV, 3,100 MW Converter at the existing Sylmar East facility.
This was achieved by upgrading and modifying the existing Sylmar East converters to the 3,100 MW converters and by using the existing control building and the valve halls and as much of the existing equipment as possible. ABB was awarded the contract in 2002 and the station was put into service in 2004.
Exterior view of the Sylmar East converter building High seismic requirements has led to flexible connections in the valve hall
/w EPDw ULLTE0N
Sitemap Login A A A ABB in India
Home About us
Products & services
News Center
Careers
Investor Relations
ABB Group
Industries and utilities
Power T&D Solutions
HVDC
HVDC References
ABB HVDC Reference Projects in Oceania
Murraylink HVDC Light
View this HVDC project in Google Earth!
Murraylink - the worlds longest underground power link The second HVDC Light project in Australia.
The Murraylink 220 MW interconnector between the Riverland in South Australia and Sunraysia in Victoria is a 180 kilometer underground high-voltage power link. Murraylink is believed to be the world’s longest underground transmission system.
ABB has provided a complete HVDC Light transmission system, made up of high-tech extruded cables buried in the ground, with a HVDC Light converter station at each end of the link. The order was placed by Murraylink Transmission Company Pty. (TransÉnergie Australia), a subsidiary of TransÉnergie, the transmission division of Hydro-Québec, Canada. It is now owned by Energy Infrastructure Investments consortium and operated by the APA Group.
Murraylink Berry station Valve enclosure vith IGBT Valves
Cable laying After cable laying
Murraylink benefits both South Australia and Victoria by enabling electricity trading in Australia’s deregulating power market.
From its near tri-state border site, it can deliver power from South Australia, Victoria, NSW and the Snowy River generation in either South Australia or Victoria. Murraylink has used existing corridors and required no private easements, nor use of private land.
Main dataCommissioning year: 2002Power rating: 220 MW No of circuits: 1AC Voltage: 132 kV (Berri), 220 kV (Red Cliffs)DC Voltage: ±150 kV Length of DC underground cable: 2 x 180 kmMain reason for choosing HVDC Light: Controlled connection for trading.
Easy to get permission for underground cables.
/w EPDw ULLTE0N
Sitemap Login A A A ABB in India
Home About us
Products & services
News Center
Careers
Investor Relations
ABB Group
Industries and utilities
Power T&D Solutions
HVDC
HVDC References
ABB HVDC Reference Projects in North America
Cross Sound Cable HVDC Light
View this HVDC project in Google Earth!
Cross Sound Cable - an energy bridge to Long Island Cross Sound Cable is a HVDC Light underwater cable link between Connecticut and Long Island, New York. The developer was TransÉnergie U.S., a subsidiary of Hydro-Québec. The link is now owned by Babcock & Brown Infrastructure.
Overview of the Shoreham station New Haven indoor AC yard
ABB has provided a complete 330 MW, 40-kilometer HVDC Light transmission system. The system is made up of high-tech extruded (oil-free) cables buried under the seabed, with a converter station at New Haven, Connecticut and Shoreham on Long Island.
The Cross-Sound link improves the reliability of power supply in the Connecticut and New England
power grids, while providing urgently needed electricity to Long Island. The HVDC Light connection is also designed to promote competition in the New York and New England electricity markets by enabling electricity to be traded among power generators and customers in both regions.
Main dataCommissioning year: 2002Power rating: 330 MW No of circuits: 1AC Voltage: 345 kV (New Haven),
138 kV (Shoreham)DC Voltage: ±150 kV Length of DC submarine cable: 2 x 40 km Main reason for choosing HVDC Light: Controlled connection for power exchange.
Submarine cables.
Sitemap Login A A A ABB in India
Home About us
Products & services
News Center
Careers
Investor Relations
ABB Group
Industries and utilities
Power T&D Solutions
HVDC
HVDC Classic
HVDC Classic technology
HVDC with CCC
HVDC with Capacitor Commutated Converters (CCC)
Overview Contacts
A fundamental change to the classic HVDC system technology.
ABB introduced the concept of Capacitor Commutated Converters (CCC) to the market in 1995. This was, in fact, the first fundamental change to have been made to the classic HVDC system technology since 1954! The first CCC-station, the Garabi 2 200 MW station in Brazil, is operating since June 1999!
CCC offers the following advantages:
Improved dynamic performance Significantly better stability, in particular when connected to AC networks with low short
circuit capacity and in transmissions with long DC cables
Dependable performance in the event of AC system disturbances, with reduced risk of commutation failures
Lower load rejection overvoltages
No need to switch AC filters or shunt capacitor banks to compensate for converter reactive power consumption
CCC has proven particularly suitable in back-to-back projects where the converter station lies in the periphery of the AC networks or is connected via long lines to strong substations. Both these situations can result in a low short circuit ratio at the converter station.
Enlarge Sitemap Login
A A A ABB in India
Home About us
Products & services
News Center
Careers
Investor Relations
ABB Group
Industries and utilities
Power T&D Solutions
HVDC
HVDC Classic
HVDC Classic technology
HVDC with CCC
HVDC with Capacitor Commutated Converters (CCC)
Overview Contacts
A fundamental change to the classic HVDC system technology.
ABB introduced the concept of Capacitor Commutated Converters (CCC) to the market in 1995. This was, in fact, the first fundamental change to have been made to the classic HVDC system technology since 1954! The first CCC-station, the Garabi 2 200 MW station in Brazil, is operating since June 1999!
CCC offers the following advantages:
Improved dynamic performance Significantly better stability, in particular when connected to AC networks with low short
circuit capacity and in transmissions with long DC cables
Dependable performance in the event of AC system disturbances, with reduced risk of commutation failures
Lower load rejection overvoltages
No need to switch AC filters or shunt capacitor banks to compensate for converter reactive power consumption
CCC has proven particularly suitable in back-to-back projects where the converter station lies in the periphery of the AC networks or is connected via long lines to strong substations. Both these situations can result in a low short circuit ratio at the converter station.
Technology
The CCC circuit
Link to:
The Garabi project, Brazil Rapid City, SD, USA
False
Documentation and downloads
Show options for filtering resultArticleDoc No: 9AKK105152A8655Title: HVDC CAPACITOR COMMUTATED CONVERTERS IN WEAK NETWORKSRevision: -File type: pdfSummary: Presented st GCC-CIGRE Power 2010, Doha, Qatar, 2010-10-18--20
Cover page: HVDC CAPACITOR COMMUTATED CONVERTERS IN WEAK NETWORKS
English - 0.48 MB - pdf
Search Search
Products & Services only Rate this page
Share this page
o Your preferences: India OK English
OKEnlarge ABB contact forIndia
Vineet Sikka Find contacts for another country: Select another country
OKProvider information/Impressum © Copyright 2011 ABB. Privacy policy
db0003db004333 1b82a580e64a9fb9c1257482002f19bf Bmb2xsb3dpbmc
/w EPDw ULLTE0N Sitemap Login A A A ABB in India Home
About us
Products & services
News Center
Careers
Investor Relations
ABB Group
Industries and utilities
Power T&D Solutions
HVDC
HVDC References
ABB HVDC Reference Projects in Europe
Gotland HVDC Light
View this HVDC project in Google Earth!
Gotland: the first commercial HVDC Light project An important reason for selecting HVDC Light was that great difficulties were experienced in getting the necessary permits to build an additional overhead transmission line.
The push for renewable forms of energy has brought wind power plants to southern Gotland, a Swedish island in the Baltic Sea. Southern Gotland already had a wind power capacity of 40 MW installed, and more capacity additions were in progress. This called for additional transmission capacity, as well as for better means to maintain a good power quality, as the variable operating conditions that wind power plants are subjected to result in flicker and in variations of reactive power.
Equally important, great difficulties were experienced in getting the necessary permits to build an additional overhead transmission line.
HVDC Light’s capabilities to overcome the power quality problems in wind power plants and that the transmission was to utilize underground cables, encouraged the local utility GEAB to decide to build the world’s first commercial HVDC Light transmission. GEAB is a subsidiary of Vattenfall AB, which is financing the project together with the Swedish National Energy Administration.
The Näs HVDC Light Converter station. Laying of the two HVDC Light Cables.
The transmission link between the southern part of Gotland and the city of Visby is rated 50 MW and was put into operation in June 1999. Two 70 km long extruded 80 kV HVDC Light
underground cables, ploughed into ground close to each other, connect the terminal stations. All equipment was mounted in enclosed modules in the factory and were fully factory tested, so that civil works, installation and commissioning was kept to a minimum.
Näs HVDC Light converter station, exterior view
Main dataCommissioning year: 1999Power rating: 50 MWNo of circuits 1AC Voltage: 80 kV (both ends)DC Voltage: ±80 kV Length of DC submarine cables: 2 x 70 km Main reason for choosing HVDC Light: Wind power (voltage support).
Easy to get permission for underground cables.
Search Search
Products & Services only Rate this page
Share this page
o Your preferences: India OK English
OK ABB contact forIndia Vineet Sikka Find contacts for another
country: Select another country OK LinksGotland HVDC Light
celebrates 10 years
View video film and read more about Gotland HVDC Light:
Gotland HVDC Light project (brochure)
Video film: Gotland HVDC Light Project (large version 32.4 MB)
Video film: Gotland HVDC Light Project (small version 10.4 MB)
Gotland HVDC Light transmission - World's first commercial small scale DC transmission
Co-ordination of parallel AC-DC systems for optimum performance
The Gotland HVDC Light project - experiences from trial and commercial operation
Provider information/Impressum © Copyright 2011 ABB. Privacy policy db0003db004333 a34c41e0fe23b18cc125774a0033abbe
/w EPDw ULLTE0N
Sitemap Login A A A ABB in India
Home About us
Products & services
News Center
Careers
Investor Relations
ABB Group
Industries and utilities
Power T&D Solutions
HVDC
HVDC References
ABB HVDC Reference Projects in South America
Garabi
Brazil-Argentina HVDC InterconnectionGarabi HVDC back-to-back station The ABB HVDC CCC concept made it possible to avoid building a synchronous compensator plant at Garabi.
Each of the two 1100 MW phases of the Garabi HVDC back-to-back converter station is divided into two blocks of 550 MW each. The first phase went into commercial operation in 1999 and the second phase in 2002.
The time schedule for the completion of the first phase of this HVDC interconnection, from signing of the contract between CIEN and ABB, to commercial operation, was only 22 months, a significant challenge for a project of this magnitude. This has required considerable innovation in manufacturing and construction techniques for both the transmission lines and converter station.
Each line to from Garabi to Itá has a length of 354 km, quite challenging for operation of a converter station where there is guaranteed delivery of 1000 MW into a rather weak point. For the chosen transmission line parameters, the short circuit capacity at the Garabi 60 Hz side is about 1500 MVA, dropping even lower under contingency conditions.
Commutation capacitor
This challenge was met by using the CCC concept and with minimum sized ConTune harmonic filters. In this way fixed line reactors are used and the CCC means that the converter has characteristics to absorb or supply reactive power as required by the system. The converter acts like a static compensator, giving smooth continuos control of voltage and power flow. The minimum size of the ConTune filters helps to keep load rejection overvoltages within limits.
Overview of the HVDC station at Garabi Outdoor HVDC valves
(Click for larger images)
The HVDC converter valves are in modular housings, factory assembled and tested and shipped to site ready for operation. The control equipment and auxiliaries are similarly factory assembled and tested, reducing the installation and commissioning time. With this type of arrangement a considerable area reduction could also be achieved.
All converter bus breakers are of the modular Compact type with breaker, disconnects, and optical current transformer (OCT) integrated in one unit. The Compact breaker can be quickly installed or removed, allowing efficient maintenance as well as facilitating future changes in sub-station layout due to planned expansion.
Main dataCommissioning year: First phase 2000, Second phase 2002Power rating: 2 200 MWNo. of circuits: 4AC voltage: 500 kV (both sides)DC voltage: ± 70 kV
Type of link Back-to-back station with CCCMain reason for choosing HVDC: Asynchronous link between a 50 Hz and a 60
Hz system
Search Search
Products & Services only Rate this page
Share this page
o Your preferences: India OK English
OK ABB contact forIndia Vineet Sikka Find contacts for another
country: Select another country OK LinksOverview of the Argentina -
Brazil HVDC Interconnection
Panorama photo of Garabi
View video and read more about the Garabi project:
Video film about the Brazil-Argentina Interconnection (large version: 27.8 MB) Video film about he Brazil-Argentina Interconnection (small version: 8.9 MB)
Brazil - Argentina Interconnection I & II (brochure)
Electrical system considerations for the Argentina-Brazil 1000 MW interconnection
"Garabi" the Argentina - Brazil 1000 MW Interconnection Commissioning and Early Operating Experience
Operational Tests of Garabi II HVDC Thyristor Valves
The Garabi 2000 MW Interconnection back-to-back HVDC to connect weak AC systems
Provider information/Impressum © Copyright 2011 ABB. Privacy policy db0003db004333 d469dda8ece2307ac125774b004331f5
/w EPDw ULLTE0N
Sitemap Login A A A ABB in India
Home About us
Products & services
News Center
Careers
Investor Relations
ABB Group
Industries and utilities
Power T&D Solutions
HVDC
HVDC References
ABB HVDC Reference Projects in Europe
Hellsjön HVDC Light
View this HVDC project in Google Earth!
Hällsjön: The first HVDC Light transmission The start of a completely new power transmission technology.
The world's first HVDC Light test transmission was a 3 MW ±10 kV link between Hällsjön and Grängesberg in central Sweden. It uses a 10 km long, temporarily de-commissioned AC line owned by VB Elnät, a subsidiary of Vattenfall AB. Trial operation in the field started in March 1997.
The transmission normally serves either as a feeder into the Grängesberg AC grid or into an islanded part of that grid. In the latter case, the DC system feeds into a passive load with no other source of power. The HVDC Light transmission then alone controls the voltage level and frequency.
The 3 MW Hellsjön transmission
During the first years a number of tests have been performed to verify the HVDC Light concept, and between the tests, the stations have been in operation on a 24-hour schedule either in transmission mode or in SVC mode to gather experience. Hellsjön is also a test bench for new components and
equipment.
Main dataCommissioning year: 1997Power rating: 3 MWNo. of poles: 1AC voltage: 10 kV (both ends)DC voltage: ±10 kV Length of DC overhead line: 10 kmMain reason for choosing HVDC Light: Test transmission
Search Search
Products & Services only Rate this page
Share this page
o Your preferences: India OK English
OK ABB contact forIndia Vineet Sikka Find contacts for another
country: Select another country OK Read also:DC transmission
based on Voltage Source Converters,CIGRE SC14 Colloquium, South Africa 1997
The Hellsjön Transmission (brochure)
Provider information/Impressum © Copyright 2011 ABB. Privacy policy db0003db004333 f9f63434f160425ac125774a00348aa6
/w EPDw ULLTE0N
Sitemap Login A A A ABB in India
Home
About us
Products & services
News Center
Careers
Investor Relations
ABB Group
Industries and utilities
Power T&D Solutions
HVDC
HVDC References
ABB HVDC Reference Projects in Europe
Baltic Cable
View this HVDC project in Google Earth!
Baltic Cable HVDC project An HVDC cable that links Sweden with Germany.
One of the world's longest HVDC submarine cables links the Swedish and German power systems. The owner is Baltic Cable AB, a company owned by Statkraft, Norway. The capacity is 600 MW at 450 kV DC. The Baltic Cable HVDC project has made it possible to postpone the construction of new power production plants and that existing production plants can be used more efficiently by the owners. Both the converter stations and the submarine cable were delivered by ABB. The in service date was December 1994.
Herrenwyk converter station, Germany Kruseberg converter station,SwedenClick for larger images!
Main dataCommissioning year: 1994Power rating: 600 MWNo. of poles: 1AC voltage: 400 kV (both ends)DC voltage: 450 kVLength of DC submarine cables: 250 km Length of DC overhead line: 12 kmMain reason for choosing HVDC: Length of sea crossing
Search Search
Products & Services only Rate this page
Share this page
o Your preferences: India OK English
OK ABB contact forIndia Vineet Sikka Find contacts for another
country: Select another country OK LinksThe Scandinavia - Northern
Europe interconnections
See utilization of Baltic Cable on NordPool's web page
Provider information/Impressum © Copyright 2011 ABB. Privacy policy db0003db004333 cb2faa9b0c1ce6c5c125774a00235526
/w EPDw ULLTE0N
Sitemap Login A A
A ABB in India
Home About us
Products & services
News Center
Careers
Investor Relations
ABB Group
Industries and utilities
Power T&D Solutions
HVDC
HVDC References
ABB HVDC Reference Projects in Europe
Konti-Skan
View this HVDC project in Google Earth!
Konti-Skan Link to:The Scandinavia - Northern Europe interconnections
Vester Hassing station in Denmark with pole 2 (thyristor valves) in the foreground and old pole 1 (mercury-arc valves) in the background.
The first interconnection between Sweden and the western grid in Denmark was established in 1965 with the 250 MW Konti-Skan HVDC link across the Kattegatt from Gothenburg to Aalborg. The converter stations were based on mercury-arc valve technology and situated in Stenkullen and Vester Hassing respectively. In 2006 the mercury-arc converters were replaced by thyrisor converters.
A second Konti-Skan cable rated 300 MW was added in 1988 from Lindome on the Swedish side to Vester Hassing.
Both poles of Konti-Skan have been testing ground for new ABB HVDC developments:
Pole 1:1973: Second generation thyristor test valve (photo), 135 kV, 1,050 A (air cooled) in Vester Hassing.
1988: Light triggered thyristor (LTT) test valve (photo), 135 kV, 1050 A in Vester Hassing.
1992: The world's first air insulated outdoor thyristor valve (photo), 135 kV, 1,050 A, in Stenkullen.
Pole 2:1991: The world's first active DC filter (photo) in Lindome.
1993: The world's first electronically controlled AC filter ,Contune, (photo) in Lindome.
Main data Pole 1 (decommissioned) Pole 2Commissioning year: 1965 1988Power rating: 250 MW 300 MWNo. of poles: 1 1AC voltage: 130/150 kV 400 kV (both ends)DC voltage: 250 kV 300 kVLength of DC submarine cables:
87 km 88 km
Length of DC overhead line: 86 km 61 kmMain reason for choosing HVDC:
Length of sea crossing Length of sea crossing
Search Search
Products & Services only Rate this page
Share this page
o Your preferences: India OK English
OK ABB contact forIndia Vineet Sikka Find contacts for another
country: Select another country OK LinksSee utilization of Konto-
Skan on NordPool's web page
Energinet.dk
Swedish Power Grid (Svenska Kraftnät)
Provider information/Impressum © Copyright 2011 ABB. Privacy policy db0003db004333 1f5e1ea1b9111d9dc125774a00411eb8
/w EPDw ULLTE0N
Sitemap Login A A A ABB in India
Home About us
Products & services
News Center
Careers
Investor Relations
ABB Group
Industries and utilities
Power T&D Solutions
HVDC
HVDC Classic
HVDC Classic technology
Thyristor valves
Outdoor valves
Prototype HVDC outdoor valve at the Stenkullen station in Konti-Skan 1
Outdoor HVDC valves The outdoor HVDC valves come in modular housings, factory assembled and tested and shipped to site ready for operation.
HVDC outdoor valves makes large customs made valve buildings unnecessary with a saving in cost and time. The outdoor valves come in modular housings, factory assembled and tested and shipped to site ready for operation. They give full flexibility in station layout and reduce delivery times.
The outdoor valve unit contains a single valve function. Consequently, 12 units are needed for a 12-pulse HVDC converter. Inside the outdoor valve unit, the electrical configuration is of traditional design with thyristor modules and reactor modules as for present indoor valves built by ABB. Therefore, valve maintenance is as easy to perform as for the ABB indoor valves.
The outdoor HVDC valves at Garabi are placed on top of each other to save space.
ABB has an air-insulated outdoor prototype valve in service since 1992 in the Swedish station of the Konti-Skan 1 HVDC transmission link. The operation has been very successful, and has proven the adequacy of the concept. The prototype valve has also proved to be important for the development of HVDC Light.
The Garabi back-to-back station in the Brazil - Argentina interconnection was the first commercial plant that has been equipped with ABB's air-insulated outdoor HVDC valve.
Search
View this HVDC project in Google Earth!
The HVDC Transmission Québec - New England The first large scale mutiterminal HVDC transmission in the world.
When ABB was awarded the contract for the Québec- New England Phase II HVDC project in 1986 by Hydro Québec and National Grid USA (formerly New England Electric Systems), it was the first large multi-terminal HVDC system ever contracted. The power is generated at the La Grande II hydro power station in the James Bay area, converted into DC at the Radisson Converter Station, and transmitted over the multi-terminal system to load centers in Montreal and Boston. Phase I of the bipolar HVDC transmission consisted of two converter stations, each rated 690 MW. One terminal, Des Cantons, is located near Sherbrooke, Quebec, and the other, Comerford, near Monroe, New Hampshire. The Phase I converter terminals were placed in service in October 1986.
The contract for Phase II included three additional converter terminals as well as modifications to the existing ones. The line was extended north from Des Canton over a distance of 1100 km to the 2250 MW Radisson terminal, located within the La Grande hydroelectric generating complex. Furthermore, the line was also extended over a distance of 214 km south from Comerford to a new 1800 MW converter terminal at Sandy Pond, Massachusetts. This extension was taken into full commercial operation in 1990.
In 1992 another terminal was placed in service on the multi-terminal HVDC system. This terminal is rated 2138 MW and located at Nicolet in the Montreal area.
Radisson Converter Station Sandy Pond Converter Station
Nicolet Converter Station Valve hall in Sandy Pond
The Comerford and Des Cantons converter stations were originally to have been integrated into the multi-terminal scheme to enable even more operating flexibility, allowing five stations to operate simultaneously. After reassessing the benefits of this additional flexibility, the owners, however, elected to suspend the commercial multi-terminal integration of Des Cantons and Comerford.
Main dataCommissioning year: 1990 - 1992Power rating: 2 000 MW (multiterminal)No. of poles: 2AC voltage: 315 kV (Radisson),
230 kV (Nicolet),345 kV (Sandy Pond)
DC voltage: ±450 kV Length of overhead DC line: 1 480 km Main reason for choosing HVDC: Long distance, asynchronous networks
View this HVDC project in Google Earth!
Fenno-Skan Fenno-Skan reduces the electrical distance between major generation and load areas in Finland and Sweden from 1500 km to 200 km.
The Fenno-Skan link is owned by Fingrid and Svenska Kraftnät (Swedish Power Grid). The 500 MW Fenno-Skan 1 link was commissioned in 1989 and the Fenno-Skan 2 link will add another 800 MW, thus strengthening the Nordic power grid, enhancing the capacity for power trading and improving the security of supply in the region. In parallel with the delivery of Fenno-Skan 2, the control system of the original Fenno-Skan link will be upgraded to the fully digital MACH2 system.
Fenno-Skan 1 was originally built as a monopolar link using sea return for the current, but will now become a bipole. The stations were built in such a way that a future addition of a second pole easily could be accomplished.
Dannebo station, Sweden Rauma station, Finland
The 200 km long cable reaches the shore in Finland south of the town of Rauma, which is situated about 90 km north of Turku. A 33 km long overhead line connects the cable with the Rauma converter station.
Dannebo, the Swedish converter station for Fenno-Skan 1, is located near the Forsmark nuclear power station on the Swedish east coast, about 150 km north of Stockholm. The DC cable comes in to the converter station area, since the station lies only about 1 km from the coast.
For Fenno-Skan 2, the Swedish converter station is located further inland - in Finnböle - and a 70 km DC overhead line will connect the station to the submarine cable.
Main dataCommissioning year: Pole 1: 1989
Pole 2: 2011Upgrade Fenno-Skan 1: 2012
Power rating: Pole 1: 500 MWPole 2: 800 MW
No. of poles: 2
AC voltage: 400 kV (both ends)DC voltage: Pole 1: 400 kV
Pole 2: 500 kVLength of DC submarine cables: 200 kmLength of DC overhead line: 33 km (Finnish side)
Pole 2: 70 km (Swedish side)Main reason for choosing HVDC: Length of sea crossing
With the active DC-filter, ABB can fulfil the toughest HVDC interference level requirements with a minimum of equipment.
Demands on the HVDC converter stations regarding permitted interference levels from DC lines have become increasingly stringent in recent years. ABB has therefore developed an active DC filter that enables efficient filtering using a small-size filter. The active DC-filter is now installed in a number of HVDC projects.
Operating principles
The principle of the active DC filter is to inject a current generated by a power amplifier into the DC circuit cancelling the DC side harmonics coming from the HVDC converter. The amplifier is controlled by a high speed digital signal processor controller.
Circuit diagram of active DC filter
Performance
These measurements were taken in a prototype active DC filter that was installed in 1991 in the Konti-Skan 2 HVDC transmission.
Harmonic current content on the DC line
Active DC-filter in the Swedish station in the Baltic Cable HVDC inter-connection. The high voltage DC-filter capacitor can be seen in the right. The small house to the left contains the DC-
filter control, the amplifiers and associated equipment.
False
Vindhyachal The first HVDC project in India. The Indian power system is demarcated into five independent regional grids namely: Northern, Eastern, Western, Southern, and North-eastern Regions. The 500 MW Vindhyachal back-to-back HVDC station interconnects the Northern and Western Regions.
The HVDC station was built by National Thermal Power Corporation (NTPC ) but after the reorganisation of the Indian power sector the transmission now belongs to the Power Grid Corporation of India Ltd..
Vindhyachal exterior with theworld's first HVDC transformers
with extended delta windings.
Inside one of the valve halls
The remote Vindhyachal region hosts three super-thermal projects of NTPC within a radius of 40 km: Singrauli, Rihand (supplying power to the Nortern grid) and Vindhyachal. Vindhyachal is the largest project of NTPC with a total capacity of 2,260 MW supplying power to the Western grid.
Main dataCommissioning year: 1989Power rating: 500 MWNo. of poles: 2AC voltage: 400 kV (both sides)DC voltage: 70 kV Type of link Back-to-back station Main reason for choosing HVDC: Asynchronous networks
View this HVDC project in Google Earth! Highgate HVDC back-to-back station A 200 MW HVDC link between
two radial distribution grids in Vermont and Quebec. In April 1984 ABB received a contract for the supply of a 200 MW back-to-back HVDC converter station to Vermont Electric Power
Company (VELCO). An extremely short delivery time of 17 months was required, and the station was taken into service in September 1985. An agreement had been reached between the State of Vermont and Hydro Quebec about the import of electric power, since it was planned to shut down the Vermont Yankee Nuclear Power Station for maintenance from mid-September
1985 for a
period of at least 8 months. This lead to the shortest delivery time for any HVDC project in the world.
Bird's eye view of Highgate converter station Thyristor valves at the Highgate converter station
In 2011, ABB received the order for a refurbishment of the Highgate station. The refurbishment permits the station to run with full overload capacity at 40 degrees ambient temperature. The delivery includes new control and protection system MACH2 and valve cooling.
Main dataCommissioning year: 1985
Refurbishment: 2012Power rating: 200 MWNo. of poles: 1AC voltage: 120 kV (north side),
115 kV (south side)DC voltage: 57 kV Type of link: Back-to-back station Main reason for choosing HVDC: Asynchronous networks
View this HVDC project in Google Earth! The Intermountain HVDC transmission The second HVDC
transmission to Los Angeles.The Intermountain HVDC transmission system operated by the Los Angeles Department of Water and Power (LADWP) brings power from a coal-fired station in Utah to the
Los Angeles area. The original rated power was 1 600 MW at ±500 kV DC. Subsequently the link has been upgraded to 1 920 MW, and an additional upgrade to 2 400 MW has now been implemented. Each
pole has a 1 200 MW continuous and 1 600 MW short term overload capacity, to minimize the impact on the power system in the event of a pole outage.
Bird's eye view of Adelanto Valve hall in Adelanto
The receiving station in Adelanto is located in a seismically active area. Suspended thyristor valves are therefore used to achieve maximum security. Extremely stringent requirements were imposed on reliability. ABB’s redundant converter control system was developed to meet these performance requirements. It has become ABB’s standard for HVDC in every project since Intermountain.
ABB had complete turnkey responsibility for the converter stations, which were commissioned in April 1986.
In 2010, ABB made an additional upgrade, which includes delivery of the MACH2 control and protection system, additional AC filters and cooling system in order for the link to reach a transmission capacity of 2 400 MW.
Main dataCommissioning year: 1986, 2010Power rating: 1 920 MW => 2 400 MW No. of poles: 2AC voltage: 345 kV (Intermountain),
500 kV (Adelanto)DC voltage: ±500 kV Length of overhead DC line: 785 kmMain reason for choosing HVDC: Long distance
View this HVDC project in Google Earth! The Itaipu HVDC transmission World's second largest HVDC transmission - two major ABB HVDC links that supply São Paulo. The Itaipu HVDC Transmission Project in Brazil,
owned by Furnas Centrais Elétricas in Rio de Janeiro (an Elétrobras company), was for more than 20 years the largest HVDC transmission in the world. It has a total rated power of 6 300 MW and a voltage of ±600 kV DC. The Itaipu HVDC transmission consists of two bipolar HVDC transmission lines bringing power generated at 50 Hz in the 12 600 MW Itaipu hydropower plant, owned bu Itaipu Binacional, to
the 60 Hz network in São Paulo, in the industrial centre of Brazil.
Itaipu 12 600 MW hydropower station Foz do Iguaçu converter station
Inside one of the valve halls Ibiuna converter station
Power transmission started on bipole 1 in October 1984 with 300 kV and in July 1985 with 600 kV, and on bipole 2 in July 1987. The converter stations were commissioned stepwise in order to match the generating capacity built up at the Itaipu hydropower plant.
HVDC was chosen basically for two reasons: partly to be able to supply power from the 50 Hz generators to the 60 Hz system, and partly because an HVDC link was economically preferable for the long distance involved.
The converter stations Foz do Iguaçu and Ibiuna represented a considerable step forward in HVDC technology compared to the HVDC stations of the 1970s. The two stations are still unique in their combination of size and advanced technology.
2004 Press releases:(2004 marks the 20th year since the first stage of the Itaipu HVDC tranmission was commissioned.)
Itaipu: the singing stone with a powerful song and Visitors experience 20 years of ABB pioneering spirit at Itaipu, Brazil .
Main dataCommissioning year: 1984 -1987 Power rating: 6 300 MWNo. of poles: 4AC voltage: 500 kV (Foz do Iguaçu), 245 kV (Ibiuna)DC voltage: ±600 kV Length of overhead DC line: 785 km + 805 kmMain reason for choosing HVDC: Long distance, 50/60 Hz conversion
Dynamically suspended valves were used in PIU for the first time
due to the severe seismic requirements. Second order raises the voltage of the Pacific Intertie to 500 kV Up until the first energy crisis in the mid -1970s power consumption was increasing strongly. A number of projects aimed at securing the long-term supply of power to Los Angeles were outlined. These were necessary not only to meet the demand, but also because it was desired to close down a
number of older, uneconomical local power stations and to reduce dependence on oil-fired and gas thermal plants. It was against this background that it was decided to investigate new projects
and also the possibility of raising the capacity of existing transmission schemes. Eventually it was agreed to raise the line voltage of the Pacific Intertie. This led to the creation of the Pacific
Intertie Upgrade (PIU) project for which
TheCelilo station with Pacific Intertie Upgrade (PIU) in the foreground
ABB received the order.The PIU essentially consisted in putting a 100 kV 6-pulse thyristor converter in series with the three mercury arc converters in each pole. The upgrading was commissioned in 1985.
View this HVDC project in Google Earth! The Gotland HVDC link The world's first commercial HVDC
transmission, the Gotland HVDC link from 1954, has been replaced with a 260 MW bipole.
Gotland 1 with thyristor valve group (click to view larger photo)
The 20 MW, 100 kV Gotland 1 HVDC transmission from 1954 was the first commercial HVDC transmission in the world. The converters valves were mercury-arc valves. In 1970 the stations were supple-mented with thyristor valves which were connected in series with the mercury-arc valves. The voltage was raised to 150 kV and the transmission capacity to 30 MW.
It was the first time thyristor valves were used in a commercial HVDC transmission in the world.
Read more in about Gotland 1 in: The early HVDC development (pdf, 0,21 MB)
Gotland 2 and 3
Gotland 2 valve hall interior
In 1983 a new cable was laid between Västervik and Ygne. The rated voltage was 150 kV and transmission capacity 130 MW and the converters were built up of thyristor valves. In order to meet the greater demand and also to increase the safety of supply to the island, a decision was taken in 1985 to invest in yet another HVDC link, Gotland 3.
The original cable and terminal equipment for Gotland 1 was taken out of service and dismantled in 1986 when Gotland 3 was built.
Main dataCommissioning year: Pole 2: 1983, Pole 3: 1987Power rating: 260 MWNo. of poles: 2
AC voltage: 130 kV (Västervik), 70 kV (Ygne)DC voltage: ±150 kV Length of DC submarine cables: 2 x 96 km Length of DC overhead line: 7 kmMain reason for choosing HVDC: Length of sea crossing
View this HVDC project in Google Earth! Inga-Kolwezi In spite of the difficult situation in central Africa, this HVDC
transmission continues to deliver power. The second to longest electric power transmission in the world, 1700 km, transmits power from the Inga falls in the Congo river to the copper mining
district of Katanga in the Democratic Republic of Congo (DRC). The Inga-Kolwezi link was formerly known as the Inga-Shaba link.
It is a long way to the other end.
The Inga-Kolwezi is a ± 500 kV, 560 MW transmission. Because of the extreme line length and the difficult logistics along the route, it was decided to build two monopolar lines with four switching stations. The converter stations were built so that the two converter poles can be operated in parallel with ground return, in case of a monopolar line outage.
The ABB contract for the converter stations was signed in 1973, but due to civil unrest in the country (then called Zaire), the transmission could not be taken into service until 1982. The link is owned by DRC's national electricity utility, Société Nationale d'Electricité (Snel).
Kolwezi station
Each valve hall in Inga-Kolwezi is equipped with six double-valves of air-cooled design. At the time, it was the highest valve voltage in the world, and each single valve has 258 series connected thyristors.
Valve hall in Kolwezi
In 2009, ABB was awarded the upgrade of this link. The refurbishment, which includes delivery of new thyristor valves, high-voltage apparatus and the MACH2 control and protection system, will extend the life span of the link, enhance the reliability of the grid and ensure efficient transmission of hydro electricity across the region. It is scheduled for delivery in 2013.
Main dataCommissioning year: 1982
Upgrade: 2013Power rating: 560 MWNo. of poles: 2AC voltage: 220 kV (both ends)DC voltage: ±500 kVLength of overhead DC line: 1 700 km Main reason for choosing HVDC: Long distance
Pacific HVDC Intertie. First order 1965 The largest ABB project with mercury-arc valves. In 1965 ABB was awarded a contract together with General Electric for two converter stations for a 1440 MW, ± 400
kV transmission scheme, the Pacific Intertie. Although the technology was well established by then, the contract nevertheless represented a challenge to both the owners and the suppliers, since the line voltage, the line length and the line current
were greater than for any previous HVDC project, making it the most complex yet. The site chosen for the northern terminal was The Dalles, Oregon, which lies close to
several large power stations on the Columbia river, with Bonneville Power Administration (BPA) as owner. The southern terminal was located at Sylmar, in the northern tip of the Los Angeles basin. Sylmar is owned by five utilities, with the Los Angeles Department of Water and Power (LADWP) acting as the managing and operating
agent.
Mercury-arc valve hall in Sylmar
The mercury-arc valve formed the basis of ABB's HVDC development work in the 1960s. When the contract for the Pacific Intertie was signed in 1965, 4-anode valves of this type for 125 kV and 1200 A, with two 6-pulse converters in series, were in operation. The bold step was now taken to adopt 6-anode valves designed for 1800 A and 133 kV per converter and with three groups in series, for a transmission scheme rated ±400 kV, 1440 MW.
ABB’s undertakings for the Pacific Intertie contract in 1965 included system studies and system responsibility, the manufacturing and supply of the converter (mercury-arc) valves plus special apparatus and the control equipment, and also the commissioning.
The transmission scheme entered into operation in 1970, but shortly after this (in 1971) the San Fernando earthquake devastated the Sylmar converter station. The station building was severely damaged, as was much of the equipment, and it was not until 1973 that the station was rebuilt and operation could be restored. After a few years of operation, the owners decided to make use of the inherent capacity of the equipment and raise the transmission rating to 2000 A and 1600 MW.
The Celilo station in Oregon The Sylmar station in Los Angeles
View this HVDC project in Google Earth! Skagerrak 1-3 HVDC Interconnections Below are descriptions of the
Skagerrak 1-3 HVDC transmission links An electric DC power transmission between Norway and Denmark (using the Thury system) was proposed as early as 1922. But it lasted 54 years
until the first 500 MW was realized in 1977. The Skagerrak 1&2 with 500 MW was commissioned in 1976-77 and Skagerrak 3 with 440 MW in 1993. The link goes between
Kristansand in southern Norway and Tjele on Denmark's Jutland peninsula. The link is owned by Statnett in Norway, and Energinet.dk in Denmark. Link to:Overview of the Scandinavia -
Northern Europe interconnections where the reasons for this link are described.
Aerial overview of Tjele converter station with the converters for Pole
1&2 to the left and Pole 3 to the right.
The converter stations for Skagerrak 1&2 (1976-77) were the first stations to employ the modern circuitry and station design that is employed even today. The first stations with thyristor valves were designed according to the principles adopted for mercury arc valve stations. But ABB adopted new design principles for the converter stations of the Skagerrak 1&2 link:
Valve hall in the first Skagerrak link
twelve pulse converters
quadruple thyristor valves
no 5th or 7th harmonic filters on the AC-side
converter transformers close to the valve-hall with the valve-side bushings in the valve-hall
The Skagerrak 1&2 link was the first one to employ ABB´s second generation of air-cooled valves (which also were used in the CU and Inga-Shaba transmissions).
The Skagerrak 1&2 link went through a control and protection system upgrade in 2007, when the advanced MACH2 control system was installed.
When Skagerrak 3 (1993) was built it was decided to reconfigure the existing bipole so that Pole 1 and Pole 2 operate with the same current direction. Thereby achieving a better current balance, since the Pole 3 has a higher current than Pole 1 and 2.
Simplified single line diagram of the Skagerrak 1-3 scheme.The converter stations of Pole 3 was the first in the series of ABB cable projects during the 1990's that also includes Baltic Cable, Kontek and SwePol.
In 2011, ABB was awarded the Skagerrak 4 link - read more about it here.
Main dataCommissioning year: Pole 1&2: 1976-77
Pole 3: 1993 Pole 4: 2014
Power rating: Pole 1+2: 500 MW Pole 3: 440 MWPole 4: 700 MW
No. of poles: 4 (2 bipoles)AC voltage: Pole 1&2: 300 kV (Kristiansand),
150 kV (Tjele)Pole 3: 300 kV (Kristiansand), 400 kV (Tjele)Pole 4: 400 kV (Kristiansand), 400 kV (Tjele)
DC voltage: Pole 1&2: 250 kV (HVDC Classic)Pole 3: 350 kV (HVDC CLassic)Pole 4: 500 kV (HVDC Light)
Length of DC submarine cable routes: Skagerrak 1-3: 127 km Skagerrak 4: 140 km
Lenth of DC land cable route: Skagerrak 4: 104 kmLength of DC overhead line: Skagerrak 1-3: 113 kmMain reason for choosing HVDC: Length of sea crossing, asynchronous link.
For pole 4, HVDC Light was chosen for its premier power quality features.
View this HVDC project in Google Earth! New Zealand HVDC - the interisland link A unique HVDC project that was decided when the first 20 MW Gotland link was the only HVDC transmission in operation and where new additions have been made. The AC systems on the South and North Islands of New Zealand were interconnected in 1965 by a ±250 kV, 600 MW HVDC Interisland Link. In 1992 the grid owner Transpower upgraded the HVDC link to 1240 MW. The existing link, with its mercury arc valves, was modified to operate in a bipolar "hybrid" scheme together with a new thyristor converter. The first stage of the upgrade was to add the 700 MW thyristor converter, and the second step was to operate the old and new equipment as a hybrid bipole rated 1240 MW. The two mercury arc valve poles were connected in parallel to form an upgraded pole 1.
Bird's eye view of Benmore converter station. Pole 1 in the front and Pole 2 in the background. Pole 2 valve hall interior, Haywards
On average 80 per cent of New Zealand's electric energy production is from hydroelectric sources, most of which is produced on the South Island. However, the North Island accounts for almost two thirds of the total electric energy demand, and has a peak load almost twice that of the South Island. After the upgrade of the HVDC transmission as much as 25 per cent of the North Island's electricity demand is met by South Island hydro capacity.
Main dataPole 1 and 2 1965-91
Commissioning year: 1965 (mercury arc valves)
Power rating: 600 MWNo. of poles: 2DC voltage: ± 250 kV
Pole 2 after 1991Commissioning year: 1991 (thyristor valves)Power rating: Nominal 560 MW,
Continuous overload: 700 MW DC voltage: -350 kV
Pole 1A+1B after 1992Commissioning year: 1992 (hybrid sceme)Power rating: 1240 MWDC voltage: +270 and -350 kV
Complete transmissionLength of DC submarine cables: 42 kmLength of DC overhead line: 575 kmMain reason for choosing HVDC: Long distance, including sea crossing
Toughened glass o Technical features
o Suspension insulators
o Coated insulators
o HVDC applications
o Railway insulators
Porcelain
Composite
Surge Arresters
Worldwide locations
DOWNLOADS
“Energy for the future”
Sediver High Resistivity Toughened Glass for HVDC applicationsSediver was the first manufacturer to develop an insulator for HVDC applications back in the 50's.
In the 1980's, Sediver started new studies on the impact of the HVDC specific electric stresses on the long term performance of high voltage line insulators.This study led to the development of the High Resistivity Toughened Glass (HRTG).Sediver HRTG insulators are specially designed to resist corrosion, pollution accumulation and other phenomena arising from DC operation.
Today, Sediver HVDC experience is:
Above 4 million toughened glass insulators installed all around the world on the most prestigious DC transmission lines up to 800 kV HVDCAbove 40 years of experience in HVDC applications
HVDC T/L where Sediver HVDC toughened glass insulators have been installed
HVDC specific stressesleading to
Sediver solution Sediver HRTG insulator
Ionic migrationIonic accumulation
Special glass chemistryimparting high resistance, reducing ion flow and localised thermal stress
Metal part corrosion
Protection of the metal end fittingsPure zinc collar bonded to the capPure zinc sleeve bonded to the pin
Electrostatic attraction ofthe dust on insulator surface
Adapted glass shell designwith wide spacing between ribs andincreased leakage distance
1. USA, Vancouver Islands 42km ± 260 kV DC, 19672. USA, Pacific Inertie 1360 km ± 500 kV DC, 19693. USA, Dickin s on - Coal Creek 687km ± 500 kV DC, 19674. Canada, Kettle Winnipeg Nelson River ± 450 kV DC, 19725. Canada, 6th James Bay ± 450 kV DC, 19886. Canada, New England 1480 km ± 450 kV DC, 1984/867. Brazil, Rio Madeira, 2500 km ±600 kV DC, 20128-9. Brazil, Itaipu I - II 2 x 800 km ±600 kV DC, 1984/8710. Mozambic, Cahora Bassa 1420 km ± 500 kV DC, 1977
11. Sweden, Fenno-Skan 2 Project ± 500 kV DC, 200912. Finland, Fenno Skan / Rihtnie – Rauma 23 km ± 400 kV DC, 1988 & 199813. India,Chandrapur Padghe 752 km ± 500 kV DC, 199714. India, Rihand Dadri 814 k ± 500 kV DC, 198715. India, Biswanath Agra 1825 km ± 800 kV DC, 2010/1116. India, Ballia Bhiwadi 780 km ± 500 kV kV DC, 2008/200917. China, Deyang – Baoji 534 km ±500 kV DC, 200918. China, Yunnan - Guangdong 1440 km ±500 kV DC, 200819. China, Ge Hu 930 km ±500 kV DC, 200920. China, Tianshengqiao – Guangzhou 1050 km ±500 kV DC, 200121. China, Guizhou - Guangong 1100 km ±500 kV DC, 200322. New Zealand, North South Island 535 km ±350 kV DC, 2010/11