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December 2004

www.peimagazine.com

• Offshore to Onshore • Making More out of Biomass • Sulphur Management • Intelligent Networks •

December 2004

Can Africa earnits stripes?

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Contents

Is it African or African’t? (Power Report)

PEi December 2004

December 2004 Volume 12, Issue 12PennWell Global Energy GroupWarlies Park House, Horseshoe Hill,

Upshire, Essex EN9 3SR, United Kingdom.Phone: +44 1992 656 600

Fax: +44 1992 656 700Worldwide Web: http://www.peimagazine.com

Managing EditorSiân Green

Acting EditorJanet Wood

Features EditorNigel Blackaby

[email protected]

Assistant EditorRobin Rowshangohar

International Sales DirectorDan Noyau

[email protected]

Studio ManagerKarl Weber

[email protected]

DesignScott Jones

ProductionCristina Vazquez

Publisher & Editorial DirectorJunior Isles

Group PublisherNick Ornstien

Corporate HeadquartersPennWell Corporation

1421 S. Sheridan Road, Tulsa , OK 74112 USATelephone: +1 918 835 3161

Fax: +1 918 831 9834

Vice President, Publishing Director, Global Energy Group

Robert W. Smock

Circulation DirectorGloria Adams

Circulation ManagerJanet Orton

ChairmanFrank T. Lauinger

President/CEORobert F. Biolchini

Circulation and subscriber enquiriesP.O. Box 3243, Northbrook, IL 60065-3243 USA

Tel: +1 847 559 7501 Fax: +1 847 291 4816E-mail: [email protected]

Power Engineering International, ISSN 1069-4994, is published monthly by PennWell Global Energy Group, Warlies Park House, Horseshoe Hill, Upshire, Essex EN9 3SR, United Kingdom. Tel: +44 1992 656 600. Fax: +441992 656 700.

©Copyright 2004 by PennWell Corporation, 1421 S. Sheridan Rd., Tulsa, OK74112, USA. All rights reserved.

Subscriptions/circulation and reader enquiry office: Power EngineeringInternational, PO BOX 3243, Northbrook, IL. 60065-3242, U.S.A. Paid annualsubscription rates: Worldwide $187, E.U. $160, U.S.A./Canada $170, UnitedKingdom $130. Single or back copies: Worldwide $16, U.S.$10.

U.S.A. circulation only: Power Engineering International, “PERIODICALSPOSTAGE PAID AT RAHWAY NJ”. Subscription price is $170 PeriodicalsPostage Paid at Rahway NJ. Postmaster send address corrections to: PowerEngineering International, C/O Mercury Airfreight International Ltd. 365 BlairRoad, Avenel, NJ 07001.

® “Power Engineering International” is a registered trademark of PennWellCorporation. POSTMASTER: Send address changes to Power EngineeringInternational, PO BOX 3243, Northbrook, IL. 60065-3242. U.S.A.

MemberAmerican Business Press

Business Publications Audit3

Printed in the U.K. GST No. 12681315`

RegularsUpfront 3

News Analysis 5

World News 7

Diary Dates 19

Equipment Roundup 34

Power ReportAfrican or African’t 16Investing in Africa can offer four times the rate of return than in G-7 countries and doublethat in Asia. So why is it that more companies are not rushing to unleash Africa's vast untapped potential?

FeaturesTransmission and Distribution 20The UK’s first high voltage offshore substation connects the Barrow wind farm to the transmission grid and is an important component in helping manage wind’s contribution to the networkCogeneration 24Biomass residues are plentiful across most of the ASEAN region and its use in small scale power generation is established. The COGEN 3 programme is spearheading biomass cogeneration to achieve better efficiency and fuel savings Emission Control 28Sulphur trioxide emissions have been the subject of increasing attention but a new injection technology is working to help wipe plumes from the sky

IT FocusBuilding the intelligent electricity network 32

New technology capabilities are making it possible for electricity distribution companies to make informed decisions about asset replacement, upgrades, network security and regulatory approvals for investment

News in Brief

Wind passes the tipping point AnalysisThe evidence shows wind is now a serious player in the power industry.

African countries agree joint power project Page 7

Areva set for partial privatization Page 9

New Zealand regulator steps in to smooth the way Page 11

US companies await mandatory carbon cuts Page 13

Enel wins tender for SE Page 15

www.peimagazine.com 1

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3PEi December 2004

Well it has been a long time coming but last month,after 13 years, the South-East Europe grid has beenre-synchronised with the rest of Europe.

A press release issued by the UCTE (Union for the Coordinationof Transmission of Electricity) stated: “UCTE performed a historicachievement when the disconnection of the power system of thesouth east of Europe, resulting from the war events in ex-Yugoslavia, was overcome after 13 years on November 1, 2004.From Lisbon to Athens, to Sofia and Bucharest, the same UCTE frequency is now beating again in the heart of electrical Europe.”

Indeed it is a historic achievement and one which should havea number of positive impacts for the rest of Europe. According tothe UCTE, several major goals have been achieved through thisproject. Firstly, the reconnection was the main prerequisite forthe progressive integration of the South European electricitymarkets into the markets of the UCTE zone going beyond EUfrontiers. Secondly, it provides a basis for improving reliabilityconditions within the whole of the UCTE zone.

This reliability issue is an important point. We can all recall theblackouts that spread across parts of Europe during the latter half of 2003 – blackouts which underlined concerns overtransmission grid reliability. The UCTE later stated that a singlemajor outage in the context of the high flows across theBelgium system in March, April and July and across the Austriannorth to south 220 kV lines in winter could have had severe consequences.

With both zones now operating as a single synchronous system, the robustness of the entire system will be increasedsince power plants in the parts of Europe that were previouslydisconnected can now be called upon to compensate for outagesin other parts of the network. Marcel Brial, secretary general ofthe UCTE said: “Now all power plants from Portugal to Bulgariacan participate and raise output to balance the system in theevent of an outage.”

The reconnection will also have a positive impact on theEuropean electricity market as a whole. It means that the elec-tricity markets in southeast Europe and the EU InternalElectricity market are now physically integrated. With anincreased number of routes for potential electrical energy flows,opportunities for power trading are increased while congestionin specific parts of the network will be reduced.

Brial commented: “Although there is no specific lack of infra-structure, we have seen the northern Adriatic area, or electrical

path into Italy come under pressure. The problem is, we just don’tknow how the market will use the system i.e. where the mainareas of trading will be.” While the UCTE does not see a deficien-cy in system structure, it acknowledges that it will have to waitseveral months to see how the flow in electrical patterns willlook after the reconnection.

Improved reliability and greater trading opportunities are allwell and good but there was perhaps a more important messagethat Brial wanted to convey. It was the fact that the reconnec-tion demonstrated the ability of countries to work together. “Thereconnection shows that investment decisions in transmissioninfrastructure can be coordinated beyond national borders. For over a decade the UCTE has managed to keep engineers up to date with the latest technical specifications so that they were ready to make the reconnection as soon as the politicalagreement was there. It was also an excellent example of howthe TSOs have had to coordinate their efforts. You can imaginehow difficult it was for Croatia and Serbia to commit to coordinating their investment in transmission infrastructure, and to coordinate the way in which they would reconnect,”explained Brial.

Looking further ahead, the studies being carried out by theUCTE underline that technical achievement is often well ahead ofpolitical will. The UCTE currently has requests on its desk forstudies on connecting Turkey and Russia to the UCTE grid. Brialalso noted that “although not yet on the desk, there is talk ofclosing the European-Mediterranean Ring”. This would synchro-nously link Europe to all the countries around the Mediterranean.“It seems the TSOs are the guys always looking ahead of thetroops to see what might be ahead,” said Brial.

It’s a shame that the TSOs are not the ones leading the politi-cal troops – they seem well adept at making the ties betweencountries that are necessary to make sure we are all operating onthe same wavelength.

Junior Isles, Publisher & Editorial Director

Renewing old ties

“With both zones now operating as a single synchronous system, the robustness of the entire

system will be increased”

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Analysis

PEi December 2004 www.peimagazine.com

Wind passes the tipping point

“Wind is not a hobby any more, it’s a serious business” says HerbertPeels of GE. The evidence backs him up, as Janet Wood reports.

Back in June, speakers at the BritishWind Power Association’s annualmeeting speculated that the industry

was reaching the “tipping point”: soon itwould be holding its own within the powerindustry. Just five months later, that shiftwas in evidence at the European WindEnergy Association’s (EWEA’s) meeting inLondon: Patricia Hewitt, UK Minister forTrade and Industry, insisted “we meanbusiness” on wind power and the exhibi-tion hall saw major energy industry playerscompeting for investment dollars.

What changed between June andNovember? Perhaps most significant in thelong term was Russia’s decision to ratify theKyoto Protocol. European utilities werealready preparing to deal with a carbon-constrained future: “TheKyoto protocol and meet-ing those obligations is oneof the top five worries” ofEuropean utilities, notedJayesh Parmar, VP for utili-ties market restructuring atconsultant Capgemini,which canvasses Europeanutilities’ views on deregula-tion in its annual GlobalUtilities Survey, and exam-ines market statistics in itsObservatory.

What is more, it is clearUS utilities are also takingpost-Kyoto constraints veryseriously. As our story onpage 13 reveals, most anticipate limits on carbonemissions within the nextdecade.

The scepticism of theBush administrationnotwithstanding, this broad acceptance ofthe post-Kyoto situation is reflected in theUS on a state level. Some 18 states have setrenewables targets – by no means all ofthem at the Democratic end of the politicalspectrum. And although moves to intro-duce a Federal ‘portfolio standard’ requir-ing a proportion of renewables failed, therewas broad support for extending the pro-duction tax credit that subsidises windpower production. Apart from its creden-tials for the green lobby, the opportunity tobuild expertise and manufacturing capabil-ity in a growing sector, and wind’s role in

reducing foreign energy dependence, gaveit credibility across the political spectrum.That means that even if the US never offi-cially signs up for Kyoto, the US windindustry could still remain the largest in theworld.

What else has changed? Investment deci-sions on conventional generation are farfrom clear cut at present. “Price signals arenot good enough,” said Parmar, echoingsimilar comments from other industrysources. Capgemini’s annual survey revealsthat electricity markets are developing fromcompetition based on price to react morelike other commodity markets, so “forcesof supply and demand are beginning toestablish prices” and respond to recentchanges in oil and gas fuel prices and con-

straints in fuel supply. But there is concernthat the market has not developed farenough to secure investment in capacity inthe long term. “It has moved on from cen-tral planning and the decision-makingprocess has been left to market and theplayers,” Parmar explained. “The levels ofprice and liquidity are good for six totwelve months, but signals are weaker moving onward from there. And there isstill a concern that regulators are too keen to interfere and that increases the perceived risk.”

For wind, it may be that the investment

climate is at least as certain as for conven-tional capacity. The proof is in EWEA’sexhibition hall, where the power industry’smajor manufacturers have grabbed turbinecompanies to secure a share of the market.

GE Wind Energy moved in early. HerbertPeels, general manager for Europe, pointsout that wind is one sector where powercompanies can make long term assump-tions on income. The UK’s RenewablesObligation regime, for example, allowscompanies to plan out to 2015.

Peels said the presence of big players likeGE helped overcome resistance in the con-ventional power market. What is more, acompany like GE already understood itscustomers concerns on headline issues likegrid compatibility. “It makes the whole dis-

cussion much easier,” hesaid. “When we focus ongrid compatibility we havesystems that comply with thegrid code and we can take asystem approach to optimisepower quality.”

The company’s AndreasWagner agreed: “There arestill myths,” he said, “andyou find people have in mindan old turbine that, forexample, can't fulfil gridrequirements. But GE haslots of competencies in thisarea and there has been lotsof development. In someaspects of operation modernwind turbines have bettercharacteristics than some gasturbines”

At this stage of develop-ment there is work to bedone and opportunities for

fast moving companies to make their mark.“We see it as the company’s task to bringdown costs,” Peel explained. “New materi-als we expect in five to ten years, and newcontrol systems in three to five years.”Larger turbines will also be on the way.

“Ten or twenty years ago this was a play-ground for idealists,” said Wagner, “butGE’s entry is confirmation that wind isbecoming mainstream and it’s a reaffirma-tion that it is serious business. In the nexttwo years it will grow to a $10 billion mar-ket.” The wind industry is a player in theworld power game at last.

The Bush administration may be sceptical about the role of renewables, but many states aresetting capacity targets

AZ: 1.1% by 2007 60% solarCA: 20% by 2017CO: 10% by 2015CT: 10% by 2010HI: 20% by 2020

IA: 2% by 1999IL: 15% by 2020MA: 4% by 2009MD: 7.5% by 2019ME: 30% by 2000MN: 19% by 2015*

NJ: 6.5% by 2008NM: 10% by 2011NV: 15% by 2013 solar5% of total annuallyNY: 24% by 2013PA: varies by utility

RI: 16% by 2019TX: 2.7% by 2009WI: 2.2% by 2011

* MN has a minimum requirementfor one utility, Xcel.

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More news at www.peimagazine.com 7PEi December 2004

Bulgaria: Germany's E.ON hasacquired the Bulgarian regionalelectricity utilities GornaOryahovitza and Varna, whichtogether have a 25 per cent marketshare. E.ON has taken a 67 percent stake in each company for atotal of g141m ($184m).

Ghana: The Electricity Company ofGhana has begun a five-year gov-ernment-backed exercise to replaceits entire power transmission sys-tems in order to ensure sustainablepower supply in the country.

Iran: Iran began filling its biggestreservoir dam with water inNovember. The hydropower plantthat will be built beside the Karoun 3dam will have an installed capacityof 2000 MW and produce 4 TWh ofelectricity each year.

Israel: Ben Gurion InternationalAirport is to build its own 80 MWprivate power station as part of theairport's new Terminal 3.Construction of the plant is depen-dent on a link-up with the nationalnatural gas pipeline and surpluspower would feed into the nationalgrid.

Israel: Israel Electric Corporationhas awarded a $2.5m contract toEmerson Process Management forthe modernization of turbine andboiler feed pump control systemsat the four unit 1400 MW MaorDavid Power Station A in Hadera.Emerson is to install a redundantOvation control system at eachunit, linked to the existingEmerson WDPF data processingand monitoring system.

Oman: Areva's Transmission andDistribution division has won an$18m contract in Oman for the sup-ply of high-voltage gas insulatedswitchgear. Areva will build andinstall three 220 kV substations forBahwan Engineering Company,subcontracted by Oman's Ministryof Housing, Electricity & Water.

Syria: Syria's Public Establishmentof Electricity for Generation &Transmission has selectedGermany's Fichtner to evaluatebids to build a 750 MW combinedcycle power plant at Deir Ezor inthe North East. The turnkey con-tract for the estimated $350m plantinvolves the supply of two 250 MWgas turbines and a 250 MW steamturbines.

UAE: The first wind power plant inthe UAE has been opened. Theexperimental plant on Sir Bani Yasisland, Abu Dhabi, cost Dh9.33m($2.54m) and has a capacity of 850 kW. If successful, more suchplants are planned.

Zimbabwe: Zimbabwe’s ElectricitySupply Authority (ZESA) has report-ed a record annual loss of $163bnin 2003. Power tariffs, a rising billfor power imports and a huge debtburden were blamed. ZESA hasbeen criticised for being without aboard of directors for nearly a year.

News digest

World Newsinternationalinternational

The five African countries ofAngola, Botswana, Congo,Namibia and South Africa haveagreed to establish a jointpower project aimed at boost-ing the supply of low cost elec-tricity. The venture will becalled the Western PowerCorridor Project and will beput together by power utilitiesin the five countries, each of

which will have an equal sharein a new joint venture companyto be registered in Botswana'scapital, Gaborone.

The project is part of theNew Partnership for AfricanDevelopment, a programmeadopted by the African Unionfor economic development ofAfrica. It is intended to be envi-ronmentally friendly and

designed to ensure that theeconomic development of theregion will not be constrainedby energy shortages.

The goals of the projectinclude building hydropowerstations in the Congo, Angolaand Namibia and increasingtrade in electricity by investingin joint venture projects thatallow sharing of capital costs.

Utility companies from coun-tries neighbouring Lithuaniahave written to the LithuanianPrime Minister, asking for apostponement in the plannedshutdown of Unit One of theIgnalina nuclear power plant.The 15000 MW unit is due tobe switched off by 1 January2005, in order to comply withan undertaking given to theEuropean Union, in exchangefor financial assistance. The

utilities have requested that thisbe deferred until a new 450 MW thermoelectric powerplant in Kalingrad is opened inNovember 2005.

The Ignalina NPP was inher-ited from the former SovietUnion and although consider-able safety measures have beentaken, its lack of radioactivecontainment means it falls shortof international standards.

Belenergo, Russian JES

Rossii, Estonian Eesti Energioaand Latvian Latvenergo point-ed out that shutting down theIgnalina unit before the newplant was opened could desta-bilize the power systems inneighbouring countries. Theunit shutdown is expected toresult in power exports fallingsubstantially due to the plannedclosure at the end of this year.Lietuvos Energija exported 7.5 TWh of electricity in 2003.

The Union for the Co-ordina-tion of Transmission ofElectricity (UCTE), the orga-nization that co-ordinates theinterests of transmission systemoperators in 22 Europeancountries, has announced that,as of 1 November, South EastEurope’s power system wasreconnected to the rest of itssystem after a 13-year interval.

The resynchronization of the

two UCTE zones has been amatter of highest priority toUCTE for many years after dis-connection occurred resultingfrom the war events in ex-Yugoslavia.

In a statement the UCTEsaid, “From Lisbon to Athens,to Sofia and Bucharest, thesame UCTE frequency is nowbeating again in the heart ofelectrical Europe.”

South Africa has agreed toadditional finance of R500m($83.2m) for the state-backedPebble Bed Modular Reactorcompany for new turbinemachinery and running costs.The nuclear reactor develop-ment programme is part ofSouth Africa’s drive to diversifyits energy sources.

Following the withdrawal ofUS-based Exelon from theproject in 2002, the govern-ment has been searching for anequity partner to provide theR1.2bn required for the facilityand to finance a fuel plant. Theadditional finance agreed bythe government was requireddue to the delay in securing apartner, although talks withlocal and international poten-tial investors are said to beongoing.

The project has come underopposition from environmental-ists, who have appealed againstgovernment approval.

African countries agreejoint power project

Utilities seek Ignalina shutdown delay

Pebble Bedinvestment

SE Europe grid reconnected

German utility group E.ON islooking to further its naturalgas and power generation inter-ests in Russia through expand-ed cooperation with Gazprom.For its part, Gazprom is seek-ing to branch out into powergeneration activities throughthe relationship with Europe’ssecond-largest utility.

E.ON plans to secure “strate-gic projects” in natural gas andelectricity production in Russiaand in fuel exports and market-

ing in Europe, Gazprom said ina statement. The utility, whichhas a 6.5 per cent stake inGazprom, has agreed to buy23bn cubic metres of gas a yearto ship to Germany andSwitzerland.

Gazprom has built up its posi-tion in power generationthrough a ten per cent interest inRussian utility Unified EnergySystems (UES), as well as a “sig-nificant” stake in Moscow’smain utility, Mosenergo.

Gazprom, E.ON cooperation

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France: The French Commissionfor Energy Regulation (CRE) hasreported that since industrial andcommercial companies and organi-sations have been allowed tochoose their electricity supplier,EDF remains dominant. It has lostonly 11 per cent of the market-place, but it has had to renegotiatewith clients who together accountfor 37 per cent of the market.

Germany: The world’s largest solarpark is to be built in Germany withSiemens to supply all of the electri-cal equipment to run the photo-voltaic generation system. Made upof 57 600 solar panels, the 10 MWphotovoltaic system, built byPowerLight Corp. will cover a totalarea of 25 hectares and will use aninnovation whereby the solar panelswill automatically follow the travel ofthe sun.

Germany: German energy groupE.ON is considering the construc-tion of a new coal fired power sta-tion at Datteln at a cost of g800m($1bn). The project would replacethe existing plant at Datteln andmark the start of a programme torenew the group's power stations.

Hungary: Eon AG has acquired amajority stake in the Hungarian oiland gas wholesale enterprise MOL.The group’s gas subsidiary hastaken a 75 per cent share in MOL'sgas trading and storage enterprisesand a 50 per cent interest in its gasimport company.

Portugal: International Power (IPR)has successfully completed theacquisition of a 75 per cent share-holding in the 990 MW combinedcycle gas turbine (CCGT) turbogaspower station in Portugal from RWEPower AG. The purchase price ofg205m ($267m) has been adjustedto a final cash payment upon clos-ing of g193m to reflect cash distrib-utions to shareholders during 2004.

Spain: Spanish electricity companyUnion Fenosa has reported a 6.2 per cent rise in net profits inthird quarter 2004 to g135.5m($17m), due largely to increasedelectricity sales to Mexico andColombia. Sales in the third quarterwent up 2.3 per cent to g1.45bn.

UK: Energy Minister Mike O’Brienhas published the UK government'splans for the review of theRenewables Obligation (RO). TheRO ensures all electricity suppliersproduce a specified and increasingamount of energy from renewablesources.

News digest

World Newseuropeeurope

France's Finance Minister,Nicolas Sarkozy, has confirmedthe intention to partially priva-tize French nuclear groupAreva.

A stake of between 35 percent and 40 per cent will beoffered to the market in thefirst half of 2005. Areva’s cur-rent capitalisation is someg10bn ($13bn).

The ministry added thatAreva would be able to grasp anumber of development oppor-tunities internationally follow-ing its enlarged access to capital

markets above the current 4 percent level. The governmentwill, however, continue to hold“directly or indirectly” morethan half of Areva's capitalgiven the strategic importanceof nuclear energy to France.

Areva's president, AnneLauvergeon, has called for theprivatization from the begin-ning but neither the previousJospin government or the cur-rent Raffarin regime were con-vinced of the need to sell partsof an entity covering the entirenuclear cycle.

It is understood that the trigger for the current changeof mind was the launch of theEPR reactor programme whichwas seen as opening up inter-esting financial prospects forthe enterprise.

Lauvergeon met the govern-ment's finance ministerial teamin early November and madewhat ministry sources say was a“strong pitch” for an openingof the group.

Areva posted a turnover ofg8.2bn last year with net profitsof g389m.

A report on a financial andindustrial strategy forElectricité De France (EDF)has indicated that it favours aEuropean deployment of EDFrather than a radical contrac-tion that would confine it tothe German marketplace.

The Roulet Commission'sprovisional report notes thatthe current fragile financialstructure leaves little room formanoeuvre and concludes that

EDF's international expansionhas had a negative effect onbalances.

The Commission hasendorsed the development ofEDF on a European scale thatwould entail EDF remaining inthe UK market, increasing itsstake in EnBW in Germanyand, in the longer term, acquir-ing 50 per cent or 51 per centof Edison in Italy. It would alsomaintain its presence in China.

Siemens and DanregnVindkraft A/S have enteredinto an agreement wherebySiemens will acquire BonusEnergy A/S. The purchase ofone of the world's five majorsuppliers of wind energy sys-tems will see Siemens take itsfirst step into the emergingmarket.

World market volume forwind energy systems is m6bn($7.9bn) and growth rates of10 per cent are anticipated overthe coming years.

Bonus Energy A/S has aworkforce of 750 and annualsales of approximately g300m.

Vattenfall plans to publish ten-ders early next year forSweden’s first full scale off-shore wind farm, to be sited 7 km offshore at Örestad. Thewind farm will have 48 turbinesrated at 2.5-3 MW. The SEK1.5bn ($218m) project isexpected to start up in 2007.

The wind farm will morethan double Vattenfall’s cur-rent Swedish wind capacity,comprising 45 turbines up to 3 MW, “some of them verysmall”, said Vattenfall’s GoranDandenell. A second offshoreproject, with five turbines gen-erating 15-20 MW, is underdevelopment at Karlskrona inthe Erland Strait.

Areva set for partial privatization

EDF strategy banks on growth Swedish windgoes offshore

Siemens enterswind market

The French site of Cadarachenow seems the most likely tohouse the InternationalThermonuclear ExperimentalReactor (ITER) project,according to sources in theEuropean Commission.Negotiations are still underwaybut the Commission has saidthat it is “optimistic” thatCadarache will be chosen.

Some sources suggest that

the Japanese may have conced-ed privately that the case for aJapanese site has been lost andwill yield the argument inexchange for compensation.

A European Commissionsource said a new accord envis-aged that ITER would be builtat Cadarache and a draft agree-ment has been prepared whichstipulates that the Japanese“should receive something”.

French site favourite for ITER

GE Energy has been awarded acontract to repower theWindpark Hartmannshain inGermany, which will triple thecapacity of the site from 2.5 MWto 7.5 MW.

GE Energy will replace sevensmaller wind turbines that werebuilt in the early 1990s withfour of its most recent 1.5 MWmodels. The repowered site's7.5 MW of capacity is expected

to annually produce approxi-mately 14 000 MWh of windgenerated electricity.

Herbert Peels, general man-ager Europe for GE Energy'swind operations, said, “Therepowering potential for windfarms in Germany is enormous,with estimates ranging from1000 MW by 2010 to 4000 MW of new capacity dur-ing the next decade.”

German wind farm to treble capacity

Correction:

The article titled “Tisza sets newstandards” in the November issueof PEI, (p39-43) incorrectly statedthat two boilers had been equippedwith low NOx emission burnersfrom RGM, USA. The equipmentwas in fact supplied by RJMCorporation (EC) Ltd, UK.

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China rise: Electricity consumptionin China will rise by 14.6 per cent in2004, compared to 2003, accordingto a forecast from the China ElectricPower Enterprises Federation andthe Guodian Power EconomyResearch Centre.

China: Zhang Ghuobao, China'svice minster at the StateDevelopment and ReformCommission, said China would pri-oritise hydropower development.Another minister noted China'shydro development stood at 24 percent of potential, compared to morethan 60 per cent elsewhere.

India: Bharat Heavy Electricals is toconstruct a 1000 MW coal firedplant in Chhattisgarh. The four 250 MW units will be commissionedin two phases, the first in late 2007.

India: India's LNJ Bhilwara Group isto partner with Statkraft Norfund onhydro projects in India. The 192 MW Allain Duhangan project inHimachal Pradesh may be the firstjoint project.

Indonesia: The Indonesian govern-ment has granted a licence for a219 MW hydro power plant in northSumatra. The $250 million plantshould start up in 2008.

Indonesia: The Asian DevelopmentBank has offered financial supportto build a transmission line fromSarawak to Kalimantan. The 150 kVline would transport power fromSarawak hydro plants.

Indonesia: Three new gas firedpower stations are to be built inSouth Sumatra, Indonesia. Thelargest, Borang, will provide 100 MW using gas from the Borangfield. Two more plants will use gasfrom other fields to generate some50 MW jointly.

Pakistan: Pakistan is to reduce theterm of agreements for new oil andgas based power projects to 15 to20 years, compared to the current25 to 30 years. Hydro projectswould remain at 25 to 35 years.

Philippines: Data from thePhilippines Department of Energy(DOE) has shown that the countryneeds to invest around PHP359bn($6.3bn) in power generation pro-jects until 2014.

Taiwan: Taiwan Power Co. willinvest more than NT$10bn ($299m)in developing wind power genera-tion in the next 10 years. Under theplan, Taipower will install at least200 wind power generators with atotal installed capacity of 300 000kW. The first generators will be setup in the coastal regions of thewestern part of the island.

Vietnam: Vietnam Coal Corp. plansto build a power plant in QuangNam Province next year. The 30 MW power plant near Nong Soncoal mine in Que Son District willcost VND600bn ($38m) and will becompleted in 2007.

News digest

World Newsasia-pacificasia-pacific

New Zealand ElectricityCommissioner Roy Hemming-way will become the first regu-lator of the country’s deregu-lated oil and gas industry, nowthat the Electricity and GasIndustries Bill has become law.

When the electricity industryin New Zealand was unbundledand privatized it was regulatedthrough the existing consumerlaw, with no dedicated regula-tory body. But the path of thederegulated industry has been

far from smooth: mergers andacquisitions among the newcompanies coincided with sev-eral years of low rainfall: theresult, in New Zealand’s hydro-reliant system, was winterpower shortages and appeals tosave energy, leading to wide-spread public concern. Powerproducers were accused of fix-ing the market, although a gov-ernment enquiry pronouncedthe accusations unfounded.

An attempt to set up a system

of self-regulation by the powercompanies failed in 2003 andthe government’s response wasto install the ElectricityCommissioner. Now theCommissioner’s role will betransformed. The law sets up a“co-regulation” regime for thegas and electricity industries,which will encompass securityof supply, consumer protec-tion, competition, demandmanagement, and distributedgeneration.

Mindanao, in the Philippines isto be the site of a unique solar-hydro tandem project backedby the International FinanceCorp, the investment arm ofthe World Bank, and local utili-ty Cagayan de Oro ElectricPower & Light Co (Cepalco).

The project comprises a 950kW grid-connected solar array,covering an area of 2 hectares,and a 7 MW hydro power plant

known as Bubunawan. Cepalco chairman and CEO

Ramon Abaya said the solararray would be the largest inSoutheast Asia, and said it “willallow Cepalco to use the solarPV power for daytime peakdemand and maximise the useof hydro power fromBubunawan”.

The cost of the PV array willbe $5.4m.

Pakistan has rejected six fasttrack power plant proposalsfrom foreign and localinvestors, including two fromthe US, citing lack of gas avail-ability. All six projects were inthe Karachi area.

The decision comes at a timewhen the Karachi ElectricSupply Corporation (KESC)faces a shortfall, estimated at

60 MW this year but likely torise to 1300 MW by fiscal year2010.

A senior government officialsaid that in view of looming gasshortages, the government haddecided on a major policy shift,rejecting proposals for gas firedstations at green field sites andputting in place a revised gasallocation plan.

Other government sourcessaid two of the power projectsthat had been shelved becauseof the policy shift were HawksBay (600 MW) and Gadani(300 MW), developed by SuiSouthern Gas Company andKESC, both offered to privatesector applicants by theMinistry of Water & Power lastyear.

GE Energy is to supply fourturbine generator sets for theXi Xia Yuan hydro power plant,under construction on theYellow River in China’s HenanProvince, in a contract worth$35m.

The hydro plant, owned andoperated by Yellow River Water& Hydropower DevelopmentCorporation, will have a totalinstalled capacity of 144 MW,generated from four GE-designed and supplied Kaplanturbines. GE will also design,manufacture and supply foursets of governors, four 35 MWvertical generators, and foursets of excitation systems andunit automation systems. Theequipment will be manufac-tured in GE Hydro Asia’s facil-ity in Hangzhou City,Zhejiang.

The plant will provide 70 MWof electricity to the regional gridwhen it starts up in 2006.

New Zealand regulatorsteps in to smooth the way

Solar-hydro project launched

Gas shortages halt proposed Pakistan projects

GE hydro winsin China

Australian electricity supplierOrigin Energy has announcedplans for a gas fired power sta-tion to be built in westernVictoria at a cost of A$1bn($723m). If approved, workwould begin on the 1000 MWstation in two years, with con-struction taking a further twoyears.

The power station would add12 per cent to the state’s gener-ating capacity and would be

fuelled by gas from a recentlydiscovered field, known as theOtway Basin, off Victoria'ssouthwest coast.

A 78 km pipeline will deliverthe gas to the site.

Victoria currently relies veryheavily on brown coal for itspower, because of its easy avail-ability in the state. Over 6000MW of its total of around8000 MW capacity is coalfired.

New plant for Melbourne

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Argentina: Argentine distributorEdenor has approved a cash offerfor its entire $500m debt, accordingto Business News Americas. Theoffer is part of a strategy to reducedebt.

Brazil: A consortium of Brazilliancompanies has jointly won an auc-tion with Spanish engineering com-pany Abengoa for the constructionand 30-year operating licences oftransmission lines. The auctionswere held by Brazil’s electricity reg-ulator, Aneel, on the Sao Paulostock exchange.

Canada: Irving Oil has announcedplans to build a 500-750 MW gasfired power plant in New Brunswick,tieing in the approval it has gainedfor an LNG terminal near Saint Johnharbour. The plant could supplyone-third of the province’s powerneeds and would head off a loom-ing energy crunch.

Central America: Bids may becalled in April next year for a trans-mission line that will connect sixcentral American countries, accord-ing to the Regional Commission forElectricity Interconnection. The 300 MW, 1800 km line, is due inoperation in December 2007.

USA: Jerry Abramson, mayor ofLouisville, Kentucky, discussed thefuture of LG&E Energy with E.ONchairman Wulf Bernotat. There havebeen rumours the German parentwanted to sell the company;Bernotat said the company has notdecided whether to leave the US.

USA: Santa Rita Jail in Dublin,California, is to be powered by fuelcell. The jail will be the site for FuelCell Energy's first 1 MW unit, whichwill be installed in partnership withChevron Energy Services.

USA: Nevada Power Company hasselected Flour Corp to complete acombined cycle power station inClark County. Work ceased on the1200 MW plant in 2003; now thefirst unit should start up in late2005.

USA: The US DOE is to award $75million in grants in its newHydrogen Fuels Initiative. Thegrants follow recommendations in arecent National Research Councilreport on the hydrogen economy.

USA: Las Vegas Valley WaterDistrict has approved a $22.6mcontract to initiate the developmentand construction of a 3.1 MW pho-tovoltaic solar energy project thatwill be one of the largest ever builtby a public agency in the US.

Uruguay: UTE, Uruguay’s stateowned power company, has askedfor revised bids on the turnkey con-tract to build a 350-400 MW com-bined cycle thermoelectric plantafter none of the companies pro-posals complied with the technicalrequirements. The plant will coverone third of Uruguay’s peakdemand.

News digest

World Newsamericasamericas

More than half the US powerindustry believes the US willenact mandatory limits on car-bon dioxide emissions in thenext ten years, according to asurvey carried out by PAConsulting Group. Nearly halfthe respondents believedmandatory limits would comesooner – within five years.

PA surveyed senior managersinvolved in developing andimplementing environmentalpolicies at 19 US generatingcompanies during the first halfof 2004. The companies,

including large and smallinvestor-owned utilities, non-regulated generators and co-operatives, accounted for 29per cent of the US’s electricpower generation in 2003. PAsaid the survey was intended inpart to allow companies tobenchmark themselves, onenvironmental issues, againsttheir peer organizations.

The questionnaire, titledEnvironmental survey 2004,found that respondents “over-whelmingly” believed green-house gas buildup was a politi-

cal problem, although less thanhalf the respondents saw thebuildup as a scientific problem.Less than half the respondingcompanies said they were incor-porating carbon dioxide emis-sion limits into business plan-ning, blaming their lack ofplans on regulatory uncertainty.

The survey also investigatedother environmental planningissues including cap and tradeprogrammes, mercury regula-tion, compliance planning, andthe likely effect of the electionon planning.

Four Brazilian distribution net-work operators (DNOs) areexpected to receive formalapproval early 2005 for loanstotalling Reals2bn ($695m).The loans, from Braziliannational development bankBNDES, are part of an exten-sive bailout for the country’spower sector.

BNDES stock investmentdepartment head ValterManfredi told BNAmericas thatloans had already beenapproved for Guarania group(controlled by Iberdrola ofSpain), AES Eletropaulo (con-trolled by AES of the US) andBrazil-owned Grupo Rede.

The fourth loan, due for finalapproval in January, is thoughtto be EDF-backed Light, ofRio de Janeiro.

The loans are part of a rescueprogramme for power compa-nies to help them improve theirbalance sheets following powerrationing in 2001 and 2002.However, the loans come withconditions: companies mustagree greater transparency,greater accountability andshares listed at level two on theSao Paulo stock exchange. Thecompanies have also beenrestructuring. BNDES has lentthe power sector Reals5.4bn sofar during 2004.

The Electric Power ResearchInstitute (EPRI) is to join with18 US utilities with coal-firedgeneration interests to acceler-ate work on cleaner, more effi-cient coal power stations. Theinitiative, “CoalFleet forTomorrow”, also aims to develop options to manage car-bon dioxide emissions.

Announcing the programme,EPRI noted that coal providesover half the US’s electricpower, and the US and othercountries have extensive coalreserves.

Hank Courtright, EPRI’svice president of generation

and distributed resources, saidthe programme would “pre-serve this abundant source offuel as a vital component in theelectricity generation mix.”

He said the focus in the firstyear would be on acceleratingmarket integration of integrat-ed gasification combined cycle(IGCC) technology, aiming at2005 to 2015. Later the pro-gramme would move to ultra-supercritical pulverized coal,supercritical circulating flu-idized bed combustion, andother firing technologies, andto options for capturing andsequestering carbon dioxide.

US power companies awaitmandatory carbon cuts

Brazilian bank plans bailout

EPRI boost for clean coal

Dynegy is to increase its gener-ating capacity in the northeastUS by acquiring Sithe Energiesfrom ExelonCorp. The acquisi-tion will bring Dynegy the1042 MW Independence com-bined cycle plant, along withfour gas-fired merchant plantsin New York and fourhydropower plants inPennsylvania.

Subject to regulatoryapprovals, Dynegy will make acash payment of $135 millionand take on debt of $919 mil-lion to acquire Exelon’s ExRessubsidiary, which owns bothSithe Energies and SitheIndependence. The latter holdsa 750 MW firm capacity agree-ment with Con Edison, whichlasts until 2014.

Dynegy said the acquisitionwould transform an array oftolling and swap contracts intoDynegy intracompany agree-ments, retaining cash flowswithin the group and mitigat-ing their financial effect.Dynegy’s Bruce A Williamson,chairman, president and CEO,said the deal addressed one ofthe company’s three long-termtolling obligations. Dynegywere also pleased to be expand-ing their power generationbusiness in the recovering NewYork market.

Dynegyacquires SitheEnergies

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APT's fifth: APT Hungaria haslaunched its fifth European branch,planned to target the south east ofthe continent. Recent figures havesuggested that it is an area forgrowth, due the further liberalizationof the region's energy market. For example, Hungarian businessvolume is estimated to grow to 1 billion kWh, corresponding to amarket share of 3 per cent.

Wabag sells: VA Technologie AGhas announced the closing of thesale of the domestic business ofWabag Germany and WabagFrance. The sale of locations VeoliaWater Systems, a division of VeoliaEnvironment, follows VA Tech'sannouncement in September, that itwas to sell the WABAG FluidizedBed Business Area.

EnBW in black: German electricitygroup EnBW emerged from the redin the first nine months of this yearwith net profits of g183.7m($239.7m), compared with a netloss of g1bn in the same period of2003. Sales fell 4.2 per cent tog7.2bn, but the company has said itis maintaining its forecasts ofresults and dividends for 2004 as awhole.

Forced sale: German energy groupE.ON AG is expected to acquireYougansneftegaz, the natural gassubsidiary of the Russian oil com-pany Yukos, according to theRussian deputy minister for economic development, AndreCharonov. The sale of 76.8 per centof Yukos is to be offered at an estimated $3.7bn.

Capstone contracts: CapstoneTurbine has received new ordersfrom distributors in Japan andFrance for MicroTurbine energy systems totalling 2 MW. The com-pany said Takuma Company, one ofthree major Capstone distributors inJapan, placed an order for just over1 MW of microturbines, taking itscommissioned CapstoneMicroTurbines total to over 100 inJapan. In France, meanwhile,Soffimat placed a follow-on orderafter the success of a landfill project north of Paris.

Iberdrola boosted: Spanish elec-tricity group Iberdrola has posted a13 per cent increase in third quarterprofits to g282m ($368m). It said ithad benefitted from extra powerfrom its windfarms and a new gasfired power plant in Mexico. Thecompany also revised upwards itsestimate of the expected operational life of its nuclear plants,which is reflected in g17m of profits. Iberdrola's operating profitsin the reporting quarter went up 14 per cent to g673m.

China: Siemens Power Generationis to join with Shanghai ElectricGroup to build nine gas turbines forfour combined cycle plants inChina. The company said the g210 million order would be delivered in late 2005.

News digest

World Newscompaniescompanies

The Slovak government has approved a recom-mendation by Economy Minister Pavol Ruskothat Italian utility Enel be named the winner of atender for a 66 per cent stake in SlovenskeElektrarne (SE), Slovakia’s dominant power pro-ducer. Czech power giant CEZ was runner-up inthe tender.

Enel has indicated that its growth inside Italy islimited by the industry regulator. However, itexpects demand in Slovakia to rise strongly, withthe economy posting growth of 5.4 per cent inthe second quarter of 2004, compared to 0.3 percent in Italy.

The decision means that exclusive talks on aprivatization agreement will now be launched bythe government, which still controls 34 per centof SE, and Enel. The two sides were expected tocome to an agreement by the end of November,Rusko told the CTK news agency.

Enel submitted the highest bid of g840m($1.1bn) for SE, followed by offers of g690mfrom CEZ and g547m from Russia's Inter RAO.

SE is the largest power producer in Slovakia.Its hydro and thermal plants account for some 85 per cent of the country’s power production.

Nordic Windpower has signedan exclusive agreement withEnergy Nevada to establishNordic’s US manufacturingactivity in Carson City, Nevada,USA.

The agreement will make theNevada plant Nordic’s firstmanufacturing site in the US,and it is from there that Nordicand Energy Nevada will con-struct wind turbines for distrib-ution in North America.

The company said recentaction by the Governor’s officeand the Public UtilitiesCommission in creating theRenewable Energy Trust Fundhas reinforced the belief thatNevada has the potential tobecome one of the largestsources of renewable energy inthe US.

Westinghouse is to supply eightreplacement steam generatorsfor the Diablo Canyon nuclearpower plant, sited in San LuisObispo county, California.According to Westinghouse,the new generators being sup-plied are a “technicallyadvanced” version of its Model54F design. They will be fabri-cated by ENSA in Spain.

The contract, worth over$100m, was placed by plantowner and operator Pacific Gas& Electric Co (PG&E). Localreports say the total cost of thereplacement, due to take placeduring refueling shutdowns in2008 and 2009, will be$700m.

Responding to calls to replacethe nuclear plant with new gen-erating facilities, PG&E said itwould cost $1.2bn more togenerate power from othersources than it would to

complete the steam generatorreplacement.

Meanwhile, Westinghousehas also won a contract for areplacement vessel head for theBeaver Valley nuclear station inShippingport, Pennslyvania.The company had alreadysigned to provide replacementvessel head hardware and con-trol rod drive mechanism hous-ings, which penetrate the vesselhead.

The replacement head con-tract was placed by the plantowner, FirstEnergy NuclearOperating Company.

The replacement vessel headand associated upgrades will beinstalled during a spring 2006refueling outage. During thatoutage the plant’s three steamgenerators will also be replaced;the replacement steam genera-tors will also be supplied byWestinghouse.

Enel wins tender for SE

Nordic andEnergy Nevadasign turbineagreement

Two replacements for Westinghouse

US-based FuelCell Energy, Inchas announced that it hasentered into an agreement tocombine its Canadian solidoxide fuel cell (SOFC) opera-tions into Versa Power Systems(Versa). In exchange, FuelCellEnergy will receive stock inVersa, increasing its holdings inVersa from 16 per cent to 42per cent.

FuelCell Energy believes thatby consolidating SOFC tech-nology development into a sin-gle entity it will have a greater

opportunity to commercializeSOFC products under the USDepartment of Energy’s 10-year, $139m Solid State EnergyConversion Alliance (SECA)programme.

FuelCell Energy recentlyannounced sales of its fuel cellto Tokyo. With its Japanesepartner, Marubeni, it has alsoformed a strategic alliance withPosco to distribute its fuel cellsin Korea and then worldwide.The three companies will alsocollaborate on research.

FuelCell Energy to combineoperations with Versa

Financing for Bahrain’s firstindependent power project hasbeen completed, according toAl Ezzel Power Company(EPC). EPC is jointly ownedby the Belgian-Gulf consor-tium Tractebel EGI and theGulf Investment Corporation.

The $500m, 900 MW, com-bined cycle gas turbine will besited in the Hidd industrialarea. Phase one (470 MW) isdue to start up in 2006 withphase two the following year.

Bahrain powerdeal signed

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December 2004 PEiwww.peimagazine.com

t around 450 kWh p.a.,Africa has the lowest percapita electricity consump-tion in the world. Perhapsthis reflects the fact that

only 10 per cent of the continent'spopulation has access to electricity.The northern and southern regionsaccount for over 80 per cent of elec-tricity generated, and nearly threequarters of electricity is generated inEgypt, South Africa, Libya,Morocco and Algeria. This distinctlack of capacity coupled with theuneven regional access to powerpresents a compelling opportunityfor investors.

Shortfalls in electricity generationand supply within each country haveencouraged grid interconnectionsbetween them. Regional networkshave tried to increase access to powerby forming power pools; but whilesuch initiatives are helpful in the shortterm, long-term solutions will have tocentre on building new capacity.

The trendsIf inadequate generation is the mostobvious motive for companies toexplore the power market in Africa, araft of supporting trends is furtherenhancing its growth potential. Overthe past decade, nationalised powercompanies in most countries havebeen partially or completely priva-

tized. Restructuring domestic utili-ties has boosted the number of IPPs,build-own-operate-transfer (BOOT)and build-operate-transfer (BOT)schemes. These new energy policiesare creating real opportunities forprivate power firms.

Many countries are aiming toincrease rural electrification over thenext decades. The most highlydeveloped programme is in SouthAfrica, where the national energyregulator is has a range of schemes.Most of the power in rural areas isbeing supplied by connection to thegrid. However, the remoteness ofmany rural communities is likely tomake such schemes costly and diffi-cult. As a result distributed genera-tion (DG) technologies, bothrenewable and conventional, arelikely to make strong gains.

The development of new offshoreoil and gas resources in South Africaand Nigeria is another growth area.Commissioning new gas fired power

stations in thenear term willincrease cen-tralised capacity.Meanwhile, awidened gasnetwork willprovide oppor-tunities for localgeneration andpresage a movetowards dieselfuelled gen-sets.

In general, thedeclining costsof completepower systems,installation andcomponents areacting as a spur

to market expansion. Reduced costsare expected to boost adoption lev-els by making power affordable to awider base of end-users.

Growth constraintsAfrica's electrical sector is rife withopportunities but has accompanyingchallenges. Most of these difficulties- high capital costs, the lack of

resources and the slowdown ininward investment - are persistent,long term and are creating road-blocks in rapid market development.

A paucity of funds in most Africannations has been compounded bythe capital outlay required for powersystems. This is a restraint to marketgrowth. While falling costs will drivethe market in the long term, projectdevelopment in the near to mediumterms will continue to be impededby high capital requirements.

Many African economies lack theresources and funding to implementdevelopment schemes. What ismore, finances from developmentagencies tend to be spread thin overseveral competing projects. Tocounter the dearth of funds, coun-tries have been attempting to attractprivate sector investment. But suchinvestments have been governedmore by the prospect of availablereturns than by their social value.Foreign investments have beenforthcoming, but have not fulfilledtheir potential. While many foreigncompanies consider Africa as capableof providing excellent returns, theyare also wary of the high risk factors.

General investments in Africa haveestablished the highest rate of return- four times more than in G-7 coun-tries, double that in Asia, and twothirds more than in Latin America.However, attracting foreign invest-ment remains problematic. Forinstance, world foreign direct invest-ment into Africa fell from a high of$17 billion in 2001 to $6 billion in2002. While much of this had to dowith the slow recovery of the globaleconomy, continued political andsocial instability is a deterrent overthe long term.

Despite concerted efforts seekingto boost uptake levels, adoption ofelectricity in rural markets remainslow. Several rural communities thathave recently been provided withaccess to the grid have made limiteduse of the resource. Due to the rela-tively high cost of electricity manyhave reverted to traditional forms ofenergy production, such as biomass.

16

AFRICA

Investing in Africa can offer four times the rate of return in G-7 coutriesand double that in Asia. So why is it that more companies are not rushing to unleash Africa's vast untapped potential?

Colin O’Hanlon, industry analyst, power and energyFrost & Sullivan, UK

A

Figure 1. In thenear term expan-sion will be dri-ven by new offshore gaspipelines

4000

Large Conventional Power Projects (Africa), 2000-2010

Source: Frost & Sullivan

3500

3000

2500

2000

1500

1000

500

0

2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010

African or African't?

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December 2004 PEiwww.peimagazine.com

Increased capacitiesWhile all power technology sectorsare forecast to develop, fossil andlarge hydro appear to offer the mostconsistent growth opportunities.Gen-set markets are expected toremain robust, with some expansion.

Despite large-scale dependence onhydropower, conventional fossilfired capacities comprise the bulk ofthe installed base. They are forecastto maintain positive growth over thelong term. In the near term, expan-sion is set to be driven by new off-

shore gas pipelines feeding new cen-tralised generating facilities.

Coal fired capacities remain thelargest contributor to conventionalenergy generation although a num-ber of large gas turbine stations havebeen built in recent years. Withnearly 66 per cent of the total to2010, the northern region is expect-ed to develop the overwhelmingmajority of new projects, followedby the southern (17 per cent), west-ern (15 per cent) and, central (2 percent) regions.

Hydropower is Africa's only signif-icant grid-connected renewableenergy source. Compound annualgrowth to 2010 has been calculatedat 94 per cent. This is based on thehigh amount of capacity due forcommissioning towards 2010.

There is significant promise of newdevelopments. The hydro potentialof Congo alone could supply threetimes as much power as Africa cur-rently consumes. Despite the enor-mous potential, however, the viabili-ty of future projects will hinge ontheir impact on the environment andon human settlements.

The central region is expected todevelop around 47 per cent of pro-jects to 2010, trailed by the south-ern (21 per cent), western (20 per

cent) and eastern (9 per cent)regions.

The compound annual growthrate of the African gen-set market iscalculated at 4.2 per cent overallbetween 2001 and 2010, with posi-tive annual growth to 2010. Thenorth is likely to exhibit the highestlevels of demand until 2010. Oftotal DG technology sales, thelargest proportion is projected to bediesel gen-sets.

Demand for renewable technolo-gies is forecast to increase to 2010

with significantincreases inwind, smallhydro and solarPV across allregions. Butwhile renewableenergy is expen-sive, additionsto the installedbase will be limited.

The com-pound annualgrowth for thesmall hydromarket to 2010is calculated at12 per cent. Themajority of pro-jects are in the

central region (60 per cent). Theeastern region is likely to account for17.5 per cent of the new projects,followed by the northern (10 percent), southern (7 per cent) andwestern (5.5 per cent) regions.

Installations of solar PV have beenmounting recently, with high poten-tial. South Africa, Egypt, Ghana,Morocco and Uganda are appraisingor installing PV in rural areas. Large-scale projects will increase the instal-lation rate in Egypt and SouthAfrica: overall market growth ispegged at 27 per cent to 2010.

The southern region is set todevelop the majority of projects to2010 (62 per cent) while the north-ern region will house almost all theremainder.

Levels of wind turbine installationshave fluctuated over the past fewyears. More consistent growth isnow projected, with a compoundannual growth of 20 per cent fore-cast to 2010. The annual installationrate is set to rise due to proposals inEgypt, Morocco and South Africa todevelop a substantial capacity. Thenorthern region is expected todevelop most projects (84 per cent),especially in Egypt (up to 600 MW),and Morocco (around 400 MW). Inthe southern region, South Africa

(160 MW to 2010) and Namibia(10 MW) are the main sites.

Biomass represents a critical ener-gy source in Africa, almost all of itconsumed on a domestic scale insub-Saharan regions. There is poten-tial for hundreds of small scale (500kW) plants, but they are unlikely toprovide large long term capacity.

The microturbines market inAfrica is still undergoing structuralchange and demand remains rela-tively low. However, sales areincreasing and centred on the oiland gas sector. Between 2001-2010, compound annual revenuegrowth is likely to be 24 per cent.

The scope The dearth of village electrificationprogrammes has underlined the rela-tively small size of the hybrid solu-tions market, but there is tremen-dous scope for growth and largerural populations with no access togrid-supplied electricity offer thehighest potential. Growing at a com-pound annual rate of 23.3 per centover 2002 to 2010, revenues mayreach $24.8 million. Major impetusis expected to come from SouthAfrica, which plans to intensify itsrural electrification initiatives.

The most established hybrid com-bination is PV with a genset. Windturbine and gen-set combinationsare secondary. However, lowerprices and better performanceshould encourage growth in small-scale wind power solutions. Otherrenewables are peripheral to hybridpower systems and have generallylow growth prospects. Fuel cells arethe exception and may reach realisticcommercialisation by 2007 to 2010.

One more nuclear station could bebuilt in South Africa. However, theproject is uncertain due to hostilityto this form of electricity generation.

Eastern Africa has great potentialto develop its largely unexploitedgeothermal resources. Kenya hasover 120 MW of installed capacitybut has plans to develop around550MW more to 2020. Djiboutiintends to develop between 230MW and 860 MW and Ethiopiaplans to develop 1000 MW.

The African power market presentsimmense opportunities for all typesof generating technologies over asustained period of time.

Investment in Africa has the capac-ity to provide exceptional returns.However, it can be highly risky.Realising the potential of Africa'spower markets will depend on secur-ing financial aid in a climate of polit-ical, economic and social stability.

18

AFRICA

Figure 2. Morelarge hydropowerprojects will beconnected before2010

8

7

6

5

4GW

3

2

1

0

2000

Source: Frost & Sullivan

2001 2002 2003 2004 2005 2006 2007 2008 2009 2010

Large Hydropower Projects (Africa), 2000-2010

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DiarydatesDecemberPOWER-GEN International, 30 November - 2 December2004, Orange County Convention Center, Orlando, USADetails from: PennWell PowerGroup, 1421 S. Sheridan Road,Tulsa, OK 74112, USATel: +1 918 832 9286 Fax: +1 918 831 9161Email: [email protected]: www.power-gen.com

Biogas - how to sustain outputfrom today's No.1 renewable, 9 December 2004, CouncilChamber, IEE, Savoy Place,London, UKDetails from: RPA RenewablePower Association, 2nd Floor, 17 Waterloo Place, London, SW1Y 4ARTel: + 44 (0)20 7747 1830 Fax: + 44 (0)20 7925 2715Email: [email protected]

January 2005

DistribuTECH, 25 - 27 January2005, San Diego ConventionCenter, San Diego, CA, USADetails From: PennWellCorporation, 1421 S.Sheridan,Tulsa, OK 74112, USATel: + 1 918 835 3161 Fax: + 1 918 832 9251Email: [email protected]: www.pennwell.com

Utilities Asset Management 2005,25 - 27 January 2005, Jolly St Ermins, London, UKDetails From: Alex German, IIRConferencesTel: + 44 (0) 20 7850 7603Email: [email protected]: www.iir-energy.com

ASIA Power, 27 - 28 January2005, Hilton Hotel, SingaporeDetails from: Ms. Marcy, AsiaBusiness Forum Pte Ltd, 3 RafflesPlace, Bharat Building, # 09-01,Singapore, 048617 Tel: + 65 6536 8676 Fax: + 65 6532 2872Email: [email protected]: www.abf-asia.com

February

POWER-GEN India & CentralAsia, 1 - 3 February 2005, PragatiMaidan, New Delhi, IndiaDetails from: Seonaid Thomas,PennWell Corporation, WarliesPark House, Horseshoe Hill,Upshire, Essex, EN9 3SR, UKTel: + 44 (0) 1992 656 629

Fax: + 44 (0) 1992 656 704Email:[email protected]: www.powergenindia.com

FLAME 2005, 22 - 25 February 2005, The Rai, Amsterdam, TheNetherlandsDetails From: Luke Raphael, ICBI,8th Floor, 29 Bressenden Place,London, SW1E 5DR, UKTel: + 44 (0) 20 7915 5103 Fax: + 44 (0) 20 7915 5101Email: [email protected]: www.icbi-flame.com /VIP REF NO: KN2097MINT1

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March

NorthWest HydroelectricAssociation 2005, 1 - 2 March2005, LIoyd Center Doubletree,Portland, Oregon, USA

Details From: Jan Lee, ExecutiveDirector, 1201 Court Street, NE Suite303, Salem, Oregon, 97301, USATel: + 1 503 363 0121 Fax: + 1 503 371 4926Email: [email protected]: www.nwhydro.org

Asia Power 2005, 1 - 3 March2005, The Grand Hyatt, SingaporeDetails From: Terrapinn Pte Ltd, 12Prince Edward Road, #03 - 01,Podium A, Bestway Building,Singapore 079212, SingaporeTel: + 65 6322 2701 Fax: + 65 6223 3554 Website: www.terrapinn.com

PEi December 2004 � Reader Reply No 9 �

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n recent years, the wind energy mar-ket has grown from small medium-voltage wind farms connecting to the

distribution network to large high-voltageparks connecting directly to the transmis-sion grid. Areva T&D has already carriedout challenging wind farm connections atmedium and high voltage in Germany,Norway, Australia, India and France,offering grid connection solutions specifi-cally designed to solve wind power quali-ty issues, as well as providing the neces-sary equipment. The Barrow offshorewind farm connection, recently awardedto the company by the Kellogg Brown &Root/Vestas Celtic Wind Technology consortium, is just one of these projects.

Under the g12 million contract, ArevaT&D will design, manufacture and assem-ble the UK's first high-voltage offshoresubstation off the coast of Barrow, in theNorth West of England, and design theentire electrical connection between theoffshore wind farm and the nationalpower grid. The project is important forAreva T&D because the Barrow substa-tion will be one of only a handful of off-shore substations in the world, connecting

one of the first wind farms at the 132 kVlevel in the UK.

The Barrow wind farm, being developedby Barrow Offshore Wind Limited, will belocated 7 km offshore and will have 30wind turbines with a total output capacityof up to 99 MW. The turbines will bealigned in four staggered rows 750 mapart, each composed of seven to eight tur-bines 500 m apart. The turbines will be 75 m high, with a 100 m blade diameter.The maximum distance between the meansea level and the vertical blade will be 125 m.

The offshore wind farm will be intercon-nected by underwater AC cables, whichwill either be buried in the sand or laid onthe seabed. The subsea cables will thenconnect into the high-voltage offshore sub-station, which will be located on a plat-form near the turbines.

Areva T&D's offshore substation willstep up the wind farm's voltage from 33 kV to 132 kV to transmit the electrici-ty onto the transmission grid. The compa-ny will supply fourteen panels of 33 kVWS gas-insulated switchgear manufac-tured in its German factory in Regensburg

and customized by its unit in Stafford, UK.Areva T&D's WS switchgear is insulated

with SF6 gas and has a robust interlockingsystem with an integrated voltage detec-tion system. Areva T&D will also supply a33/132 kV 120 MVA transformer andMicom protection panels from its UK fac-tory in Stafford and a 132 kV gas-insulat-ed B65 disconnector from its factory inSwitzerland. The B65 disconnector has aspring-operated mechanism and will helpprotect the substation equipment.

ImplementationIt will take Areva T&D around six monthsto build the equipment, which will bedesigned to withstand sea salt, rust, windand rain, which can corrode and damagethe substation. The equipment will beinstalled into steel modules which, afterundergoing preliminary tests, will bebrought to the Barrow dockyard wherethey will be installed onto the platform.

Once assembled and following furthertesting, the platform carrying the moduleswill be taken offshore as one system andwill be hoisted onto a monopile founda-tion driven into the seabed. To maintainthe platform's centre of gravity, ArevaT&D engineers are working with KBR'sengineers to study how to position themodules in the allocated space. To helpreduce the size of the platform withoutcompromising the operation of the substa-tion, the equipment will be stacked withminimum space between the modulesmade available for maintenance opera-tions. Areva T&D's Technology Centrewill also model the entire electrical systemto ensure that its performance meets GridCode requirements and will specify theentire electrical connection between theturbines and the transmission grid at theHeysham substation.

Electricity will be transmitted from theoffshore substation via a single 132 kVcollector cable 26 km long. It will beburied in 1 to 3 m of sand via trenching,jetting or ploughing. At the shore, it willconnect to an onshore buried cable, whichwill transport the electricity 3 km to a new132 kV substation to be jointly owned byUnited Utilities and Barrow Offshore

December 2004 PEi20 www.peimagazine.com

The UK's first high-voltage offshore substation connects the Barrow wind farm to the transmission grid, and is alsoan important component in helping manage wind's contribution to the network

Transmission and DistributionPhill Cartwright, Laurent Schmitt and Richard Cooke, Areva T&D, UK

Shipshapesolution for offshore wind

I

Figure 1. Relocatable static var compensators (SVC) are part of Areva T&D’s solution

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Wind Ltd. The new onshore substationwill also be designed and installed byAreva T&D and will have a single circuitconsisting of a fixed connected reactor, cir-cuit breaker, surge arrestors and aMiCOM protection system. Anotherburied 132 kV cable will connect the newsubstation to the Heysham substation,jointly owned by National Grid Transcoand United Utilities, to carry the farm'selectricity onto the transmission network.

Supervisory control of the entire windfarm will be implemented through aSCADA system, enabling the BarrowOffshore Wind teams to monitor thepark's performance via the Internet.

Areva T&D's solutionsThe UK government's objective - to gener-ate 15 per cent of the country's electricityfrom renewable energy sources by 2015 -means Barrow is just one example of thegrowing number of wind farms, plus otherdiverse sources of energy, connecting intothe distribution and transmission grid.This mix in power systems provides tech-nical challenges. Power networks were ini-tially designed for central electricity gener-ation production and not for distributedenergy sources, such as wind farms. Thereal challenge with wind farms however ismanaging their unpredictable energy pro-duction and ensuring that they complywith the new and emerging grid codes.

As distributed energy sources proliferatein a liberalized market, including largewind farms, the risk of disturbing the net-work's stability has increased significantly.Wind may not be available when demandrequirements are high, resulting in energyimbalances, and some utilities may chargepenalties. As a consequence, utilities haveestablished minimum connection require-ments, in terms of system operating con-straints, power quality and supply stabili-ty, that each independent power producermust meet to safeguard the grid and itscustomers. Power imbalances and voltagefluctuations can occur because wind is anintermittent source of energy.

Power quality and balance problemsmay have to be resolved using power elec-tronics technology and energy manage-ment software solutions. The cost ofpower imbalances can be minimized withmore accurate wind predictions, as pro-posed as part of Areva T&D's e-terrawindsoftware package.

Large wind farm control Areva T&D’s e-terrawind offers an end-to-end IT platform covering the reporting ofthe wind farm's real-time critical datafrom both the turbine and the electricalsystem. E-terrawind can also be used for alarge wind farm to improve its voltage andVAR controllability so it reacts (from anetwork perspective) very similarly to con-ventional plants.

In addition, e-terrawind's generationscheduling and optimization tools allownetwork operators to optimize their gener-ation strategies. It also includes a verydetailed dispatcher training simulator uti-lizing wind generation models, which canprecisely assess the effect of the wind farmon network security.

To compensate for wind power's upre-dictability, operators usually combine itwith other generation such as coal orhydro. With higher costs and environmen-tal constraints, the challenge is to achievebetter controllability and energy optimiza-tion to define the most profitable energymix at any instant. In this case, e-ter-rawind extends to the level of an adaptedtrading functionality including integrationof weather-based generation forecast, gen-eration portfolio scheduling and dispatchmonitoring, providing interfaces to thetrading market places and maximizing therevenue opportunities for wind operators.

With large offshore wind farms in theUK, the British Electricity Trading andTransmission Arrangement (BETTA) mar-ket system offers generators various trad-ing opportunities, such as long term con-tracts. In this case e-terrawind is integrat-ed with Areva's e-terramarket electronicmarket place systems and e-terratrade participant trading systems.

Managing intermittency is not the onlychallenge wind farm developers and net-work operators face. Power quality andgrid stability issues also exist, but they canbe avoided. Areva T&D can stimulate thedynamic behavior of the turbines accord-ing to the developer's control strategy andwind speed fluctuations. It can also per-form steady state and dynamic studies ofthe installation, from the wind turbinethrough to the grid connection and

beyond, to provide a cost-effective andtechnically compliant system design thatmeets grid connection requirements.

Power electronics solutionsIn the case of the Barrow farm, an AC con-nection was most applicable and cost-effec-tive, given the short distance from theshore. But for wind farms located far fromthe load centre, high voltage DC (HVDC)can offer many advantages: higher trans-mission capacity, lower losses, precise andrapid control of the power flow and fewerdisturbances during network faults.

For wind farms connected with a tradi-tional AC connection, flexible AC trans-mission (FACTs) solutions such as staticvar compensators (SVC) represent effectivepower quality solutions and ensure thatwind energy contributes to the steady stateand dynamic performance of the AC sys-tem and meets grid connection standardsand requirements. However, as withBarrow, where grid connection is strong,steady-state and dynamic performancestudies may show that a grid-code compli-ant connection can be achieved using thecapabilities of wind turbines coordinatedwith switched reactive elements.

Some wind farms do not ride throughlocal faults. If there is a short circuit faultnear to the wind farm and the fault iscleared, the wind farm may not recover.This depends on the turbine being used. Asolution can be implemented at the turbinelevel. Alternatively, however, a systemsolution can be provided by coordinatedcontrol, protection of the wind turbineand a form of compact dynamic reactivepower support, provided at the substation.Such dynamic reactive power support canbe provided by the modular product, theC-Statcom.

Figure 2. Installed technology helps define the most profitable energy mix at any instant


Transmission and Distribution

PEi

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Forthcoming issues:

PEi Jan '05Featuring:

• Diesel Engine Technology• Emission Control• Supercritical Boiler Technology• Transmission Grid Development• IT- Focus

PEi Feb '05Featuring:

• Refurbishment & Repowering• Transmission Systems• Renewable Energy• IT Focus

Special Russian language publication - Russia Power (Feb 05)

For more information about these issues please contact:

Advertising:Dan NoyauAdvertising DirectorTel: +44 (0) 1992 656 609Fax: +44 (0) 1992 656 700E-mail: [email protected]

Editorial:Nigel BlackabyFeatures EditorTel: +44 (0) 1992 656 607Fax: +44 (0) 1992 656 700E-mail: [email protected]

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any Association of South EastAsian Nations (ASEAN) industriessuch as sugar, palm oil, rice and

wood have been utilising biomass as a fuelto cover some or all of their energyrequirements. Biomass is one of the mostimportant sources of renewable energy inthe region. Despite its wide use already,there is still much to be done to optimisethe utilisation of biomass for cogeneration.

Power demand growth in ASEAN is stillhigh. Favourable government policies andfinancing conditions for cogeneration havestimulated the development of cogenera-tion systems in wood and agro-industries.These systems provide the energy neces-sary for the industrial operation. Excessenergy can also be sold to nearby indus-tries or to the national grid.

Biomass cogeneration Most ASEAN countries are large produc-ers of wood and agricultural productswhich, when processed in industries, canproduce large amounts of residues, varyingbetween 20 and 70 per cent of the rawmaterial input. These residues often have avery low economic value, sometimes evennegative, because of the costs involved indisposing them. Every year, more than 120million tonnes (t) of biomass residues aregenerated in the region, which could beused to fuel high efficiency cogenerationwith a capacity of about 10 GW. Anincreasing trend for biomass related indus-tries is to use cogeneration to satisfy theirenergy demands and to boost profitability.

In the sugar industry, bagasse is thefibrous residue produced after the extrac-tion of juice from sugarcane. It has tradi-tionally been used as a fuel to producepower and steam for internal consumptionin the mills. In ASEAN, cogeneration inmost sugar mills today is still limited tooutdated equipment using conventionalsteam thermal technology based on oldcogeneration plants. The equipment com-prises basic conventional low pressureboilers with spreader stokers operating at20-25 bar and back pressure turbines.Modern installations are operated at 40bar and above using extraction-condens-ing turbo-generators. They can produce up

to three times the amount of power gener-ated by conventional systems. Excesspower is then exported to the grid.

In the palm industry, as much as 70 percent of the fresh fruit bunches (FFBs) areturned into waste in the form of emptyfruit bunches (EFBs), fibres and shells, aswell as liquid effluent. Fibres and shells aretraditionally used as fuels to generatepower and steam. Effluents are sometimes

converted into biogas that can be used ingas fired gensets.

Like sugar mills, palm oil mills have tra-ditionally been designed to cover theirown energy needs (process heat and elec-tricity) by utilising low pressure boilersand back pressure turbo-generators. Heatand power demand in the palm oil indus-try is generally met by operating low-pres-sure horizontal fixed-grate three-pass boil-ers of a simple design producing saturatedsteam at 15-20 bar.

More efficient energy conversion tech-

nologies that utilise all solid palm oilresidues, including EFBs, are currentlyavailable and are being implemented.Thus, palm oil factories have the potentialto generate large amounts of electricityusing their own residues. Extra power canbe exported to the national grids.

Rice mills produce a large amount ofrice-husk as solid residue (around 20 percent of paddy input), which can also be

used as a fuel in a cogeneration plant. Incontrast with the sugar and palm oil mills,there are very few installations of cogener-ation systems in rice mills in ASEAN. Asrice is the staple food and as it is a widelyexported agricultural commodity in thisregion, cogeneration systems with mediumpressure boilers (over 30 bar) and efficientextraction condensing turbines seem tomeet the challenges posed by rice husk dis-posal. The sale of ash produced during thecombustion of rice-husk can yield revenuesof over $100 per tonne of prime quality


Biomass residues are in plentiful supply across most of the ASEAN region and its use in small scale power gener-ation is established. The European Commission-backed ASEAN COGEN 3 Programme is spearheading biomasscogeneration, showing how modern cogeneration systems can achieve big efficiency and fuel utilization savings.

CogenerationLudovic Lacrosse & Sanjeeb Kumar Shakya, EC-ASEAN COGEN Programme Phase III, Thailand

“Favourable government policies and financing conditions

for cogeneration have stimulated the development of small as well as

large cogeneration systems in wood and agro-industries”

ASEAN ripe forCogen

M

Figure 1. The 41 MW Dan Chang Bio Energy Project in Thailand

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amorphous silica ash, which adds to theprofitability of such systems.

The EC-ASEAN COGEN Programmehas been supporting the implementation ofproven, clean and efficient biomass cogen-eration projects. New technologies fromEurope have been introduced in theASEAN rice, sugar, palm oil and wood sec-tors. Some biogas plants have also beenimplemented in other sectors.

Dan Chang Bio-Energy An example of one of these is the DanChang Bio-Energy project, implementedby the Mitr Phol Sugar Group, Thailand.The Mitr Phol Sugar Group has been inthe sugar business for more that 45 years.In 2004, the total cane crushing capacityof the group stands at 109 000 t per day. Itgenerates a total of 32 000 t of bagassewhich is the major by-product of the sug-arcane crushing.

Their new 41 MW bagasse fired cogen-eration project is designed not only to pro-vide the steam and electricity requirementsof the sugar mill but also to produce 24 MW of excess electricity to be export-ed to the national grid through a firm con-tract of 21 years. The project consists of a41 MW extraction condensing steamturbo-generator and two vibrating grateboilers with an hourly capacity of 120 t ofsteam at 68 bar and 510

oC each.

The total investment cost for the projectis around g35.5 million, excluding civilworks and building foundation. Theexpected payback period is five years aftercommissioning. The major revenue for theproject is coming from the sales of excesselectricity to the national grid. The projectwill also earn revenue selling steam andelectricity to the sugar mill. As the genera-tion is located near the mill, there is mini-mal transmission and distribution cost andelectricity loss. The total greenhouse gas(GHG) mitigation by implementing this

bagasse fired project is expected around278 610 t of CO2 equivalent per year.

TSH Bio-Energy Another EC-ASEAN COGEN supportedproject is TSH Bio-Energy, a subsidiary ofTSH Resources Bhd, a Malaysian compa-ny involved in oil palm plantation, palmoil milling, timber products and powergeneration.

The new cogeneration plant is usingempty fruit branches as fuel. It is located atKunak, Sabah, East Malaysia. The totalcapacity of the project is 14 MWe with atotal live steam capacity of 80 t per hour at66.5 bar and 402ºC. Around 10 MWe willbe exported to the local grid, while 25 t ofsteam will be used for palm oil processing.

The plant consists of a fuel conveying

system; a water-cooled inclined vibratingmembrane grate; a water-tube steam boil-er with a capacity of 80 t per hour, 66.5 bar; an automatic de-ashing system; amulti valve steam turbine, with inlet pres-sure at 50 bar; and a turbo-alternator withrated output of 17 500 kVA.

The total investment cost of the projectis around g9.0 million, excluding civilworks and building foundation. Theexpected payback period is four years aftercommissioning.

The energy use of palm oil residues con-stitutes an elegant way to dispose of theprocessing residues from palm oil millingactivities, while generating additionalincome. It is estimated that between 40 000 and 50 000 t of CO2 equivalentwill be mitigated annually thanks to theuse of the EFBs.

Chia Meng Rice Mill Chia Meng is an example of a cogenera-tion project in the rice industry.

The Chia Meng Rice Mill is located inNakhon Ratchasima province. Chia Mengis one of the biggest rice mills in Thailand,with a milling capacity of 700 t of paddyper day. It has implemented a 2.5 MWcogeneration plant which utilises rice huskas a fuel.

The plant was commissioned in March1997. The rice mill produces about 140 tof rice husk per day to fuel the plant.

The plant consists of a rice husk silo; aconveying and automatic boiler feedingsystem; a step grate/boiler producing 17 tof superheated steam at 35 bar andequipped with automatic ash removal sys-tem; a 2.5 MW multi-stage fully condens-

ing turbo-generator; and heat exchangersusing boiler flue gas and/or superheatedsteam to generate hot water for paddy dry-ers.

The project involved an investment ofg3.6 million, excluding civil works andbuilding structures. The major revenuescome from savings in fuel oil, electricitypurchase and rice husk disposal.

An additional income comes from ashsales. The payback time of this project was3.6 years after implementation of theplant. Total GHG avoided by implement-ing this rice husk boiler is around 7000 t ofCO2 equivalent per year.

Biocogen benefitsMany countries in ASEAN are implement-ing biomass cogeneration plants, as bio-mass is abundantly available in the region.As a fuel, it is relatively cheap, clean andenvironmentally friendly.

Biomass residues can help meet theincreasing demand for power in develop-ing countries. When used in modern medi-um to high pressure cogeneration systems,big improvements in efficiency and fuelutilisation are realised.

Industry leaders see cogeneration as oneof the means to reduce costs in order toincrease their competitiveness. In addition,they are able to sell excess power to thegrid and solve their waste managementproblems.

From an economic point of view, the useof biomass offers many benefits, such asreducing dependence on imported fuelresources and increasing local economicsustainability. It generates high environ-mental benefits through the mitigation ofGHG emissions and a substantial reduc-tion of SOx and NOx emissions, whencompared to the use of fossil fuels.

Cogeneration

“Industry leaders see cogeneration as one of the means

to reduce costs in order to increase their competitiveness, while

selling excess power to the grid”

Figure 2. The Chia Meng Rice Mill in Thailand includes a 2.5 MW cogeneration plantPEi

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ontrol of sulphur trioxide (SO3) emis-sions from coal fired power plantshas recently been the subject of atten-

tion from utility management, the publicliving near the plants, and environmentalregulators. What once was an aggravatingproblem of sulphuric acid corrosion ofducts and electrostatic precipitators (ESP)has become a problem of visible plumes,plume touchdowns, increased operatingcosts, and increased scrutiny from regula-tors and the public. Ironically the maincause of the recent attention has been theadvent of selective catalytic reduction(SCR) for control of nitrogen oxides(NOx). These SCR units actually reduce theamount of air pollution coming from theplants. However, they also increase SO3concentrations in flue gas enough to makesignificant changes in the sulphuric aciddew point and in the visible plume.

When burned, about one per cent of thesulphur in coal is oxidized in the boiler toform SO3. The installation of SCR unitsfor NOx control can more than double theamount of SO3 in the flue gas by oxidationof sulphur dioxide (SO2) across SCR cata-lysts. When the flue gas is subsequentlycooled, the SO3 in the gas is converted tosulphuric acid. This sulphuric acid cancondense in air heaters, in ducts and ESPs,and it can become a very fine mist oraerosol in the plume from the stack.Depending on atmospheric conditions, thevisible plume appears as a blue-white haze,or a brown cloud carried for miles down-wind. At elevated SO3 concentrations,plume buoyancy can be influenced to theextent that touchdowns of the plume inthe vicinity of the plant have occurred atseveral plants upon startup of the SCRunits, leading to public outcry and someregulatory concerns.

SBS injection technologyControl of SO3 emissions can be achievedby contacting the flue gas with a clearsolution of sodium bisulphite and/or sodium sulphite (SBS solution). The technology is patented by CodanDevelopment LLC and is offered, in conjunction with URS Corporation,Codan's engineering partner.

Ideally the clear SBS solution is injectedinto the duct before the flue gas is cooledbelow the acid dew point for sulphuricacid. The sprayed solution dries upon con-tact with the hot flue gas and forms mil-lions of small alkaline particles that reactwith the SO3 in the flue gas according tothe following chemical reactions:

NaHSO3 + SO3 � NaHSO4 + SO2 (1)(Sodium bisulphite) (Sodium bisulphate)

Na2SO3 + 2 SO3 + H2O � 2NaHSO4 + SO2 (2)(Sodium sulphite)

When the sodium to SO3 molar additionratio exceeds 1.0, the reactions become:

2NaHSO3 + SO3 � Na2SO4 + 2SO2 + H2O (3)(Sodium sulphate)

Na2SO3 + SO3 � Na2SO4 + SO2(4)

Alternately, Codan has developed andpatented a process known as In-Situ SBSInjection. In this process, a clear solutionof a variety of sodium-based reagents (car-bonate, bicarbonate or hydroxide) isinjected into the duct where it is convertedto sodium sulphite or bisulphite by reac-tion with SO2 in the flue gas. Then thesame chemical reactions listed above occurto replace SO2 in the SBS particles withSO3 absorbed from the flue gas. The endresult is the removal of SO3 and the for-mation of particles of sodium sulphate andsodium bisulphate, which are thenremoved with the fly ash.

In all cases, the alkali used for SO3

control is not consumed by reacting withSO2. Since SO2 is not absorbed, very lowmolar ratios of active sodium to SO3, typ-ically 1.3 to 2.5, can produce the desiredSO3 removal results. Other chemicals suchas lime, limestone and magnesium hydrox-ide must be used at very high molar ratios,since SO2 in the flue gas consumes most ofthe alkali.

Figure one indicates the various poten-tial locations for injecting the SBS solu-tion. Since a solution is being injected, itis necessary to have a three to eight metresection of duct downstream of the injec-tion point and free of obstructions, toallow adequate drying time before thesolids contact any surfaces to preventsolids deposition. The duct work andobjectives at each plant must be evaluat-ed to select the most desired injectionlocation.

Figure two is a simplified illustration ofthe equipment required for the SBSInjection technology. The heart of the sys-tem is the injection grid itself. SBS reagentsolution is injected into the flue gasthrough a series of lances with a number ofdual-fluid nozzles on each lance. Each noz-zle is supplied with both SBS solution andcompressed air. The lance itself is cooledby an internal flow of ambient air that isforced into the lance shroud by the differ-ential pressure between the duct and theshield air supply.

Process developmentAfter initial pilot testing of the SBS injec-tion process on simulated flue gas in 2000and 2001, a 265 MW demonstration test


Sulphur trioxide emissions have been the subject of increasing attention from a spectrum of observers, but a newinjection technology is working to help wipe plumes from the sky.

Emission ControlJames H. Wilhelm��Codan Development LLC, USA

SBS Injectionfights off SO3

C

PreferredLocation

Boiler

SCRAir

PreheaterESP (BH)

I.D. FanFGD Stack

Possible Alternate Locations

Figure 1. The optimum SBS injection point is dependent on many parameters, which differ from plant to plant

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was conducted at the AB Brown stationUnit 2 of Vectren Corporation, Indiana,USA. The Electric Power ResearchInstitute (EPRI) studied the process in twophases between August and December2002. URS Corporation directed allaspects of process application, includingnozzle and lance development.

Three additional full-scale demonstra-tion programmes were conducted in 2002,at 400 MW, 430 MW, and 750 MWscales, leading to the first commercial systems starting up in 2003.

The first permanent SBS Injection systemwas installed at the Bruce Mansfield plantof FirstEnergy, which began operation atUnit 1 in March 2003. A total of eight full-scale systems (totaling 5300 MW) are nowoperational, and several additional full-scale systems (totaling 4000 MW) arebeing planned for installation in 2005.Some of the SBS Injection systems areinstalled ahead of the air heater, while oth-ers are installed between the air heater andthe ESP. The injection point is selectedbased on evaluation of many parameters,including duct configuration, residencetime ahead of major obstacles and majorequipment, balance of plant impacts, costof reagent and objectives for additionalprocess benefits at the plant.

Costs and performance Capital costs for the technology areinversely related to unit size, and haveranged from $4 to $10 per kW. Operatingcosts are highly dependent on the level ofSO3 in the flue gas, the SO3 removalrequired, and the reagent contract.Although site specific, operating costs inthe US are estimated to fall between $250to $600 per ton of SO3 removed.

Data from full-scale demonstration testsand many of the permanent installationsshow that over 90 per cent removal effi-ciency can be achieved at molar ratios of1.0 and above, and removal efficienciesabove 95 per cent are possible at higher

reagent ratios (Figure three). Full-scaleinstallations have generally achieved reli-able, consistent operation at molar ratiosof sodium to SO3 of about 1.3 to 2.5,depending on site-specific considerations.

The reagent cost is by far the largestcomponent of the annual operating costfor the SBS Injection technology.Commercial products are available forreagent (sodium bisulphite solution, sodi-um sulphite solution, and sodium sulphitesolids), but are relatively expensive com-pared to the use of a flue gas desulphurisa-tion (FGD) byproduct solution. Since theproduct of the scrubbing of SO2 withcaustic or sodium carbonate is a solutionof sodium sulphite and bisulphite, a lowcost reagent for the SBS Injection processcan be made at any plant site willing toinstall and operate a scrubber for the pur-pose of producing their own reagent forSBS Injection. Alternatively, the In-SituSBS process using soda ash or caustic can

be considered. If a utility elects to produceits own SBS reagent or use the In-Situ SBSprocess, the reagent cost could be reducedby 30 to 70 per cent.

The effective removal of SO3 from theflue gas can provide valuable operationand maintenance (O&M) benefits, in addi-tion to the highly desirable environmentalbenefit of eliminating the plume opacityaspects of sulphuric acid aerosol emis-sions. Removal of 90 to 95 per cent of theSO3 will reduce the acid dew point of theflue gas by somewhere between 4˚C and16˚C (depending on the pre-injection SO3level), thereby providing significant pro-tection against acid corrosion for allequipment and ductwork downstream ofthe injection point. This lower acid dewpoint allows for flexibility in the tempera-ture of operation of the air heater, and insome cases can result in substantial savingsby improving heat rate.

Promising technologySBS Injection technology is promising foreffectively and selectively removing SO3from flue gas. The technology is currentlybeing applied at eight power plants total-ing approximately 5300 MW, and is beingconsidered for a number of additionalapplications in the US utility sector.Demonstrations are planned for SO3 miti-gation applications for a utility oil firedboiler and a petrochemical industry flu-idized catalytic cracker unit (FCCU). Thecapability to effectively remove SO3 hasbeen consistently demonstrated. As thecommercial applications accumulate oper-ating experience, it will be possible to bet-ter document long-tem reliability, mainte-nance and operating costs as well as thepotential for other plant benefits likereduced corrosion and improved heatrecovery.

Emission Control

PEi

Injection Lance

Shield AirBlower

(optional)

SBSStorageTank

Treated WaterSpray Nozzle

FlueGasDuct

Flow

Injection AirCompressor(or plant air)

Equipment List

• SBS Storage Tank and Dilution/Feed Tank

• SBS Transfer Pump

• Injection Lances (shields)

• Dual-Fluid Injection Nozzles

• Injection Air Compressor (or plant air)

• Dilution Water Treatment

• Shield Air Blower (optional)

• Piping, Valves, Insulation, Heat Tracing

• Electrical and Controls

Figure 2. SBS reagent solution is injected into the flue gas through a series of lances

00

10

20

30

40

50

60

70

80

90

100

0.5 1 1.5 2 2.5

SO3

Rem

oval

Per

cent

age

Na: SO3 Molar Injection Ratio (Mole Na/Mole SO3)

Full-Scale SO3 Removal Results

Figure 3. Removal efficiency of 90 per cent can be achieved at molar rates of 1.0 and above

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oday many distribution networkoperators (DNOs) find themselvesstruggling to power a 21st century

world using the technologies and manage-ment concepts of the 20th century. Underpressure from ageing assets, growing peakdemand, the emergence of new power gen-eration technologies and revenue con-straints from regulation and theft, DNOsare seeking a new, smarter approach tooperating their networks.

Ageing assets are a major concern. Inmuch of the electrified world, grids werebuilt in the 1950s, 1960s and 1970s. Now,many of the assets critical to running thesenetworks are approaching the end of their

planned lives. Yet capital spending atDNOs has failed to keep pace withstraightforward annualized renewal forthese assets. In Great Britain, for example,the annual network renewal investment ofthe typical distribution company is lessthan one percent of its asset base. Thisamounts to a renewal cycle of more than100 years - well beyond the design life ofnetwork assets.

Traditional responseAs a result, DNOs face billions of dollarsin backlogged investment. The obvioussolution is heavy spending. But for the vastmajority of distribution companies, andregulatory and political counterparts,immediately doubling or tripling capitalexpenditures is not a realistic strategy.What is worse, operating assets beyondtheir design limits represents a growingthreat to network reliability and safety.

Distributors must increase the capacityof their networks to keep up with peakdemand that is growing in almost everyelectricity market. If left unaddressed,growing demand can lead to blackouts attimes when electricity is needed most.

Meanwhile, the makeup of the networkitself is changing to favour small-scalepower generation connected to the distrib-ution system. This change is being driven

by technologies like solar, wind and fuelcell, and a growth in onsite small-scale, gasfired generators. Small power sources arebeing embedded in grids originallydesigned for large, centralized powerplants. This threatens to wreak havoc withdistribution networks, which are not builtto handle the complex power flows thatcome with distributed generation, such assudden reverse flows when generators aredisconnected.

Revenue threatThe ability of distributors to meet thesechallenges is under threat from anothersource: revenue pressures from regulation

and theft are constraining investment innew infrastructure. Generally, regulatorsare reluctant to authorize investment indistribution assets. They have an obliga-tion to protect the interests of customersby ensuring supply, but they also seek toavoid the political ramifications of ratehikes. This gives officials an acutecost/benefit sensitivity. DNOs need tomake compelling arguments that renewingthe network is money well invested.

Revenue lost to theft is another con-straint. Electricity theft is an importantissue affecting distribution company

balance sheets. India, DominicanRepublic, Burma and Bangladesh top thelist by percentage of off-meter consump-tion, but theft in established markets is nosmall problem. In 2002, UK power theftwas estimated at $72.2-$541.7 million andin 1998 in the US at $1.6-$10.9 billion.

Tough choicesTogether, these pressures are forcingDNOs to make difficult choices. Theyhave three options.

The first is to do nothing and hope forthe best. By avoiding investment in net-work upgrades, distributors can keep costslow in the short term. But operating capi-tal-intensive network components beyondtheir design life means eventually some-thing will fail, with unforeseeable results.

The second, more traditional, option isto invest in an over-engineered network.Historically, technological constraintshave forced network designers to planaround worst-case scenarios. Thisapproach - prudence based on sparseinformation - requires DNOs to buildcomponents larger than needed andreplace them earlier than necessary. Over-engineered networks operate with a highdegree of fault tolerance, but always erringtoward caution is an expensive strategy.

The third option is to make the networksmarter. As sensor technologies decline inprice and the industry develops advancednetwork analytics, realtime monitoring


As increasing demand pushes ageing grids to the breaking point, new technology capabilities are making it possible for electricity distribution companies to make informed decisions about asset replacement, upgrades,network security and regulatory approvals for investment.

IT FOCUSJeanette Carlsson, Alistair Green and Colin Sawyer, IBM, UK

“Ageing assets are a major concern. In much of the electrified

world, modern grids were built in the 1950s, 1960s and 1970s”

Building the intelligent electricity network

T

Figure 1. Around the globe, network infrastructure is ageing

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www.peimagazine.com 33PEi December 2004

and reconfiguration of the network is agrowing possibility for DNOs. Building anintelligent electricity network allows themto escape from the dilemma of risking cat-astrophe or spending beyond their means.

Intelligent electricity networkDNOs can begin building an intelligentnetwork by adopting advanced networkanalytics supported by intelligent networkenablers.

Sensors and smart meters continuouslymonitor the status of the network, anddistribution companies can store the datathey provide in a data warehouse. Thenadvanced network analytics can be appliedto boost operational efficiency. Analyticscan ‘mine’ sensor and meter data to sup-port key strategic imperatives, targetinvestment at components that are aboutto fail or are running near full capacity,enable realtime reconfiguration in theevent of a blackout, optimize the configu-ration of the network and satisfy regula-tors that prudent investment decisions arebeing made.

Advanced network analytics focus onasset life, network design and networkoperation.

Asset life analytics focus on when com-ponents should be replaced and how tonurse them when they begin to fail.Because similar assets fail in similar ways,they can be analyzed based on historicusage patterns. When augmented withrealtime sensor data, life span analysis canyield more accurate life span predictions ofindividual assets. As assets begin to fail,detailed analytics can suggest how toadjust the network to protect the asset andprevent sudden or catastrophic faults.

Network design optimization can alsolower the cost of operating networks andhelp reduce capital expenditure. Withoutfine-grained information, DNOs respondto growing demand by upgrading the net-work across the board, as if every cus-tomer is the hypothetical ‘biggest con-sumer.’ Analysing individual customerload patterns can help determine whetherand where upgrades are really needed.

Detailed analysis of load patterns alsolets DNOs balance the load on each phase,reducing losses on the network. By incor-porating the results of asset life analytics,maintenance planning can be optimized.

Network operations analytics focus onpower flows within the network, helpingto improve reliability and reduce or defercapital expenditures. With realtime moni-toring of contingent fault currents, opera-tors can trigger network splitting andswitching to keep fault currents from over-loading critical components, defer upgrad-ing switchgear to handle fault overloadcurrents and cordon off exclusion zonesaround areas where even a low probabili-ty of a hazardous fault arises. Data fromsmart meters allow engineers to be

dispatched to fault zones with the rightequipment. Realtime control of powerflows also enables networks to handle distributed generation.

Four technology enablersThe intelligent network is supported byfour technology enablers: automatedmeter management; remote asset manage-ment and control; mobile workforcemanagement; and IP-enabled SCADA.

Smart meters in homes and businessesenable time-of-use pricing, which incen-tivizes customers to use less energy duringpeak hours. US studies suggest demandreductions of up to 5.2 per cent for mod-erate time-of-use changes in pricing. In1998, Gulf Power of Florida launched aprogramme, dubbed “Good Cents”, thatcut consumption by nearly 45 per centduring peak hours. Time-of-use pricing isalso popular with regulators, as it miti-gates peak demand growth and allowsDNOs to defer network upgrades, keepingprices stable.

Smart meters placed on the network canalso help DNOs locate areas where powertheft is occurring. For example, if a meterat a low voltage substation indicates thattoo much power is being drawn, theft maybe occurring in the immediate vicinity.

The second enabler, remote asset moni-toring and control, can extend the life ofcritical network infrastructure andimprove customer service through faultanticipation.

First, remote sensors can detect whetherevents on the network are consistent withthe network's capacity and warn operatorswhen a component begins to operate out-side optimum ranges. By monitoringwhether power flows are within optimumrange, operators can load componentshigher than otherwise possible.

Second, sensors can detect when parts ofthe network begin to fail. Based on the

feedback from these sensors, the controlcentre can adjust network configurationsto reduce the load on compromised assetsand warn field engineers when deteriora-tion creates a probability that an asset willbe unsafe.

Sensors on transmission wires can warnwhen foliage grows too close to powerlines. The location data of such anticipat-ed faults can be used to dispatch crews toaffected points. Similarly, smart end-usermeters can boost service levels by remote-ly identifying where on the network a fail-ure has occurred and providing diagnosticdata to speed repair times.

The third enabler, mobile workforcemanagement, boosts the speed and accura-cy of maintenance and repairs by electron-ically streamlining the flow of data fromsensors through the central control centreto PDA-equipped field crews. If assets areoperating beyond tolerances, or if a faultposes a danger, network operators canissue rapid, detailed repair instructions orwarnings to stay clear of danger zones.

The fourth enabler, IP-enabled SCADA,can cut telecommunications costs by 20per cent or more and offers a robust, fault-tolerant architecture that scales easily tosupport the deployment of sensors, smartmeters and remote PDAs across the net-work, often in numbers that would stretchexisting telecommunications well beyondpractical limits.

IP-enabled SCADA replaces proprietarySCADA systems with standard Internetcommunications protocol. This releasesutilities from relying on proprietary com-munications protocols and offers the high-er fault tolerance of a packet-based net-work. The Internet technology that under-pins IP-enabled SCADA can also provide acommunications platform for possiblefuture services, like smart home appliancesthat can be operated remotely via a webbrowser console.

IT FOCUS

Figure 2. Advanced network analytics

PEi

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EquipmentRoundup

StandardpublishedThe International ElectrotechnicalCommission (IEC) has published itsfirst fuel cell standard.

IEC 62282-2: Fuel cell technologies- Part 2: Fuel cell modules covers thesafety and performance of five typesof fuel cell modules: alkaline, protonexchange membrane, phosphoricacid, molten carbonate and solidoxide.

The standard covers minimumsafety requirements for modules, andwill be used by manufacturers in pro-ducing fuel cells for use by con-sumers. It was prepared by the IEC'sTechnical Committee on Fuel CellTechnologies (designated TC105).

The IEC’s future standards in thisfield are to focus on spelling out addi-tional and specific requirements asthey relate to the setting in which fuelcells will be used, such as in vehicles,on ships, in homes and factories, or onaircraft.

Reader Reply Number 101

Berlin’s bi-fuel cellMTU CFC Solutions, part ofDaimlerChrysler, has installed a bi-fuel fuel cell at a “fuel cell innovationpark“in Vattenfall, Berlin.

Known as HotModule, the fuel cell isbeing tested in operation as part of aprogramme of field trials. Its 350 cellstogether generate some 270 kW, at anoverall electrical efficiency of 56 percent. The unit can be operated fuelledby natural gas, methanol or both; theliquid fuel used is derived from wastesgenerated in the city and MTU notedthat in future alternative fuels couldinclude gas from sewage waste orindustrial residues.

The HotModule is the result of morethan 10 years development work,which has already seen twelve trialfuel cells installed. MTU said it expect-ed more trial systems to be installedduring 2005, and added that seriesproduction of the cell was 'imminent',with a target date of 2006.


CFCL widens fuel feedstock optionsAustralia-based Ceramic Fuel Cells(CFCL) has announced preliminaryfindings that its fuel cell offering canbe operated using ethanol fuel.

The company said it had carried outa preliminary feasibility study andmodeling that had shown ethanolcould be made into a fuel mix suitablefor CFCL's fuel cell product. It saidthe energy efficiency would be up to

50 per cent, similar to that of a fuelcell using natural gas.

The finding means that fuel for thecells could be produced by fermentingplant material such as wheat chaffand corn plants. Most ethanol world-wide is currently produced from sugaror starch.


China’s fuel cell UPSMGE China is to join with its US-basedparent, MGE, and Ballard PowerSystems, to offer fuel cell uninterrupt-ible power systems (UPSs) in China.

The UPS is powered by BallardPower Systems' Nexa RM Series fuelcell modules, which have been inte-grated into MGE's 3 kVA DX rack-mount UPS system, fitting standard 19in rack mounting.

The fuel cells are fuelled using

hydrogen, which is supplied inreplaceable cylinders, and continue tooperate as long as hydrogen is sup-plied. MGE China said the applicationwould be suited for telecommunica-tions markets where runtime andweight limitations made batteriesunsuitable for backup periods aboveone hour.



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EquipmentRoundup

Bespoke insulation design and re-balancing were part of the packagewhen UK-based Wyko overhauled nine30MW turbo rotors at a UK site.

According to Wyko, the companywas asked to assess if repairs wouldbe economic for one of the rotors.Investigations revealed that the rotorshad not been designed for the site anddid not have sufficient insulation.

The new design included improvedslot insulation, manufactured atWyko's Newcastle upon Tyne work-shop, and a new inter-turn design to

improve thermal, mechanical andinsulation characteristics. In additionthe rotors, each weighing 15 t, had tobe rebuilt, to replace worn insulation,and rebalanced.

Overhauling the 15 t units involvedcomplete disassembly, annealing,cleaning, non-destructive testing andcondition reporting on every elementof the coils. Electrical tests were car-ried out to ensure integrity of the rotorlaminations.


VA Tech Hydro has announced thecommissioning of two Ecobulb smallhydro units, the first to be rated at 1 MW, at a site in Paullo, Italy. The twounits were built for STE Energy.

The Ecobulb unit uses a bulb tur-bine and direct-driven generator toproduce high-efficiency hydropower.Permanent magnet excitation of thegenerator rotor permits generator sizeto be reduced, allowing capital costsavings to be made and efficencyincreased. An industrial prototype hasbeen in operation at Aubas in Francefor 18 months, however the Paullounits were scaled up to have a runnerdiameter of 2600 mm and nominalspeed of 150 rpm.

Further units with outputs of up to 4 MW are now under construction inFrance and Canada.


An innovative heat transfer technologyunder development has received atwo-year $750 000 research grantfrom the US Department of Energy'sNational Energy TechnologyLaboratory.

SPX Corporation's CoolingTechnologies and Services business,in partnership with CeramicComposites Inc, will explore the use ofhigh thermal conductivity carbonfoam in air-cooled steam condensersfor power plant cooling. The compa-nies say the system could help mini-mize or eliminate organism intake,warm water discharge, wet or hybridtower evaporation, pumping systemmaintenance, and internal power con-sumption. It may also help meet newClean Water Act legislation, whichrequires power plants to preventadverse environmental effects onaquatic organisms.

The grant was seen by SPX as agreat chance to examine how thetechnology could benefit the powerindustry and the environment.


A turn for the better Small hydrodesigngrows up

Cool stuff

Company Page

ADVERTISEMENT INDEX

A Ametek Power Instruments ......................19

Ansaldo Caldaie SpA................................14

Argillon GmbH..........................................29

B Balcke Durr GmbH ....................................6

Bechtel Co. ................................................2

C Cummins Power Generation ......................8

D Doosan Heavy Industries &

Construction Co., Ltd ..............................10

E E-World of Energy & Water GmbH............35

F Filtro SA ..................................................23

G GE Energy................................................34

GE Energy................................................12

H Honeywell Process Solutions ................OBC

Hytorc......................................................23

I Invensys SimSci-Esscor ..........................21

K Korea Electric Manufactures Association..31

P PennEnergy (OGJ Equipment Exchange) ..36

Proton Energy Systems..............................4

S SKF Reliability Systems ..........................IFC

T Tenaris, Inc. ............................................25

W Westfalia Separator AG ............................17

WETEX ..................................................IBC

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