Page 1 of 25

To: EPA-HQ-OAR-2013-0495 Date: 08/03/2015 Re: U.S. DOE Information Relevant to Technical Basis for “Large Modification” Threshold

Note: The attached information was provided to EPA by the U.S. Department of Energy dreview of the final 111(b) rule. The EPA described the types of large projects that could co

potential increase in hourly CO2 emissions (lb/hr) of more than 10%. Neither the EPA nor imply that any of the projects listed in the tables below necessarily would have resulted i‘Modifications’. However, the table is intended to indicate the types of projects that EGUcould potentially result in increased hourly emissions. 
Page 2 of 25

Modifications of Existing Units – Summary Table 

Unit Name Unit Type Original 

Capacity

Modified Capacity 

Percent Change in Capacity 

TimeRequired

Number of Units Modified

Cost Description of Modificati

Arnot Fossil 

Steam 

350 MW 400 MW 14.3% ~3 years 6 units 110 

million Euros (2012) 

• Retrofit high pressure 

intermediate pressurturbines 

• Capacity upgrade of l

pressure steam turbin

• Replacement and upg

associated turbine sidand auxiliaries 

• Boiler upgrades, inclu

pressure part componburners, and modificaother equipment such coal mills and classifieand heaters. 

Matra Fossil 

Steam 

212 MW 241 MW 13.7% ~2 years 2 units $50.6

million (2005) 

• Add two gas turbines 

existing power blocks power station. 

None/GE Combined 

Cycle 

N/A N/A 12% N/A N/A N/A • Replacement of turbi
Page 3 of 25

Unit Name Unit Type Original 

Capacity

Modified Capacity 

Percent Change in Capacity 

TimeRequired

Number of Units Modified

Cost Description of Modificati

DTEK Vostokenergo 

Fossil Steam 

175 MW 210 MW 20% ~1 year 2 units N/A • Retrofit to unit boiler

and generator. 

• A full–scale automate

control system (APCSadded. 

Belchatów Power Plant 

Fossil Steam 

360 MW 390 MW; 

400 MW 

8.3%; 11.1% 

~4 years 6 units 160 

million Euros (2011) 

• Retrofit turbines and 

electro-hydraulic conand instrumentation (I&C) equipment. 

• Upgrade boiler firing • Add distributed contr

eight new pulverized burners and a flue gaexchanger 

Bonanza Plant Fossil 

Steam 

440 MW 500 MW 13.6% ~1 year? ? units N/A N/A

Hawthorne Fossil 

Steam 

500 MW 550 MW 10% ~2 years 1 unit N/A N/A 

Intermountain Power Plant 

Fossil Steam 

750 MW; 880 MW

950 MW 8%; 

26.6% 

~1 year (8%) 

2 units $27 

million 

• Uprating generators 

Dunamenti Power Plant 

CT converted to Combined Cycle 

215 MW 400 MW 86% ~2 years 1 imot N/A • Replaced high-pressu

turbine with a high penew module 

• Upgraded medium an

pressure cylinders, geand balance of plant 
Page 4 of 25

Unit Name Unit Type Original 

Capacity

Modified Capacity 

Percent Change in Capacity 

TimeRequired

Number of Units Modified

Cost Description of Modificati

Río Escondido Fossil 

Steam 

1200 MW 

1320 MW 

10% ~2 years 4 units $200 

million 

• New steam turbines 

Koradi power plant 

Fossil Steam 

210 MW 230 MW 8.5%; 

9.5% 

~1 year 1 unit Rs2 crore 

per MW 

• The vital parts of the 

turbine and generatocoal handling system changed and modifieincrease the operatioefficiency. However, tfoundation and the bwill remain as it is. 

Polaneic Power Plant 

Fossil Steam 

225 MW 240 MW 6.7% ~1.5 

years 

6 units 65 million 

Euros 

• Replace intermediate

pressure turbines 

• Overhaul of low press• Modernization of turb

auxiliary systems 

Suralaya Power Plant 

Fossil Steam 

400 MW 440 MW 10% ~2 years 2 units N/A • Refurbish boilers 

LaCygne power plant 

Fossil Steam 

750 MW 765-770 

MW 

2%; 3% N/A 1 unit N/A • Replaced control valv

once-through supercr

Tiverton Power Station 

Combined Cycle 

265 MW 287 MW 8.3% N/A 1 unit ~$80 

million 

• Incorporate three GE 

FlexEfficiency* upgraofferings, including a compressor, a Dry Low 
Page 5 of 25

Unit Name Unit Type Original 

Capacity

Modified Capacity 

Percent Change in Capacity 

TimeRequired

Number of Units Modified

Cost Description of Modificati

combustor and GE’s AGas Path technology 

Little Barford Power Station 

Combined Cycle 

680 MW 720 MW 5.8% ~1 year ` unit ~£100 

million 

• Replaced two gas tur

control system 

• Full upgrade of boiler

turbines, generators, plant components 

Craig (CO) Fossil 

Steam 

418 MW 448 MW 7.2% N/A 1 unit $39 

million 

• Installing low NOx bu

scrubber upgrades 

Allen S. King Plant 

Fossil Steam 

550 MW 610 MW 10.9% ~4 years 1 unit $488 

million 

• Complete steam turb

replacement 

• Steam generator reha

with replacement of cand lower furnace 

• Conversion to balance

operation 

• Circulating water syst

modification with new towers 

• Coal handling upgrad• Auxiliary electric syste

upgrades 

• Complete distributed 

system replacement 

• Installation of comple

quality control system 
Page 6 of 25

Unit Name Unit Type Original 

Capacity

Modified Capacity 

Percent Change in Capacity 

TimeRequired

Number of Units Modified

Cost Description of Modificati

selective catalytic redNOx control, flue gas for control of SOx emand fabric filters for cPM 

Hamm Power Plant 

Fossil steam 

160 MW 1600 

MW 

900% N/A 2 units N/A • Replacing old units w

coal-fired units 

Termopaipa power plant 

Fossil steam 

31 MW; 33 MW 

39 MW 25.8%; 

18.1% 

~2 years 1 unit Est. €14 

million 

• Modify boiler steam f

auxiliary systems 

• Replace generators a

turbine 

Note: Source for data in this table are included in the Attachment below. 
Page 7 of 25

Attachment – Source Data for Modifications 

[Arnot] Alstom signs power plant upgrade and retrofit contract with Eskom in 

South Africa 

03/01/2012 

Alstom has won a contract worth 110 million euros to refurbish the 2,100 MW Arnot coal-fired power 

plant in South Africa, and increase its power output by 300 MW to 2,400 MW. The plant is owned by 

state-owned utility company Eskom. 

For each of Arnot’s six steam generating units, Alstom will carry out a complete retrofit for the high

pressure and intermediate pressure steam turbines, a capacity upgrade of the low pressure steam 

turbine and the replacement and upgrade of associated turbine side pumps and auxiliaries. In addition,

Alstom will carry out major upgrading works to the boiler plant, including supply of new pressure part

components, new burners, and modification to other equipment such as the coal mills and classifiers, 

fans and heaters. 

The first unit is scheduled to be completed by December 2007 and the last unit by December 2010. 

Alstom was able to offer Eskom an integrated plant retrofit approach for this complex power plant 

project, which encompasses many major generating plant components such as boilers and turbines. The 

Arnot capacity increase project (ACIP) is the first combined capacity increase and retrofit project in

South Africa. 

Philippe Joubert, President of Alstom’s Power Turbo-Systems/Power Environment Sector, said: "This 

new contract represents a significant milestone in the historically strong relationship between Alstom

and Eskom. This demonstrates our unique ability to offer an integrated solution involving all the major 

components of a retrofit project - boilers, steam turbines...This solution allows us to offer Eskom a 

better competitiveness as well as an environmentally friendly power plant." 

Source: http://www.alstom.com/press-centre/2006/10/alstom-signs-power-plant-upgrade-and-retrofitcontract-with-eskom-in-south-africa/

Adding a much needed 300 MWe at South Africa’s Arnot coal fired power plant 

As power stations built in the last thirty years approach the end of their design life, and the cost of new 

capacity continues to increase – along with demands for improved efficiency and lower emissions - an 

integrated approach to retrofit looks increasingly compelling. The ambitious upgrade project currently

underway at the Arnot coal fired plant in South Africa – which will result in an uprate from 6 x 350 MWe 

to 6 x 400 MWe and a life extension of 20 years – illustrates the benefits. 

http://www.modernpowersystems.com/features/featureadding-a-much-needed-300-mwe-at-southafrica-s-arnot-coal-fired-power-plant/ 
Page 8 of 25

[Matra] Babcock-Hitachi wins €40m extension order for Hungary's Matra 

power plant 

05/19/2005 

19 May 2005 - Babcock-Hitachi Europe (BHE) has received the order to extend the Matra lignite-fired 

power plant from Matra Kraftwerk AG, with head offices in Visonta, Hungary. The order is worth around 

€40m ($50.6m). 

BHE will be supplying two turnkey gas turbine systems. This will raise the capacity of the Matra power

plant by 82 MW. Currently five lignite-fired units at Matra generate electricity; total capacity is in the 

order of 836 MW. The power plant lies at the foot of the Matra mountains near Gyöngyös, 100 km 

north-east of Budapest. 

The main equipments of both systems are two Hitachi H-25 gas turbines/generator sets, which will be 

supplied by Hitachi, Ltd. The order also includes concept and final planning, supply and erection of the 

components, quality assurance management and system commissioning. For Klaus-Dieter Rennert, Chief 

Operating Officer of the BHE board of directors, "the contract award reflects well on the 

competitiveness of the Hitachi gas turbines in the wake of operating condition optimization in European 

power plants by experienced Oberhausen BHE specialists." Rennert went on to say that this order was a 

good example of the excellent cooperation with the Hitachi group to provide an integrated solution for

customer. "Our knowledge of customer needs in Europe is of enormous help," says the managing 

director, "in getting across the product benefits of technology to the customer." 

Apart from a greater capacity, the two upstream systems starting commercial operations at the end of 

2006 and the start of 2007 provide Matra Kraftwerk AG with a further advantage. There will be a 

substantial increase in controllability of the power plants -plant that generate electricity for base load 

requirements. Consequently, the operator can react considerably more flexibly to electricity market 

demands. And there is also something positive for the environment: both systems will lower specific 

CO2 emissions of the two lignite-fired units by some 10 per cent. 

Source: http://www.power-eng.com/articles/2005/05/babcock-hitachi-wins-euro40m-extension-orderfor-hungarys-matra-power-plant.html 

Matra targets new gas turbines 

Hungary’s Matra Power Plant has signed a 40 million Euro contract with Babcock-Hitachi Europe GmbH 

to build gas turbine generators, Interfax reported, citing the plant telling MTI on February 18. The new 

generators, to be in operation by early 2007, will boost the plant’s capacity by 92 MW to 928 MW. 

Matra also signed a 20 million Euro contract with Hitachi Europe GmbH to service the turbine until 2021. 

Matra will finance the project from its own funds. Babcock-Hitachi Europe will build two gas turbines, of 

29 MW capacity each, to two 212 MW existing blocks of the power station, which has a total of five 

blocks. Steam from the two generators will add an additional 34 MW capacity combined. The new 

generators will increase the efficiency of the two blocks where they will be built from 20 percent to 37 
Page 9 of 25

percent. The gas-steam cycle generators themselves operate at 46.5 percent efficiency. The new 

generators will also reduce the two blocks’ CO2 output by 10 percent. 

Source: http://www.neurope.eu/article/matra-targets-new-gas-turbines/ 

[GE] GE Supplies New Turbines, Unveils New Retrofit Technologies that 

Increase Plant Capacity and Efficiency 

General Electric (NYSE: GE) is deploying gas turbines at power plants in the U.S. and Saudi Arabia, and is 

also introducing new equipment that can be used to retrofit existing plants, driving up capacity and 

efficiency at those existing facilities. 

GE unveiled the technologies in a Dec. 9 session with the media at PennWell’s annual Power Generation 

Week conference in Orlando. 

In the U.S., GE will supply two of its highly efficient and flexible 7F.05 gas turbines to Calpine Corp. for 

the York 2 Energy Center, a nominal 760-MW, dual-fuel combined cycle plant near York, Pa. That project

is adjacent to Calpine’s existing York Energy Center. The turbines are to be delivered to the site in 

December 2015. 

These turbines will use GE’s Dry Lower NOx 2.6+ dual-fuel combustion system, which reduces NOx 

emissions to as low past 9 parts per million during gas-fired operations without using water injection

technology. The turbines will also be able to operate on low-sulfur diesel fuel. 

In Saudi Arabia, the first four of GE’s 7F.05 gas turbines at Saudi Electric Co.’s Power Plant 12 have

reached commercial operation, with another four to follow. All eight units at PP12 should be operating

commercially in combined-cycle mode by early 2015, delivering nearly 2,000 MW. 

PP12 is part of Saudi Arabia’s plan to add 33 GW of power capacity by 2020. The eight units at PP12 are 

the first of 20 GE 7F.05 turbines to be delivered, with another 12 turbines for PP13 and PP14 to be 

delivered in late 2014 and early 2015. 

Two new breakthrough technologies that GE announced for its 7F turbines - which can be built as part of 

new installations and retrofit on older ones – are the Dry Low NOx (DLN) 2.6+ Combustion and 

Advanced Compressor upgrades. These are the latest additions to GE’s Power FlexEfficiency portfolio of

upgrade solutions. 

Said Paul McElhinney, GE’s president and CEO of Power Generation Services: “These solutions will 

provide our customers with the operational flexibility to quickly respond as their needs evolve over 

time.” 

The DLN 2.6+ solution adds fuel flexibility, allowing burns of up to 25 percent ethane or propane from

shale gas, along with regular natural gas. The system can also handle up to 20 percent hydrogen. The 

first order for this upgrade system has been placed with an unnamed Midwest power plant. The 

technology also allows reductions of NOx emissions to as low as 5 ppm. It can be combined with GE’s 

OpFlex software to further reduce emissions. 
Page 10 of 25

The Advanced Compressor can increase efficiency (by up to 2 percent), output (by up to 12 percent) and

operational availability. This system is new to the retrofit market, but already being used on new 7F.05 

gas turbines. 

Source: http://www.power-eng.com/articles/2014/12/ge-supplies-new-turbines-unveils-new-retrofittechnologies-that-increase-plant-capacity-and-efficiency.html 

Gas Turbine Performance Upgrades: 7F Advanced Compressor Technology 

Expanding Asset Value with High Performance 

In recent years, GE’s 7F compressor technology has focused on solutions to help keep you up and 

running reliably. The new 7F gas turbine advanced compressor upgrade solution breaks through new 

performance barriers that can better position you to capture new revenue opportunities, lower 

operating costs and solidify a long-term asset management strategy. 

Increased efficiency up to 2% - driven by an airflow increase up to 25% 

Expanded output up to 12% - generate more power, even in hot climates 

What Can the 7F Advanced Compressor Do for You? 

Elevate efficiency, enabling lower fuel costs, as well as improved hot day performance, delivering more 

power when it’s needed most. 

Lower costs by reducing maintenance needs and downtime. 

Increase flexibility—fulfill your existing grid commitments, and generate more power to capitalize on 

peak demand, capturing new revenue. 

Extend the power generation capacity of your surrounding plant assets as they’re upgraded and 

replaced—getting more value from overall plant operation. 

How We Get You There 

Engineering advancements with 3D aero superfinish airfoils and variable stator vanes enable higher 

performance in the advanced compressor. 

Collaborate with our team to create a customized package tailored to your budget and needs. 

Our teams can advise you on a range of advanced software and controls options to tap into even better 

performance and value with your compressor and turbine assets. 

- See more at: https://powergen.gepower.com/service-optimize/services/gas-turbines/performanceupgrades/7f-advanced-compressor-solution.html#sthash.F6gzIq4e.dpuf 

Source: https://powergen.gepower.com/service-optimize/services/gas-turbines/performanceupgrades/7f-advanced-compressor-solution.html 
Page 11 of 25

[DTEK Vostokenergo] Emerson chosen to automate DTEK Vostokenergo 

thermal power plant in Ukraine 

PlantWebTM technologies chosen for project to increase output, reduce fuel consumption at Lugansk 

Unit 10 

PITTSBURGH (May 31, 2011) – Emerson Process Management has been chosen to provide new control, 

measurement, and automation technology for Unit 10 of the Lugansk coal-fired power plant in 

northeastern Ukraine. Emerson’s PlantWebTM digital plant architecture will play a key role in the 

Vostokenergo generating company’s project to modernize the Lugansk thermal power plant. 

“Reconstructing Unit10 will help us increase its generating capacity from 175 to 210 MW while reducing

fuel consumption,” said Alexander Nagorsky, operations director for Vostokenergo LLC. “Commissioning 

of the unit is scheduled for the beginning of this autumn, and within five years we expect to replace 

obsolete equipment in five more units with reliable, high-quality technology that will also help improve 

the plant’s technical and economic performance.” 

As part of the PlantWeb architecture for Unit 10, Emerson will provide its OvationTM expert control 

system, Fisher® control valves, and Rosemount® instruments for measuring flow, level and pressure of 

steam and water. Plant personnel will use Emerson’s AMS Suite predictive maintenance software to 

detect and diagnose problems before they disrupt power-generating operations. 

“With the combined capabilities of these integrated technologies, Vostokenergo can look forward to 

gaining the full benefits of the PlantWeb architecture,” said Alexey Etkin of Emerson Process 

Management. 

The project is the first in the Ukrainian power industry to use Emerson’s AnnubarTM averaging pitot tube 

technology rather than traditional diaphragm-based sensors to measure the flow of process water and 

steam. The Annubar sensors’ insertion technology helps reduce installation and maintenance costs as 

well as ongoing energy costs. 

Emerson also provided automation design, installation, or commissioning services for the modernization

project. 

Lugansk is one of three plants operated by Vostokenergo LLC, which is part of the vertically integrated 

DTEK energy company. Emerson previously modernized the control systems of Units 5 and 7 at 

Vostokenergo’s Kurakhovskaya plant and control of Unit 2’s turbo feed pump at the Zuyevskaya thermal 

power plant. 

About Vostokenergo 

Vostokenergo (DTEK) is a private power generating company in Ukraine, a leader in thermal power 

generation, and operates the Zuyevskaya, Kurakhovskaya and Lugansk power plants. Total installed 

capacity for all units on January 1, 2011 was 4157 MW. Since 2007 Vostokenergo has been 

implementing a large-scale modernization program for all units. 
Page 12 of 25

About Emerson Process Management 

Emerson Process Management (www.EmersonProcess.com), an Emerson business, is a leader in helping 

businesses automate their production, processing and distribution in the chemical, oil and gas, refining, 

pulp and paper, power, water and wastewater treatment, mining and metals, food and beverage, life 

sciences and other industries. The company combines superior products and technology with industryspecific engineering, consulting, project management and maintenance services. Its brands include 

PlantWebTM, SyncadeTM, DeltaVTM, Fisher®, Micro Motion®, Rosemount®, DanielTM, OvationTM, and AMS 

Suite. 

About Emerson 

Emerson (NYSE:EMR), based in St. Louis, Missouri (USA), is a global leader in bringing technology and 

engineering together to provide innovative solutions to customers in industrial, commercial, and 

consumer markets through its network power, process management, industrial automation, climate 

technologies, and tools and storage businesses. Sales in fiscal 2010 were $21 billion. For more 

information, visit www.Emerson.com. 

 PlantWeb, Syncade, DeltaV, Fisher, FIELDVUE, Micro Motion, Rosemount, Annubar Daniel, and Ovation 

are marks of one of the Emerson Process Management legal entities. All other marks are the property 

of their respective owners. 

Source: http://www2.emersonprocess.com/en-US/news/pr/Pages/1105-Vostokenergo.aspx 

DTEK Announces 2011 Operating Results 

[Excerpt from text follows]

In 2011, Vostokenergo’s Luganskaya TPP unit #10 and Kurakhovskaya TPP unit #8 were retrofitted. The 

retrofit included all the unit’s main components: boiler, turbine and generator. A full–scale automated 

process control system (APCS) is also being introduced. The retrofit is expected to increase the installed 

capacity of Luganskaya TPP unit #10 from 175MW to 210MW, reduce fuel consumption by 63 g/kWh, 

and increase its operational range from 45 MW to 80 MW. 

Source: http://www.dtek.com/en/media-centre/press-releases/details/dtek-announces-2011-

operating-results#.VbKis6RVhBc 

[Belchatów] Belchatów Power Plant, Poland 

Key Data 

Plant Type Coal-fired power plant 

Location Bełchatów, łódź province, Poland 

Start of Operation 1988 
Page 13 of 25

Output 4,440MW 

Plant Owner PGE Elektrownia Belchatow 

Boiler Supplier Rafako under license from Sulzer and EVT 

Turbine Supplier Zamech under a license from Brown Boveri & Cie 

The 4,440MW Belchatów power plant is located near Belchatów in the lódz province of Poland. 

Operated by PGE Elektrownia Belchatow (PGE), it is the biggest lignite-fired power plant in Europe. The 

plant was commissioned in 1988 and currently accounts for 20% of the Polish power market. 

In January 2011, PGE commissioned the 13th unit with a capacity of 858MW. The new unit has the 

highest efficiency of 41% and conforms to European standards on green house gas emissions. The 

generator was commissioned in September 2011. 

"Prior to the expansion, the Belchatów plant had 12 units of 360MW each." 

Retrofit of the existing units is also underway to increase the design life of the plant by 25 years. 

Plant make-up 

Prior to the expansion, the Belchatów plant had 12 units of 360MW each. All of the units are equipped 

with a BB-1150 boiler, an 18K360 turbine and a GTHW-360 generator. Coal is supplied to the plant from 

a nearby coal mine through conveyor belts. 

Plant details 

With a heat capacity of 750Gcal/h and performance rating of 1,150t/h, the boilers have spirally wound 

furnace walls and are suspended on a grate carrier supported by four pillars. Design of the boiler 

features a low load circulation system. 

Coal is fed into the combustion chamber through a scraper and belt feeders. Eight mazut burners are 

used to light the coal with air supplied by two air fans and exhaust fans. The combustion chamber of the 

boiler features two circulating pumps. 

Superheated steam generated by the boiler is sent to single shaft turbines. The turbines feature four 

control valves and are rated at 370MW with a turnover of 3,000rpm. A programme to modernise the 

turbines was carried out between 1997 and 2004, which increased the capacity by 10MW and reduced 

heat energy consumption by 210KJ/kWh. 

A synchronous generator with a bipolar structure and cylindrical rotor generates electricity. 

Development 

In April 2009, PGE launched a retrofit programme for unit 6 of the power plant to increase the unit's 

output to 390MW-400MW. 
Page 14 of 25

The upgrade programme will retrofit the turbines and auxiliaries, electro-hydraulic control system and

instrumentation and control (I&C) equipment. The boiler firing system will be upgraded to reduce 

emissions to 200mg/Nm3 for CO and NOx. A new distributed control system, eight new pulverised coal 

burners and a flue gas heat exchanger will also be added to the unit. 

In 2010, another retrofit project for units 7 to 12 was launched to increase their capacity by 20MW each. 

High pressure and intermediate pressure turbines and auxiliaries, bypass systems and I&C equipment 

will be installed as part of the retrofit. New electrostatic precipitators will also be installed to reduce 

emission levels to 50mg/Nm3. 

The contract for the retrofit programme was awarded to Alstom in March 2011. 

"Alstom was awarded a €160m contract in 2009 to retrofit the unit 6." 

IFS implemented an ERP system at the plant, which helped in quick access to operational data and 

enhanced document management. 

Emerson was contracted in November 2009 to carry out the modernisation of units 5 and 6. The 

company had earlier won a contract to automate units 3 and 4. Under the 2009 contract, Emerson 

installed its PlantWeb digital plant architecture and Ovation expert control system to upgrade the units' 

I&C. 

Emerson will also install 110 Rosemount wireless temperature transmitters on the boilers to monitor 

temperatures. The project will help in reducing the CO2 emissions to 200mg/m3 and the NOx emissions 

to 200mg/m3. 

In February 2011, Emerson won another contract worth $95m to automate units 7 to 12. 

The units 7 and 8 of the plant are planned to be shut down in January 2012 and June 2012 respectively 

for modernisation. These units will be recommissioned in 2013. 

Contractors 

Rafako constructed the boilers for the plant with technology licensed from Sulzer and EVT. 

The turbines were manufactured by Zamech under a license from Brown Boveri & Cie (now part of ABB). 

The generators were manufactured by Dolmel (now part of Alstom Power). Hayward Tyler supplied the 

circulating pumps. 

In 2008, Hempel provided its high quality protective coatings for the cool water pipelines of the plant. 

Babcock Borsig Service was awarded a contract in 2009 to supply flue gas displacement system for units

5 and 6. 

SGS served as the technical consultant for the 13th unit of the plant. PERI supplied a falsework 

combination consisting of ST 100 stacking towers and MULTIPROP aluminium slab props for the 13th 

unit. ME Construct was also involved in the construction of the unit. 
Page 15 of 25

Alstom was awarded a €160m contract in 2009 to retrofit the unit 6. In October 2010, Alstom was 

awarded another retrofit contract worth €140m for units 7 to 12. 

Pollution issues 

The Belchatów plant is considered to be one of the biggest producers of greenhouse gas emissions in 

the EU, emitting about 30mt/y of CO2. To reduce the emissions from the plant, PGE has launched a two 

phase programme to build carbon capture plants (CCP). 

In the first phase, a pilot CCP will be built at unit 12. The pilot CCP will use Alstom's Advanced Amine 

Process with amine solvent supplied by Dow Chemical. It will capture about 100,000t/y of CO2. 

In the second phase, a bigger plant will be built to capture carbon emissions from the new 858MW unit.

The new plant will capture 1.8mt/y of CO2 and is expected to be operational by 2015. The project will 

require an investment of $776m and has received a €180m grant from the European Investment Bank in 

May 2010. 

Source: http://www.power-technology.com/projects/belchatow-plant/ 

[Bonanza] Deseret Power Electric Cooperative, Bonanza Power Plant, Uintah 

and Ouray Reservation, Uintah County, Utah: Statement of Basis 

[Excerpt from text follows]

We are especially interested in how the State made the determination in 1998 that the “ruggedized 

rotor” project was only a synthetic minor modification and did not trigger PSD review. The 1998 

Approval Order and supporting documentation state that boiler heat input was increased from 4381 

MMBtu/hr to 4578 MMBtu/hr, and that approximately 20 MW from the upgrade will result from an 

increase in steam flow produced by the boiler. To date, the boiler has not been operated at its peak 

potential due to limitations of steam flow at the existing Turbine Generator. The Project will allow the 

Turbine Generator to accept all of the steam flow the Boiler is capable of producing. While the 

Ruggedized Rotor by itself will not result in any change to Bonanza 1’s emissions, the increased capacity 

of the Turbine Generator to handle the Boiler’s peak capacity will increase the Bonanza plant’s overall 

potential to emit (PTE). 

To our knowledge, we were never advised of, nor involved in, that action. We do not understand how 

this boiler could be up-rated from 440 MW to 500 MW without an increase in actual emissions, unless 

Deseret acted to offset the increase in actual emissions by some physical change or change in its 

method of operation. We are concerned that the reductions in allowable lb/mmbtu emission rates 

mentioned in the “Permitting History” do not reflect a reduction in actual emissions and what we are 

seeing are merely “paper” reductions. 

Source: http://www2.epa.gov/sites/production/files/2014-04/documents/deseret_04-28-

14_draft_statement_of_basis_v-uo-000004-00.00.pdf 
Page 16 of 25

[Hawthorne] Completing a 550MW Pulverized Coal Fired Utility Project on an 

Accelerated Schedule 

In February 1999, a natural gas explosion destroyed a 500MW coal-fired utility boiler at Kansas City 

Power & Light Company’s Hawthorn Generating Station. The loss of this critical base-load unit left 

Kansas City Power & Light (KCPL) with a difficult decision—replace the coal-fired boiler, or convert to 

gas-fired combined cycle. Although most of KCPL’s power generating plants burn coal, Unit #5 was the 

only coal-fired unit at Hawthorn Station. Ultimately, KCPL decided to replace the destroyed steam 

generator with another coal-fired unit, and repower the existing turbine/generator equipment. By 

August, 1999 the utility, Burns & McDonnell and Babcock & Wilcox had a plan in place to build a new, 

550MW pulverized coal-fired facility and have it producing power and revenue by June 2001. 

Source: http://www.babcock.com/library/Documents/br-1724.pdf 

[Intermountain] THE ECONOMIC AND FISCAL IMPACTS OF EXPANDING THE 

INTERMOUNTAIN POWER PROJECT 

[Excerpt from text follows]

Construction of IPP began in October 1981. The initial concept for the $5.4 billion project was to build 

four 750-MW coal-fired units in Lynndyl, Utah, a site located approximately 100 miles southwest of Salt 

Lake City. However, by the time the first two units began operating in 1986 and 1987, the project had 

beendownsized to two 750-MW units leaving room on the site for additional expansion. Since the mid1980s, the gross capacity of the existing units has been upgraded to 1,900 megawatts. 

Source: http://bebr.business.utah.edu/sites/bebr/Documents/uebr/UEBR2003/Sep-Oct%202003.pdf 

Intermountain Power Agency Annual Report 2004 

[Excerpt from text follows]

Particularly notable this year was the completion of a project to upgrade the generating capacity of IPP’s 

units to 950 megawatts. The uprate project was completed during three one-month outage periods 

involving 22 separate contracts and 192,000 hours of work. The project resulted in an increase of 140 

megawatts of new, net generation capacity. Cost of uprating both of the plant’s generators was 

approximately $27 million and the investment is expected to pay for itself in about a year. 

Source: http://www.ipautah.com/data/upfiles/pdfs/IPAAnnaulReport2004.pdf 

[Dunamenti] Alstom successfully completes the retrofit of the steam turbine 

island at the repowered gas-fired Dunamenti Power Plant in Hungary 

Alstom’s Thermal Services unit in Hungary has successfully completed modernisation of unit 8 of the 

Dunamenti gas-fired power plant owned by Gaz de France Suez. The modernisation project awarded to 

Alstom in 2008 included the retrofit and upgrade of the complete steam turbine island and the 

associated balance of plant at unit 8 of the plant to match the new steam data following the installation 

of a gas turbine from another vendor. The project started in April 2009 and has been successfully 
Page 17 of 25

completed with the commissioning of the retrofitted unit 8 in July this year. It has contributed to the 

increased output of unit 8 from 215 MW to above 400 MW and the jump in efficiency by more than 20 

% - from 36 % to 57 %. The efficiency increase also results in a substantial reduction of CO2 emissions 

from the plant. 

This project was a brown field investment, whereby the steam turbine island unit no 8 was modernised 

by using the power plant’s existing infrastructure. The six conventional type 215 MW steam turbines at

the plant including the related condensers and feedwater heaters were originally supplied by Alstom 

companies. Within the scope of this project, Alstom replaced the high-pressure steam turbine in unit 8

with a high performance new module and upgraded the medium and low-pressure cylinders, the 

generator and the balance of plant – thus enabling the turbo group and its auxiliaries to operate in a

highly efficient combined cycle mode. 

László Deák, Country President of Alstom Hungary said, “Alstom is proud to have been a part of the 

rehabilitation of Hungary’s biggest power plant. Repowering is a special engineering application that 

requires significant engineering capabilities to synchronise the existing equipments with the new ones. 

Alstom has significant experience in the field that has allowed us to complete this project timely and

contribute to the increase in output and efficiency. This upgrade will be a key example of the services 

we can provide to upgrade the power generation fleet in Hungary.” 

Dunamenti is located near Budapest and is one of the country’s biggest power plants with 6 x 215 MW 

steam turbine units and two other combined cycle and cogeneration units. The plant has a total capacity 

of 1736 MW. The retrofit of unit 8 labelled ‘G3’ was part of a bigger rehabilitation programme 

undertaken by Gaz de France Suez to reduce the environmental impacts of their plant. 

Source: http://www.alstom.com/press-centre/2011/7/alstom-successfully-completes-retrofit-steamturbine-island-repowered-gas-fired-dunamenti-power-plant-hungary/ 

[Río Escondido] MHPS to increase output at thermal power plant in Mexico 

12/03/2014 

Mexico’s Federal Electricity Commission (CFE) has awarded Mitsubishi Hitachi Power Systems, Ltd. 

(MHPS) a full turnkey order, worth $200 million, to increase the output of Units No.1 through No. 4 at

CFE's Río Escondido Thermal Power Plant from 1,200-MW to 1,320-MW. The plant is located in Coahuila, 

Mexico. 

The order was received through Mitsubishi Hitachi Power Systems de México, S.A. de C.V. (MHPS-MEX) 

and Eléctrica de Río Escondido S.A. de C.V. 

MHPS will replace the original equipment, installed in 1982, with new steam turbines and other core 

equipment, and will be responsible for all aspects from auxiliary equipment design, manufacture and 

procurement to civil engineering, installation and test operation. 

Construction is expected to begin in February 2017, with work on the remaining three units to get under 

way every six months or so thereafter. The project is scheduled for completion in February 2019. 
Page 18 of 25

Source: http://www.power-eng.com/articles/2014/12/mhps-to-increase-output-at-thermal-powerplant-in-mexico.html 

[Korai] Maharashtra all set to upgrade old power sets 

Monday, 27 July 2015 - 6:50am IST | Place: Mumbai | Agency: dna | From the print edition 

Move will help increase generation capacity at lower costs than setting up new projects 

To boost electricity generation and increase the efficiencies of its thermal power units, the state power 

generation utility is planning to modernise its old sets. This will help add capacity at lower costs than 

setting up new projects and generate more power from lesser quantity of coal. 

A large number of the Maharashtra State Power Generation Company Limited's (MahaGenco) thermal 

power sets are old and antiquated. Of the 29 units in service, 11 are over 30 years old and 6 are aged

above 25 years. All these units have an installed capacity of 210 MW each. 

Of the MahaGenco's 7,980 MW installed coal-based capacity, almost half (3,570 MW) is in these 

antiquated units, which have lower generation efficiencies. The modernisation project, which will add 

capacity and expand efficiency in generation at a cost lower than that of setting up a new unit, has been 

launched at the Koradi power plant. It will later be expanded to four more units, namely one set each at 

Nashik, Bhusawal, Chandrapur and Parli, based on this experience. 

"We have undertaken the renovation and modernisation of one 210 MW unit at Koradi. Here, the vital 

parts of the boiler, turbine and generator and the coal handling system will be changed and modified to 

increase the operational efficiency. However, the foundation and the boiler's body will remain as it is. 

This will increase the installed capacity of this unit to around 228 to 230 MW from the present 210 MW. 

Since these units are old, they have a plant load factor of only 50 to 52% and this renovation will bring it 

up to 80 to 85%. This means we can generate more power with lesser coal," said a senior MahaGenco 

official. 

The Koradi project was launched last year and the actual work has begun this month. It is expected to be 

completed by March 2016. The state will get funds from the World Bank and infuse the remaining 

amount as equity for the project, the official stated. 

The official added that this modernisation cost just around Rs2 crore per MW as compared to the costs 

of setting up a new coal-based thermal power set at around Rs6 to 7 crore per MW. 

"We are undertaking work on 3,230 MW new capacity, including three 660 MW sets at Koradi and two 

1,000 MW units at Chandrapur. The Koradi units are supercritical sets, which means they have less 

variable costs. This additional capacity, which will be on line by March 2016, will enable us to shut down 

old units for renovation and modernisation," the official said. 

MahaGenco has 7,980MW of its 11,237MW installed conventional energy capacity in coal, with the 

remaining comprising of gas (672MW) and hydro power (2,585MW). The average weighted average cost 
Page 19 of 25

of power generated by the utility is about Rs3.28 per unit, with that of thermal being around Rs3.70 per 

unit. 

Source: http://www.dnaindia.com/mumbai/report-maharashtra-all-set-to-upgrade-old-power-sets2108357 

[Polaneic] Alstom signs modernization contract worth approximately 65 

million euros for the Polaneic Power Plant in Poland 

07/05/2012 

Alstom, the global leader in steam turbine retrofitting, today announced that it has signed a contract

worth approximately €65 million with GDF Suez Energia Polska S.A., which owns and operates Poland’s 

Polaniec power plant for modernisation of six units (units 2-7) of the power plant. The contract also 

includes the option of retrofitting an additional unit (unit 1) of the power plant. 

Połaniec Power Station is a coal-fired power station near Połaniec in Świętokrzyskie Voivodeship, 

Poland. It consists of eight units each with a generation capacity of 225 MW. The first unit was 

commissioned in 1979 and the last in 1983. Between 1992-1995, the low pressure (LP) steam turbines of 

all the units were retrofitted. 

Under the terms of the contract , Alstom will engineer, deliver and commission new high pressure (HP) 

and intermediate pressure (IP) steam turbines. The scope also covers main overhaul of LP parts, the 

modernisation of the turbine auxiliary systems. The first modernised turbine will be ready for operation 

in May 2013 and the final one will be handed over for commercial operation in December 2014. 

Decision about the modernisation of unit 1 will be taken before 2014. 

The modernisation will improve the units’ availability and reliability and will extend the plant’s lifetime 

by an additional 25 years. On average each unit will generate an output in excess of 240 MW, following

the modernisation. Increase in unit efficiency will also significantly reduce carbon dioxide emissions

from the facility. 

The modernisation project will be fully executed by Alstom’s Thermal Services organisation in Poland. 

The majority of the steam turbine will be manufactured at Alstom’s steam turbine factory in Elblag. 

The contract represents a further consolidation of Alstom’s retrofit experience in Poland and follows 

orders worth approximately €15 million to upgrade the Kozienice and Lodz coal-fired power plants, 

signed earlier in March this year. 

Alstom is also currently retrofitting the existing steam turbine of Polaniec power plant unit 9* to 

optimally match its new biomass-converted boiler. It is expected to enter commercial operation by the 

end of this year. 

Source: http://www.alstom.com/press-centre/2012/5/alstom-signs-modernisation-contract-worthapproximately-65-million-for-the-polaniec-power-plant-in-poland/ 
Page 20 of 25

[Suralaya] B&W subsidiary awarded contract to upgrade boilers at Indonesia 

power plant 

1/20/2009 11:00 AM BARBERTON, Ohio 

Babcock & Wilcox Power Generation Group, Inc. (B&W PGG), a major operating unit of The Babcock & 

Wilcox Company (B&W), has been awarded a contract to refurbish two B&W Radiant Tower-type boilers 

at the Suralaya Steam Power Plant on Java Island, Indonesia. 

B&W PGG will redesign and supply superheater and reheater surface, low NOx combustion systems, 

pulverizer performance enhancements, and other boiler upgrade equipment. 

The contract was signed with Marubeni Corporation, the prime contractor on the Suralaya rehabilitation

project. The Suralaya plant is owned by Indonesia's government-run utility company, Perusahaan Listrik

Negara which is overhauling the 3,400-megawatt (MW) coal-fired power plant to extend its life, improve

its efficiency and reduce emissions. 

Suralaya's Units 1 and 2, currently 400 MW each, were originally supplied by B&W in the early 1980s. 

The upgrades will increase the capacity of each unit to 440 MW. 

"B&W is known for its commitment to designing and delivering high-quality steam generating and 

pollution control systems for customers around the world," said Richard L. Killion, President and Chief 

Operating Officer of B&W PGG. "We have nearly 5,000 MW of installed capacity in Indonesia, and B&W 

designed and supplied all seven original boilers and accessory components for the Suralaya plant. We're 

pleased to have been selected for this new project and appreciate the continued confidence the 

customer has in our ability to meet their needs." 

Engineering is underway at B&W PGG's Barberton, Ohio, headquarters and material delivery is expected 

in late 2009 and early 2010. P.T. Babcock & Wilcox Asia, a wholly owned subsidiary of B&W PGG, will 

provide services during boiler installation, commissioning and testing. Unit 1 is scheduled to go online in 

the fall of 2010, followed by Unit 2 several months later. 

Marubeni Corporation is one of the largest general trading companies in Japan. 

Source: http://www.babcock.com/news-room/Pages/BW-subsidiary-awarded-contract-to-upgradeboilers-at-Indonesia-power-plant.aspx 

[LaCygne] KCP&L increases plant capacity by retrofitting new control valves 

2011 

KCP&L investigated potential advantages of replacing the BW202 and BW207 valves on the once 

through supercritical boiler on Unit 1 at their 750 MW LaCygne power plant. 

Since the startup valve upgrade, the plant’s capacity has increased by 15-20 MW. 
Page 21 of 25

Source: 

http://www.documentation.emersonprocess.com/groups/public/documents/articles_articlesreprints/d

350930x012.pdf 

[Tiverton] GE Signs $80M Agreement with Emera Energy; Pact Includes 

Upgrades to Tiverton Power Plant 

Nova Scotia, Canada-based energy company Emera Energy has selected GE (NYSE:GE) to upgrade its 

Tiverton Power station in Rhode Island in an effort to increase the efficiency, capacity and long-term

availability of the power plant and reduce its operating costs and environmental impacts. The 265-

megawatt (MW) natural gas-fired combined-cycle power plant provides electricity to Rhode Island and 

the surrounding area through ISO New England (ISO-NE). 

This investment marks the first combined-cycle project in North America to incorporate three GE Power 

FlexEfficiency* upgrade offerings, including a new .04 compressor, a Dry Low NOx 2.6+ combustor and 

GE’s Advanced Gas Path technology solution. 

The upgrades of the plant’s 7F.03 gas turbines would help Tiverton Power save an estimated $1 million 

in fuel costs annually and boost the plant’s combined-cycle output by 22 MW. Emera Energy’s Pickles 

noted that by producing more megawatts more efficiently, this also will help improve Emera Energy’s 

competitive position against other power plants in the ISO-NE dispatch stack. 

About Emera (Parent Company of Emera Energy) 

Emera Inc. is geographically diverse energy and services company headquartered in Halifax, Nova Scotia, 

with $10.19 billion in assets and 2014 revenues of $2.97 billion. The company invests in electricity 

generation, transmission and distribution, as well as gas transmission and utility energy services. 

Emera's strategy is focused on the transformation of the electricity industry to cleaner generation and 

the delivery of that clean energy to market. Emera has investments throughout northeastern North 

America and in four Caribbean countries. Emera continues to target having 75-85 percent of its adjusted 

earnings come from rate-regulated businesses. Emera common and preferred shares are listed on the 

Toronto Stock Exchange and trade under the symbols EMA, EMA.PR.A, EMA.PR.C, EMA.PR.E, and 

EMA.PR.F. Additional Information can be accessed at www.emera.com or at www.sedar.com. 

About GE 

GE (NYSE:GE) imagines things others don’t, builds things others can’t and delivers outcomes that make 

the world work better. GE brings together the physical and digital worlds in ways no other company can. 

In its labs and factories and on the ground with customers, GE is inventing the next industrial era to

move, power, build and cure the world.www.ge.com 

Source: http://www.businesswire.com/news/home/20150715005919/en/GE-Signs-80M-AgreementEmera-Energy-Pact#.VbfKSrNVhBc 
Page 22 of 25

[Little Barford Power Station] 

Little Barford is a combined cycle gas turbine power station located south of St Neots on the 

Cambridgeshire-Bedfordshire border on the site of a former coal fired power station. 

Little Barford began operation in 1996 and had a generating capacity of 680MW enough to meet the 

electricity demands of over half a million households. 

The power station has one generating module, consisting of two gas turbines and one steam turbine. 

The Station also has an open cycle gas turbine providing black start capability to the site. 

Earlier this year the station finished a year long £100 million investment to upgrade the gas turbines and 

other areas of the power station. It is envisaged that the upgrade will extend the life of the plant to 

around 2025, and included replacing the two gas turbines and the control system alongside a full 

upgrade of the boilers, steam turbines, generators and other plant components. 

The Power Station has a new capacity of 720MW, equivalent to an additional 30,000 homes that can 

now be powered by the plant. 

Emissions of nitrogen oxides (NOx) have been reduced by 40% which will enable the station to meet the 

stricter environmental limits being implemented in the UK on power generators. The increased fuel 

efficiency of the plant will save the equivalent of 118,000 tonnes of carbon dioxide (CO2) each year. 

When operating normally the power station can provide all its own works power. However when the 

power station is shut down it then usually requires electricity from the National Grid to start up. 

In the event of a major failure of the national grid distribution system, the black start turbine will allow 

the power station to start up without taking electricity from the National Grid. 

The main fuel used to generate electricity at Little Barford Power Station is natural gas, however the

station also has the ability to use gas oil as a back up fuel. 

Source: http://www.rwe.com/web/cms/en/97560/rwe-npower/about-us/our-businesses/powergeneration/little-barford/ 

Little Barford Power Station 

Little Barford is a combined cycle gas turbine power station with a generating capacity of 700MW, 

enough to meet the electricity demands of over half a million households. 

The power station has one generating module, consisting of two gas turbines and one steam turbine. 

The Station also has an open cycle gas turbine providing black start capability to the site. In 2012 the 

station underwent a £100 million upgrade to improve its efficiency and environmental performance – 

boosting the station’s output by 50MW and reducing CO2 emissions by around 70,000 tonnes a year. 

The station is located south of St Neots on the Cambridgeshire-Bedfordshire border on the site of a 

former coal fired power station. 
Page 23 of 25

Source: http://www.rwe.com/web/cms/en/1772606/rwe-generation-se/locations/uk/little-barfordpower-station/ 

[Craig] Tri-State plans $39 million power plant upgrade 

 A $39 million renovation project for Tri-State Generation and Transmission's 418 MW Craig power plant

will increase output without increasing emissions, according to the company. The renovation, slated to

begin April 4, will increase turbine capacity by 30 MW. 

The project includes installing low-NOX burners and scrubber upgrades as well as planned maintenance 

operations, Tri-State said. 

Source: http://www.power-eng.com/articles/2009/02/tri-state-plans-39-million-power-plantupgrade.html 

[Allen S. King] Xcel Energy Allen S. King Generating Station 

The first project consisted of process piping installation for the new air quality control system (AQCS) 

and selective catalytic reduction (SCR) equipment at the single-unit coal-fired generating plant. This 

contract included process pipe for the ammonia, lime, and ash handling systems, as well as lubrication

equipment and various utility systems. 

The second contract included installing process pipe for the Balance of Plant Project. This contract 

consisted of process pipe and equipment for the steam, condensate, cooling water, and feed water 

processes for the 550 megawatt facility. This project ties into several systems of the new AQCS and SCR. 

After the upgrades were completed, the Allen S. King plant emissions were significantly reduced and 

output increased by 60 megawatts. 

Source: http://www.hmcc.com/projects/allen-s-king-plant/ 

Projects of the Year 

01/01/2008 

The Allen S. King Plant Rehabilitation Project was successfully completed and dedicated July 25, 2007 

and is the 2007 Best Coal-fired Project Honorable Mention award winner. The project scope 

encompassed installation of state-of-the-art emissions control equipment and rehabilitation of the 

existing electric generation equipment to return this Xcel Energy plant to its original design capacity 

while significantly reducing the plant’s airborne emissions. 

The Allen S. King Plant permitting and equipment design activities began in 2003, with on-site 

construction activities beginning in 2004. It was the first of three Xcel Energy projects tied to the 

Emissions Reduction Rider to be completed. 

The scope of the project included installation of a complete air quality control system (AQCS) that 

included selective catalytic reduction (SCR) for NOX control, flue gas scrubbers (spray dryers) for control 

of SOX emissions and fabric filters for control of particulate matter. It also included complete steam
Page 24 of 25

turbine replacement; steam generator rehabilitation, including replacement of the cyclones and lower 

furnace; conversion to balanced draft operation; circulating water system modifications, including new

cooling towers; coal handling upgrades; auxiliary electric system upgrades; complete distributed control 

system replacement; and other equipment rehabilitation to extend the plant’s life. 

Source: http://www.power-eng.com/articles/print/volume-112/issue-1/features/cover-featureprojects-of-the-year.html 

Direct Testimony and Schedules James R. Alders Before the Public Utilities Commission of The State of 

South Dakota In the Matter of the Application of Northern States Power Company, a Minnesota 

corporation For Authority to Increase Rates for Electric Service in South Dakota 

06/30/2015 

Further, the [Allen S. King Plant] project resulted in the recovery of 60 MW of capacity and energy that 

had been lost due to degradation and fuel switching, restoring the King plant to its full original output of 

564 MW with plant investment of approximately $488 million. This additional capacity and energy is 

now available to serve our customers at very little additional operating expense using state-of-the-art 

pollution control equipment. The rehabilitated King plant began operations in 2007. 

[Hamm] Westfalen power station - Units D and E 

New hard coal-fired units 

Two new hard coal-fired units with a total capacity of some 1,600 megawatt are being erected at the 

existing Hamm power plant site in Westphalia. The most advanced plants of their kind worldwide, they 

will replace the 160-megawatt units commissioned in 1962/63 and expand the capacity of the site. At 

the same electricity production, the new plant will require 20% less coal. With net efficiency of 46%,

they reduce CO2 emissions by an annual 2.5 million tons compared with legacy plants – an effective 

contribution to preventive climate protection. In addition, the power plant can later be retrofitted with 

a flue gas scrubber that permits carbon dioxide to be captured and stored following combustion. 

Source: http://www.rwe.com/web/cms/en/348148/rwe-technology-the-power-plant-specialist-in-therwe-group/construction-projects/new-build-projects/westphalia/ 

[Termopaipa] Alstom signs a contract to upgrade Termopaipa thermal power 

plant in Colombia 

Alstom has signed a contract worth over €14million with Gensa SA ESP for lifetime extension and power 

upgrade in Termopaipa Unit 1, a power plant located at Paipa, Boyaca. The upgrade will bring more 

energy to the local population and improve the efficiency of the plant. The implementation will be 

concluded in 2016. 

Alstom’s scope includes a power output increase from nominal 33 MW to 36 MW in a first step and later 

on to 39 MW upon further modifications for boiler steam flow, auxiliary systems and life time extension 
Page 25 of 25

through repair or replacement of components, such as generators and steam turbine. The work will be 

executed in a partnership between Alstom’s teams in Columbia and Germany. 

“We have been providing services to this key Customer for more than 50 years and now we have the 

unique opportunity to improve its performance and extend its lifecycle. We are proud to be part of this 

important chapter in the history of the Colombian power sector”, says Patricio Albuja, Managing 

Director for Thermal Services at Alstom Colombia. 

Termopaipa Unit 1 power plant was commissioned in 1963 with original turbines and generators from 

Alstom. The Electrostatic precipitators of Units 1 and 3 were recently upgraded by Alstom to comply 

with the more stringent environmental regulations in Colombia. 

Source: http://www.alstom.com/press-centre/2014/11/alstom-signs-a-contract-to-upgradetermopaipa-thermal-power-plant-in-colombia/ 

Energy Management GENSA SAESP 

[Note: Translated using Google translate] 

 SAESP Energy Management - is a corporation, joint utility company, commercial, with its headquarters 

in Manizales, own legal status, full administrative autonomy and independent capital. Its main 

shareholder is the Nation - Ministry of Finance with 90.93% of the share percentage. 

The Central Termoelectrica Termopaipa property GENSA, is a plant for generating electrical energy from

steam, whose production is used as the only fuel coal and is located at Km 3 via Paipa - Tunja, 

Municipality of Paipa, Department of Boyaca; has an installed capacity of 321 MW, distributed with 

31MW Unit I, Unit II with 70 MW and 70 MW Unit III GENSA property and commercial representation in 

the MEM Unit IV of Company property Sochagota Electric CES with a generating capacity of 150 MW, 

which makes GENSA in most coal-fired thermal generating company in the country. 

Source: http://www.andeg.org/node/14