Power Plants Around the World

Waneta Expansion Generating Station, BC, Canada

In Oct 2010, Waneta Expansion LP began construction on a new hydropower project immediately downstream of the Waneta Dam on the Pend d’Oreille River near Trail, British Columbia. At the time, the genco was a JV of Fortis Inc, Columbia Power Corp, and Columbia Basin Trust. The expansion project shares the existing hydraulic head of the ~ 370 MW Waneta dam owned by Teck Resouces and BC Hydro. Construction included two new parallel power tunnels, the surface powerhouse, and a new 10 km long, 230kV transmission line to BC Hydro’s Selkirk Substation. Work on the Waneta Expansion started in Oct 2010 and about 1,400 people were employed overall in the design, manufacturing, construction and commissioning work. The EPC contractor was SNC Lavalin Inc-ASL JV and Voith Hydro supplied two 167.5-MW Francis turbines along with generators, governors, exciters and various additional auxiliary systems. The HPP was synchronized on 12 Jun 2015, about 6wks ahead of schedule. The official opening was on 22 Jul 2015. The Waneta Expansion capex was CAD 900mn and electricity is sold to BC Hydro and FortisBC under a 40yr PPA. In Jan 2019, Columbia Power and Columbia Basin Trust announced that they had agreed to purchase Fortis Inc’s 51% interest in the Waneta Expansion PS and the purchase was concluded in Apr 2019.

Photo: Columbia Power

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Patuha Geothermal Plant, West Java, Indonesia

In 1997, U.S. developer CalEnergy, at the time an affiliate of the large American construction company Peter Kiewit, closed finance on an 80-MW geothermal power plant at Patuha in Indonesia’s Bandung Regency, West Java, but the Patuha Power Ltd project never started active construction. In 2002, PT Geo Dipa Energi was established as a JV of state-owned energy company PT Pertamina and the national power company PT PLN to manage Indonesia’s Dieng and Patuha geothermal fields. In Aug 2010, the Indonesian government transferred all the Pertamina shares to itself. In Dec 2011, PT Geo Dipa awarded EPC and equipment contracts for a single, 60-MW set at the revived Patuha project to a consortium of EPC contractor Maurbeni Corp and equipment supplier Toshiba Corp, which supplied the single-flash STG. The GPP has a 23ha site in Sugihmukti Village, Pasir Jambu District, 40km southeast of Bandung City. In May 2012, PLN officials and other interested parties gathered for a groundbreaking ceremony for Patuha, by then part of the country’s FTP-2 fast-track capacity program. The plant was then expected to complete in early 2014 with an estimated capex of USD 52.6mn for around a dozen production and reinjection wells and steam production facilities and USD 91.5mn for the power station and steam piping system. In Sep 2009, PT Bank Negara Indonesia made a USD 103mn loan to PT Geo Dipa for the project and Pathua Unit-1 went online in Sep 2014. In 2015 and 2020, the government made further investments in PT Geo Dipa Energi and is now the largest shareholder with a 94.5% stake, leaving PLN with a 4.5% shareholding. Pathua’s 2022 production was 445 GWh and electricity is sold into PLN’s JAMALI (Java, Madura, Bali) 150kV network at USD 0.0682/kWh. In Aug 2022, Toshiba Energy Systems & Solutions Corp signed a contract with PT Geo Dipa to deploy IoT and AI technologies to improve the Patuha plant utilization rate. This service uses predictive failure diagnosis and performance monitoring and is Toshiba’s first commercial application of IoT services for geothermal power plants. In Jan 2024, PT Geo Dipa tendered for the EPC work for a a long-planned second unit at the site.

Photo: Toshiba Corp

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Sur Combined-Cycle Power Plant, Ash Sharqiya South Governorate, Oman

In Sept 2010, Oman Power and Water Procurement Co (OPWP) began the tender process for a 2-GW, gas-fired IPP at the Sur Industrial Estate in the historic coastal town of Sur, approximately 175km southeast from Muscat on the Gulf of Oman. In Jul 2011, Phoenix Power Company SAOC was formed to build the CCGT project by investors Marubeni Corp (50%), Chubu Electric Power Co (30%), Qatar Electricity and Water Co (15%), and Multitech LLC of Oman’s Suhail Bahwan Group (5%). OPWP signed a 15yr PPA with Phoenix Power, which also has a 15yr natural gas purchase agreement with the Ministry of Energy and Minerals. Gas comes from central Oman gas fields and is carried through a 48in pipeline operated by Petroleum Development Oman (PDO). Financial close for the power project was in Nov 2011. In total, the Sur project cost USD 1,650mn and required about USD 1,244mn of debt financing. Of this, about USD 700mn was provided by Japan Bank for International Cooperation (JBIC), and about USD 550mn came from commercial banks including Bank of Tokyo-Mitsubishi UFJ Ltd, KfW IPEX-Bank GmbH, Mizuho Corporate Bank Ltd, Standard Chartered Bank, Sumitomo Mitsui Banking Corp, and Sumitomo Trust and Banking Co Ltd. A tranche was covered by export credit insurance from Nippon Export and Investment Insurance. Siemens supplied SGT5-4000F, dual-fuel gas turbines for two 800-MW 2+1 CCGT blocks and one 400-MW 1+1 block. South Korea’s Sedae Enertech built the HRSGs to Nooter Eriksen design and Fuji Electric built the STGs. In Sep 2011, Daewoo E&C signed the EPC contract and, in April 2012, Mott Macdonald was appointed owner’s engineer. Sur went commercial on 11 Dec 2014 and was officially inaugurated in April 2015 by HH Sayyid Hamad bin Thuwaini bin Shihab Al Said. At completion, this was both the largest IPP and the largest power station in the Sultanate. In Jun 2015, Phoenix Power successfully closed an initial public offering of 35% of its share capital on the Muscat Securities Market. The current shareholders are Axia Power Holdings BV, 100% owned by Marubeni, JERA Power Management Mid East BV, which assumed the share held by Chubu Electric Power Sur BV, Nebras Power QPSC, a joint venture of two state-owned entities, Qatar Electricity and Water Co (QEWC) and Qatar Holding (QH), and Middle East Investment LLC (MEI), a subsidiary of Suhail Bahwan Group which, in Feb 2019, had purchased all shares previously held by affiliate Multitech LLC. Sur is connected to Oman’s 400kV network and 2022 electricity delivery to the grid was 8,714 GWh.

Photo: Phoenix Power Co SAOC

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John Day Hydroelectric Plant, Oregon, USA

John Day Lock and Dam was authorized by the U.S. Congress for power, navigation, and flood control in the 1950 Flood Control Act. The project was built and is operated by the U.S. Army Corps of Engineers on the Columbia River near Rufus in Sherman County, Oregon, 215mi upstream of the Pacific Ocean. This was the final, large-scale hydroelectric development on the Lower Columbia River and is just below the confluence of the John Day River and the Columbia. John Day from Virginia was an early explorer into the Oregon territory. The original design for the power station called for thirteen 85-MW units with provision for an additional seven machines, all to be built for USD 310mn. However, the scheme was considerably upsized by the time construction began in 1958 and the 2,160-MW project was finished in 1972 at a total cost of USD 511mn. There were numerous construction subcontractors including Montag-Halvorson-McLaughlin & Associates, Vinnell Corp, and McNamara-Mannix-Fuller Joint Venture. Baldwin-Lima-Hamilton supplied 16, 135-MW Kaplan T/G sets and General Electric built the generators. These were among 25 identical turbines installed at John Day and three USACE powerhouses on the Lower Snake River (Lower Monumental, Little Goose, and Lower Granite). At completion, the John Day powerhouse was the second largest in the world and it remains the third largest conventional hydro plant in the USA. The project has a 281ft tall, 5,543ft long structural array including a powerhouse, spillway, fish passage facilities on both shores, and a navigation lock. Lake Umatilla, impounded by the dam, extends 110mi upstream to the foot of McNary Dam. In June 2016, USACE awarded a contract to Andritz Hydro for the upgrade of four sets at John Day. Nowadays, the units generally operate at 155 MW. John Day is grid-connected with two 500kV transmission lines and average annual production is 8,418 GWh.

Photo: U.S. Army Corps of Engineers

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Central Solar de Mocuba, Zambezia Province, Mozambique

In Dec 2014, Scatec Solar, Norfund, and Electricidade de Mocambique EP (EDM) signed an agreement for a pre-feasibility study for a solar power project near Mocuba in Mozambique’s northern Zambezia Province. A Joint Development Agreement was executed in Dec 2014 for a 40-MW SPP and this became part of the government’s Economic and Social Development Plan for 2015/16. The 126ha site is near an existing substation, 13km from Mocuba city center in the Zona Economica Especial de Mocuba. The original development consortium was Scatec Solar (52.5%), EDM (25%), and KLP Norfund Investments (22.5%), a financial institution owned by Oslo-based Kommunal Landspensjonskasse (KLP) and the Norwegian Investment Fund for Developing Countries (NORFUND). Scatec served as the EPC contractor. Capex was around USD 76mn and lenders were the International Finance Corp (IFC) and the Emerging Africa Infrastructure Fund (EAIF). Although the FID was made in 2016, Mozambique’s debt crisis and related matters pushed the construction start to Mar 2018. The Mocuba project was inaugurated by the President of Mozambique in Jul 2019. At peak construction, 1,209 people worked on the site of which 1,052 were hired locally. The plant has around 126,000 solar modules. In Jul 2023, Scatec announced the sale of its stake in the Mocuba to Globeleq and the USD 8.5mn sale closed in Dec 2023. The solar plant holds a 25-year PPA with EDM and design production is around 79 GWh/yr. A short, 33kV tie-line was part of the development.

Photo: Norfund

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San Juan de Marcona Wind Farm, Ica Department, Peru

In Apr 2016, Energia Renovable del Sur SA was granted the concession to build the 131-MW San Juan de Marcona Wind Farm, in Peru’s Marcona District, Nazca Provnce, Ica Department. Average wind speeds in excess of 9 m/s are found at the site on the Pacific Coast. The project, originally developed by Enhol Group and later acquired by Acciona Energy, was slightly upsized to 136 MW in Jul 2021. In Apr 2022, Acciona Energia placed an order with Nordex Group for 23 N163/5.X wind turbines from the Delta4000 series for the WPP, the first order from Peru for this model. The WTGs have tubular steel towers with a hub height of 148m with rotors of 163m diameter. The wind farm components were transported from the Peruvian port of Paracas around 240km south to the plant site and Acciona served as its own EPC contractor with Transbiaga acting as the lead er****on and installation company. San Juan de Marcona was connected on 21 Dec 2023 to Peru’s Sistema Electrico Interconectado Nacional de Peru (SEIN). Design production is 608 GWh/y delivered through a 33km long, 220kV transmission line to the Marcona Substation.

Photo: Acciona Energia

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Wendeng Pumped Storage Power Station, Shandong Province, China

In Sep 2015, work got underway on the 1,800-MW Shandong Wendeng pumped storage power station in Jieshi Town, Wendeng District, Weihai City, Shandong Province. The site is in the eastern part of the Shandong Peninsula in the Kunyu mountains and Wendeng was jointly-constructed by State Grid Xinyuan Group Co Ltd and State Grid Shandong Electric Power Co. In Nov 2017, six, single-stage, 300-MW Francis pump-turbines were ordered from Harbin Electric. Hydrochina Beijing Engineering was the consultant and China Gezhouba No 2, China Aneng Construction Group No 2, and Sinohydro No 5 were the contractors. The upper reservoir is formed by a 101m tall, 472m long concrete face rockfill dam. This project is said to be first of its kind to use alkali-resistant, glass fiber reinforced composites (GFRP) in place of traditional rebar in dam panels, tailrace linings, forebays, and other locations. In addition, a new-design, compact, turning radius TBM was developed and built for the project, drilling around 2,300m of tunnels in all. The powerhouse is 360m below ground. The construction workforce peaked at about 5,000. Filling of the upper reservoir was completed in July 2022, the first two units were commissioned in Jan 2023, and the plant went to full power in Sep 2023, around 10mos ahead of schedule. Wendeng PSP was officially commissioned on 19 Dec 2023 with a reported capex of CNY 8,567mn. A 32km, double-circuit, 500kV tie-line was built to connect to the grid. Design annual power generation is 2,628 GWh with an annual pumping power consumption of 3,504 GWh. Provisions were made to both minimize land clearing during construction and expedite re-vegetation.

Photo: Weihai Municipal People's Government

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Maxima Power Station, Flevoland, Netherlands

In November 2005, Electrabel announced plans to build three new power plants in the Netherlands including a pair of 400-450 MW gas-fired, combined-cycle blocks in Lelystad, Flevoland. In Jan 2008, Alstom won an EPC order worth over EUR 400mn for two gas-fired, 440-MW single-shaft CCGT blocks at Flevo based on GT26 gas turbines. The plant was built by GDF SUEZ Energie Nederland, now ENGIE Nederland, and the brownfield, reclaimed site in Lelystad previously hosted the 833-MW Flevocentrale power station. The new plant was completed in Jul 2010 and inaugurated on 6 Dec 2010. It was named after HRH Princess Maxima and cost over EUR 500mn in total. Alstom also supplied the HRSGs, the STF15C steam turbines, and the generators. Maxima connects to the Dutch 380kV and 150kV networks. A 2.2 MW solar plant was built on the artificial island using part of the area previously occupied by the demolished steam-electric plant. In Jul 2021, Ansaldo Energia was contracted for the first installation of the MXL3 upgrade for the No 2 gas turbines at Flevo Maxima, the MXL2 upgrade having previously been installed on the No 1 machine. The MXL3 upgrade was completed in Nov 2023 and increased GT efficiency by almost 3%.

Photo: ENGIE

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Tokushima Tsuda Biomass, Tokushima Prefecture, Japan

In Apr 2019, Hitachi Zosen Corp received an EPC order for the 74.8-MW Tokushima Tsuda Biomass Power Plant. The newbuild project is in the Tsudakaigan lumber park, part of the Tokushima-Komatsushima Port area in Tokushima Prefecture, Japan. The lumber park was completed in 1970 and was one of the largest in the country. For years, the complex on Shikoku Island was a primary entry point for timber imports to meet Japan’s booming housing market but, over time, usage fell off. It is hoped that the new biomass plant will revitalize port and related facilities. Tokushima Tsuda has an Andritz reheat CFB boiler, a Siemens STG, and an air-cooled condenser. Design fuel is imported wood pellets and palm kernel shells (PKS), although domestic woody biomass may be used in future. Plant company Tokushima Tsuda Biomass Power Plant GK is jointly-invested by lead developer RENOVA Inc (60.8%) and Osaka Gas Co Ltd (33.5%), along with local companies Forestbank Co Ltd, DAIRI FPC Co Ltd, and Tokushima Denki Sangyo Co Ltd, which each have 1.9% shares. Hitachi Zosen also secured a 20yr O&M contract for Tokushima Tsuda. Trial operations began in Oct 2022, but operation was delayed for some time by technical issues and Tokushima Tsuda did not go commercial until 11 Dec 2023, about 8mos past the original schedule. Design production is around 500 GWh/yr. Shikoku Electric Power Co Ltd is the power offtaker and will pay a tariff of JPY 24/kWh over the 20yr PPA period.

Photo: RENOVA Inc

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Al Kharsaah Solar Power Plant, Doha Municipality, Qatar

In Jan 2020, project company Siraj 1 SPV secured a 25yr build, own, operate, and transfer (BOOT) agreement with Qatar General Electricity & Water Co (Kahramaa) for the 800MW Al Kharsaah Solar Power Plant. The 1,000ha plant site is 80km west of Doha in Al Kharsaah, Doha Municipality. The project company is jointly-invested by Siraj Energy (60%) and TotalEnergies and Marubeni (40%). Siraj Energy in turn was then a 60:40 JV of Qatar Electricity and Water and Qatar Petroleum. This was the first utility-scale solar park in Qatar and construction started in Feb 2020 during the COVID-19 pandemic period. High temperatures and heavy dust loads also complicated construction. Al Kharsaah was built in two 400-MW sections with a total of around 2mn bifacial solar panels manufactured by Longi Green Energy Technology Co Ltd. These are mounted on automated single-axis sun-tracking system. The plant features a semi-automated cleaning system for the solar modules that cleans off every module once every four days. Sungrow Power Supply Co Ltd supplied ~ 3,200, 1500V string inverters and PowerChina Guizhou Engineering Co Ltd was the EPC contractor while Tractebel was Kahramaa’s independent engineer. On 18 Oct 2022, the SPP was inaugurated by the Emir of Qatar, Sheikh Tamim bin Hamad Al Thani. Design production is around 1,800 GWh/yr and completion allowed for the supply of solar power for the 2022 FIFA World Cup in Qatar. The total SPP capex was reported to be about USD 460mn with co-financing from Japan Bank for International Cooperation (JBIC) and Mizuho Bank. Electricity is supplied to the grid via a 132kV IPP substation and a 132kV/220kV offtaker substation.

Photo: Sungrow

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Shidaowan HTR-PM Project, Shandong Province, China

In Mar 2005, a consortium led by China Huaneng Group Co Ltd selected Rongcheng County, Weihai City, in Shandong to be the site of a ~ 190-MW demonstration, high-temperature reactor (HTR) power station using pebble bed reactor (PBR) technology. In Dec 2006, Huaneng Shandong Shidao Bay Nuclear Power Co Ltd was formed to further the project in cooperation with China Nuclear Engineering and Construction Corp (CNEC), Beijing’s Tsinghua University Institute of Nuclear Energy Technology (INET), and State Nuclear Electric Power Planning Design and Research Institute (SNPDRI ). In 2003, INET finished a 10-MW equivalent PBR and went on design the larger unit, then planned for operation around 2014. However, the development process was considerably extended and the construction permit was not issued until the end of 2012. The Shidaowan HTR configuration includes two INET-designed, 250-MWt PBR reactors plus a single 210-MW STG built by Shanghai Electric. CNEC was the lead EPC contractor and SNPDRI was responsible for the conventional power island. Construction began in Dec 2012 and the concrete base mat concrete pour was completed in Aug 2014. In Jan 2018, CNEC was merged into China National Nuclear Corp Ltd (CNNC). Fuel loading began in Aug 2021, criticality for one reactor followed in Sep 2021 and the second reactor went critical in Nov 2021. Each reactor is loaded with about 400,000 spherical graphite and ceramic fuel elements (pebbles), each 60mm in diameter and containing 7g of enriched fuel. The STG was synchronized in Dec 2021, full power for both reactors was reached in Dec 2022, and the Shidaowan plant was declared in commercial operation on 6 Dec 2023. The HTR-PM is a Generation IV nuclear plant design and is also considered a small modular reactor (SMR). According to CNNC, the project localization rate reached 93.4%. The total investment in the Shidaowan HTR-PM project was reported to be CNY 100bn.

Photo: China National Nuclear Corp Ltd

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Rizziconi Combined Cycle, Reggio Calabria Province, Italy

Rizziconi was built by EGL Italia SpA in the Rizziconi council area on the Gioia Tauro Plain. The plant has two 380-MW, 1+1 CCGT blocks with V94.3A2 gas turbines supplied by Ansaldo. Ansaldo also supplied the STGs and Ansaldo Caldaie SpA built the HRSGs. The EPC contractors included Ansaldo, Electrowatt-Ekono SPE, and Rina Industry. In Feb 2006, a 20yr, EUR 455mn non-recourse financing package closed. This was arranged and underwritten by MCC, Royal Bank of Scotland, and Finmeccanica with participation by Bank of Tokyo-Mitsubishi, Bayern LB, BBVA, BNL, Fortis, HypoVereinsbank, Societe Generale, WestLB and Banca Mediocredito. Milbank, Tweed, Hadley & McCloy LLP, and Grimaldi e Associati represented the lenders. Frigerio Design Group was an industrial design consultant. Rizziconi went commercial on 15 Jul 2008 after 27mos of construction. The plant has an SPX ACC and is zero liquid discharge. It has a 300m overhead connection to the Terna 380kV grid and natural gas is provided through the Snam Rete Gas network. In 2012, the name EGL Italia SpA was changed to Axpo Italia SpA and the plant company is a wholly-owned Axpo subsidiary. In 2019, about three-quarters of the fuel was from Algeria delivered via the Transmed pipeline with the balance from Libya via the Greenstream pipeline.

Photo: Axpo

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Zarqa Power Plant, Zarqa Province, Jordan

In Dec 2015, the Government of Jordan and Saudi company ACWA Power signed an agreement to replace the 400-MW, oil-fired Al Hussein Thermal Power Station with a new 485-MW combined-cycle IPP. In Apr 2016, ACWA and Dubai-based 5 Capitals Environmental and Management Consulting completed an Environmental and Social Impact Assessment (ESIA) for the project for submission to the Jordanian Ministry of Environment. The site is 31km northeast of Amman and 4km east of Zarqa City in the Zarqa Industrial Zone. In Sep 2016, ACWA and EPC contractor Sepco No 3 ordered three dual-fuel 9E.03 gas turbines from GE Power. The plant genco reached financial close in Dec 2016 and obtained non-recourse project financing from the European Bank for Reconstruction and Development (EBRD), the International Finance Corp, the OPEC Fund for International Development, the Europe Arab Bank (EAB), Industrial and Commercial Bank of China (ICBC), and China Construction Bank (CCB). In 2017, Amman-based Kingdom for Energy Investments Co (KEC) acquired a 40% share in ACWA’s plant company Mahatat Al Zarqa Le Tawleed Al Takah Al Kahrabaieyah PSC. KEC in turn is jointly-invested by Social Security Investment Fund, Daman for Energy Investment Co, and the Privatization Holding Co of Kuwait (PHC). The 3+1 plant has NEM HRSGs, and a Doosan Skoda STG. Natural gas is the primary fuel and light distillate oil (LDO) is the backup. A new 600m, gas pipeline spur was built by National Electric Power Co (NEPCO) from the main Jordanian gas pipeline that runs from Aqaba to the north of Jordan. The venture has a 25yr PPA with NEPCO delivered through an existing, onsite NEPCO 132kV substation Design production is around 3,200 GWh/yr. The Zarqa power plant cost USD 489mn and went commercial on 1 Apr 2019.

Photo: Kingdom for Energy Investments Co

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La Yesca Hydroelectric Plant, Jalisco and Nayarit States, Mexico

La Yesca is on the Rio Grande de Santiago in the Sierra Madre Occidental mountains, at the border between the Mexican states of Nayarit and Jalisco. In late 2006, Mexico’s national utility Comision Federal de Electricidad (CFE) rejected the first EPC bids for the 750-MW HPP due to cost and technical reasons and new draft rules were posted in Jan 2007. In Sep 2007, a consortium led by Mexico's Ingenieros Civiles Asociados (ICA) won the CFE bidding with a proposal of USD 768mn. In Jan 2008, President Felipe Calderon inaugurated dam construction at the site, which is 23km northwest of Hostotipaquillo, JAL, and around 105km northwest of Guadalajara. ICA and its consortium partners Promotora e Inversora Adisa, La Peninsular Compania Constructora SA de CV, and Constructora de Proyectos Hidroelectricos, built the world’s then tallest concrete-faced, earthfill dam at 208.5m. The structure has a crown length of 629m. The project also includes a spillway with eight radial gates, a right-bank intake structure, two pressure tunnels, an underground powerhouse, and three, 410m discharge channels. The La Yesca reservoir is around 55km long. The project design and construction specifically addressed the need for additional seismic protection due to the previously unrecognized presence of a fault-line in the project area. These requirements increased the cost of the project by 25-30% according to CFE officials. The La Yesca hydroelectric project generated around 10,000 direct and indirect jobs. Russia’s Power Machines Group was awarded the contract for two 375 MW Francis generating units and their manufacture and supply was completed in 2010. President Calderon inaugurated the project on 7 Nov 2012, at which time the plant was formally named after Ing Alfredo Elias Ayub, who was CFE director for over 10yrs. Design production is around 1,210 GWh/yr delivered to the grid through a 400kV substation in Mesa de Flores, JAL. In Sep 2012, CFE issued MXN 13.5bn of Certificados Bursatiles (Cebures) in the Mexican market to conclude the financing for La Yesca’s construction. The stock certificates carry a 30yr term. The total capex for La Yesa was reported to be about USD 1.25bn.

Photo: CFE

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Los Teros Wind Farm, Buenos Aires Province, Argentina

The YPF Luz Los Teros Wind Farm was built in two phases on around 3,500ha of agricultural lands approximately 45km from city of Azul, in Argentina’s Buenos Aires Province. In Nov 2018, YPF Luz signed a turnkey EPC and equipment supply agreement with GE Renewable Energy for the first phase which has 32, GE Wind 3.83-MW WTGs arranged in four sections. The first phase capex was around USD 144mn. Construction on Los Teros-II began at the end of 2019 and was completed in Jun 2021. GE also supplied the second phase with 13, 4-MW WTGs and overall construction staffing on the WPP was around 800. CTE Wind and Neowind SA were sub-contractors for the 175-MW project, which connects to the Transba SA 132kV line between Tandil and Olavarria. The site has a better-than-average wind resource and annual production is around 838 GWh. Los Teros Wind Park exclusively supplies the Mercado a Termino de Energia Electrica de Fuente Renovable (MATER). YPF has offtake agreements with various industrial and commercial companies such as Toyota, Coca -Cola FEMSA, Nestle, Profertil, Holcim, Santander, Ford, Roca, Hyatt and YPF, among others. The total capex for the full project was reported to be USD 235mn.

Date: 27 Nov 2023

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Ali Metin Kazanci Antalya Phase-II, Antalya Province, Turkey

The Ali Metin Kazanci Antalya power station of Aksa Enerji is in Dosemealti District, around 25km northwest of Antalaya City in Turkey's south-coast Antalaya Province. The 900-MW, second phase of the combined-cycle plant began simple-cycle operation in Aug 2009 and full combined-cycle service in Oct 2011. The plant has two 300-MW Siemens SGT5-4000F gas turbines, NEM HRSGs, and one 300-MW Siemens SST5-5000F steam turbine. The EPC contractors were Aksa Enerji, BGM Engineering Ltd, and Mastir Enerji Tesisleri Montaj Ltd Sti. The Phase-II project cost about USD 1.1bn and average production is around 5,000 GWh/yr. In Q4, 2022, a comprehensive EUR 16mn modernization program was carried out by Proterm Enerji and Siemens after the CCGT plant had reached 100,000 operating hours. Around three-quarters of the annual natural gas requirement is obtained from Turkish national pipeline company Botas with the remainder secured from private-sector fuel companies. Around 90% of the CCGT plants annual sales are on the spot market. The plant is named after Ali Metin Kazanci, Chairman of Kazanci Holding, which is Aksa Enerji’s parent company.

Photo: Aksa Enerji

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South Texas Project, Texas, USA

In Dec 1971, Houston Lighting & Power Co (HL&P), the City of Austin, the City of San Antonio, and Central Power and Light Co (CP&L) initiated a feasibility study for a regional, jointly-owned nuclear power plant. At the time, the initial cost estimate was reported to be USD 974mn. Two years later, a 4,900ha site was selected west of the Colorado River, 15mi southwest of Bay City, Matagorda County, and about 90mi southwest of Houston. Two 1,250-MW, four-loop Westinghouse PWRs and Westinghouse Electric turbosets were ordered for the project and Houston-based Brown & Root was hired as the EPC contractor. The construction permit was issued in May 1974 and construction got underway in Dec 1975. In 1979, construction began on the associated 2,800ha reservoir to provide main condenser cooling water. This began filling in Jul 1983. In Sep 1981, the owners dismissed Brown & Root and contracted Bechtel Power Corp and Ebasco Constructors as replacements. At that point, STP’s estimated capex has doubled from around USD 2.7bn to USD 4.8bn. In May 1985, Brown & Root announced that it had agreed to pay USD 750mn to settle a lawsuit over construction delays and related matters at STP. At that time, the final cost for both units was estimated to be USD 5.5bn. Unit-1 went critical in Mar 1988 and went commercial on 25 Aug 1988. Unit-2 reached initial criticality in Mar 1989 and went into commercial operation on 19 Jun 1989. In Dec 2002, CP&L, by then part of AEP announced that it was selling its STP stake along with other generating assets in Texas and, in May 2005, Texas Genco LLC acquired 13.2% for USD 164mn and CPS Energy purchased 12% for about USD 150mn. In Oct 2005, NRG Energy agreed to take HL&P’s stake in STP, then held with tother plant assets by Texas Genco LLC, and the sale closed in Feb 2006. On 1 Nov 2023, Constellation Energy Corp completed its ~ USD 1.75bn acquisition of NRG Energy’s 44% ownership stake in STP Nuclear Operating Co. CPS Energy continues to have a 40% share and Austin Energy has 16%. Both units have been uprated to 1,354 MW gross and station output is around 20 TWh/yr. STP is connected to the regional 345kV grid. In Jun 2006, plans were announced for two additional units at the site, and an application was made to the Nuclear Regulatory Commission in Sep 2007, the first such application since 1979. Due to substantial cost escalation and other issues, the extension was cancelled in Apr 2011.

Photo: Constellation Energy

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