Vigilant Plant Success Stories

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Vigilant Plant Success Stories part 1

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  • 2010

    30204

    VigilantPlantSuccess StoryCollection

    00A01A53-01E

    TrademarksAll brand or product names of Yokogawa Electric Corporation in this bulletin are trademarks or registered trademarks of Yokogawa ElectricCorporation. All other company brand or product names in this bulletin are trademarks or registered trademarks of their respective holders.

  • This is a showcase of success stories from our customers worldwide.

    Many leading companies are using Yokogawa products to manage their

    plants and processes.

    VigilantPlant Success Stories

  • The clear path to operational excellence

    Envision a plant where people are watchful and attentive while your business responds to change quickly and efficiently. Now picture an operation that delivers non-stop production while confidently expanding your capabilities into the future.

    Imagine no further. This is the vision and promise behind VigilantPlant, the clear path to operational excellence.

    Making critical plant information fully visible is just the beginning of the vigilant cycle.

    Power

    Contents VigilantPlant Success Stories

    23 SC Electrocentrale Bucuresti SA2325 EGCO Cogeneration Co., Ltd.2527 Samutprakarn Cogeneration Co., Ltd.27

    29 Australian Gas Light Company2931 Greater Toronto Airports Authority 3133 District Cooling System and Power Plant Co., Ltd.3335 Kraftszer Kft3537 PetroChina Company Limited3739 Energy Brix Australia Corporation 3941 PNOC-EDC41

    01 Eraring Energy0103 The City Utilities of Springeld0305 Pha Lai 2 Thermal Power Joint Stock Company0507 The 4th Thermal Power Plant0711 Macquarie Generation1113 Tachibanawan Thermal Power Station1315 Itoigawa Power Plant1517 Tuas Power Station1719 Korea South East Power Co., Ltd.1921 Bahia de Bizkaia Electricidad, Bahia de Bizkaia Gas21

    49 Japan Wind Development Co., Ltd.4951 Lakeside EFW51

    43 Australian National University4345 NEP SOLAR Pty Ltd.4547 A.T. Biopower Co., Ltd.47

    Seeing clearly gives you the knowledge necessary to anticipate the changes required in your process. Knowing in advance brings you the speed and flexibility to optimize your plant in real time.

    And by acting with agility, you are able to adapt to the ups and downs of your business environment.

    VigilantPlant excels at bringing out the best in your plant and your people - keeping them fully aware, well informed, and ready to face the next challenge.

  • 1 Power 2

    Plant InformationPlant name: Location: Project type: Plant type: Output: Order date: Completion:

    System maintainabilityAnother important issue to be considered was system maintainability. From the late 1990s (before the control system replacement), the customer had progressively upgraded its analog field instruments selecting Yokogawa DPharp EJA transmitters as well as other vendors devices. A further requirement was to upgrade the original paper-based field device management system to a Windows-based, user-friendly tool which integrates various data from multivender HART and analogue devices into a single database. The customer wanted system compatibility with the DCS and used the opportunity of the plant revamping to achieve tight integration of the field device management system into the DCS.

    Minimum plant outageAnother challenge was the tight commissioning schedule. The first outage was planned 15 months after the initial order. To minimize the time taken for the control system replacement, Yokogawa proposed a unique solution making full use of the capabilities of the Yokogawa DCS and simulator.

    The CENTUM has a unique engineering test function that enables an application functional test on a general-purpose PC without any real controller hardware. Yokogawa affiliate TechComm Simulation developed the high-fidelity simulation system based on the detailed plant documentation supplied by the customer. Combining these capabilities, Yokogawa engineers were able to very extensively test the new control system on the simulator prior to DCS commissioning, thereby minimizing the final tuning work once the unit returned to service.

    Eraring plant operators were well trained in the new control system utilizing the simulator. This avoided mistakes that could have occurred if they had not been familiar with the new system, ensuring a smooth plant commissioning process.

    System DetailsDistributed control system, Burner management system: CENTUM CS3000 R3 Plant information management system: Exaquantum Integrated plant resource management system: Plant Resource Manager (PRM) Simulator: TechComm full-replica training simulator Field devices: EJA series electronic pressure transmitters, GD series gas density meters Project includes: Full functional requirements design, control system software development, factory acceptance, installation, commissioning & tuning

    Operational improvements ensuring plant reliabilityThe Eraring plant has four large units with a total system input/output (I/O) count of more than 40,000 as well as 25,000 interfaces to other plant auxiliary systems. Yokogawas CENTUM CS 3000 R3 DCS supported this large application in a single architecture while ensuring reliable plant operation with itspair&spare non-stop controller technology.

    To satisfy the need for further operational improvement, a Yokogawa Exaquantum plant information management system was used for long-term data storage, data and alarm logging, and performance calculation. The users can monitor the graphical data for both current and historical plant information in an Exaquantum window at their own PCs using the Eraring wide area network. This makes it easier for operators and plant managers to keep informed and to make decisions for future plant operation.

    The customer also desired to improve plant operation in the aspects of human resources and operating environment. Yokogawas high fidelity, full-replica simulator enabled custom-made operator training that fully replicated the characteristics of the Eraring Power Station. This allowed the operators to be familiar with all aspects of plant operation using the new control system before running the real plant. The original analog-based control room was replaced with a new control room which is based on the latest ergonomic design, securing operators higher performance.

    Eraring Energy

    Australia

    BackgroundEraring Power Station, located just north of Sydney, is one of the largest power stations in Australia, comprising four 660MW coal-fired units. The power station has operated reliably since 1981. To ensure continued reliability for the next few decades, Eraring Energy, the owner of the power plant, decided to replace the original hard-wired control equipment with a modern integrated control and monitoring system (ICMS). Significant project drivers were the requirements to maintain plant reliability and to gain operational improvements in order to ensure the competitiveness in the deregulated Australian power market. The re-instrumentation work started in early 2003 under the leadership of Yokogawa Australia, which teamed up with TechComm Simulation, a wholly owned Yokogawa subsidiary.

    The Challenges and the SolutionsThe customer required an integrated system to control the operation of the boilers, turbines, generators and other balance of plant equipment. Yokogawa proposed an integrated solution comprised of a distributed control system (DCS), plant information management system, field device management system, full-replica training simulator and field instruments together with strong local support.

    Highly Integrated Control and Monitoring Systems Solution for Australias Largest Power Station

    Yokogawa met these requirements for integrated device management across the HART protocol with a combination of its CENTUM CS 3000 DCS and its Plant Resource Manager (PRM) software. The new system integrates all field information into a single database on a PRM server and allows real-time, remote maintenance of many hundreds of devices, including around 500 EJA transmitters, via the DCS networks and HART I/O modules. The open architecture of PRM will also allow the diagnostics of smart Fisher valve positioners via the Yokogawa DCS just by loading diagnostic plug-in software onto the PRM server. This integrated maintenance solution helped Erarings maintenance crew streamline plant maintenance work.

    The ResultsFaster commissioningThe four units at Eraring are being retrofitted progressively, with the first changeover in August 2004 and the second unit being completed at the beginning of 2005. The customer was very pleased that Yokogawa has completed return to service of the first unit ahead of schedule, with the second unit approximately two weeks early and similar results expected for the third and fourth units.

    Efficient operation ensuring high reliabilityThe renovated units give very stable, and at the same time more flexible operation than before. After the revamping, the customer now makes everyday load changes at a rate faster than with the previous control system. This can provide financial benefits in the competitive Australian electricity market.

    Efficient maintenanceIntegrated device management enables predictive maintenance, reducing routine maintenance work. Jeff Hogan, Power Station Technicians Supervisor of Eraring Energy said, The upgrading of field instrument is still in progress but PRM has provided access from our workshop to all smart instruments on site. When a plant problem occurs we are able to verify the validity of reading and configuration settings of the associated instrument within a couple of minutes. A great diagnostic tool which enhances the Yokogawa CS3000 System.

    Plant InformationPlant name: Eraring Power StationLocation: New South Wales, AustraliaProject type: Plant revampingPlant type: Coal-fired power plantOutput: 4 x 660MW Order date: 2003Completion: August 2004-2005

  • Power 4USA

    System DetailsSystem: CENTUM CS 3000 Total I/O: Approximately 1,400System configuration: 9 x HIS, 1 x EWS, 1 x SIOS, 1 x GSGWOther: PRM (Plant Resource Manager), FF, Bailey INFI90 interfaceScope: System, project management, design, configuration engineering, commissioning services

    ScopeWe decided to handle all the new-system installation in-house, said Stodden. That way our personnel would be very familiar with everything involved. We were delighted with how smoothly the entire procedure went, and we completed installation in only six weeks. We had virtually no problems with the CS 3000 hardware or software. Our biggest obstacle was moving the electrical interlocks required to combine the two control rooms into one. If the Yokogawa system had not worked so well, we would never have made our startup dates.

    Originally, he continued, Units 1 and 2 were housed in one control room, while Units 3, 4 and 5 were housed in a separate control room. As part of this project, we combined these into one. The new system has worked so well, that we now utilize one control operator to run both Units 1 and 2, where before each unit had a dedicated control operator assigned to each unit.

    Units 3, 4 and 5 use a hybrid configuration. These units are equipped with an older control system platform, utilizing Hand-Auto Stations for operator interface. This control system, while dated, is still supported. Therefore, as a step toward uniformity among the units, we utilize the Yokogawa Operator Console Platform to communicate with the older control system hardware already in place. The operators see the same style of operator screens as Units 1 and 2, without realizing that it is utilizing a completely different control system. Annunciators and selected other functions work directly from the CS 3000 control; control loops are displayed on the CS 3000 screens but are processing existing control loops through an interface.

    When asked about acceptance by operators of the new electronic system, Stodden illustrated by quoting one of the men who initially said he thought the new system was the worst decision we had ever made. But within two months after startup, the same operator asked When are we going to do the other three units? Suffice it to say that by now our operators are very comfortable and pleased.

    The CS 3000 system has provided the ability for automatic control sequences not previously practical. For example, shutting down a coal feeder used to require many control manipulations to maintain safe operation of the boiler. The entire sequence is now automatic. We just hit a key and sit back to watch everything progress through the control sequence, said Stodden with a satisfied smile.

    Notes on James River Power PlantThe plant, which celebrated its 50th anniversary in 2007, consists of five coalfired boilers equipped with steam turbines and two natural-gas-fired turbines. The plant initially was designed to utilize natural gas as its primary fuel, with coal as a winter backup fuel. This switched during the late 1970s driven by the Power Plant and Industrial Fuel Use Act of 1978. The station now utilizes less than 1% natural gas for fuel for the steam boilers.

    Ultra low-NOX burners and overfire air(OFA) were introduced later to greatly reduce nitrogen oxide emissions in preparation for EPA standards that went into effect in 2009. All units of the James River Power Station remain capable of burning either 100% coal or 100% natural gas in order to produce electricity.

    The plant currently supplies slightly more than half of the electricity generated by City Utilities. Forced outages at the plant have averaged slightly more than 1%, which is approximately one-fifth of the national average.

    BackgroundIn 1957, the City Utilities of Springfield, MO, commissioned a pneumatic distributed control system for its James River Power Plant. At that time, the plant was considered very advanced because it utilized a centralized control room for operations, instead of a series of separate control stations located throughout the facility.

    Through the years since, explained Maintenance Manager Steve Stodden, we had attempted to keep the existing systemfunctional, but maintaining a 50-year-old system has proven difficult. Several years ago we started discussions with all plantpersonnel involved about upgrading the old control system to improve the safety of the plant and to take advantage of modern digital technology. The result is that we now operate our five generating units with varying stages of a new CS 3000 control system from Yokogawa.

    Evaluating the ChoicesOur evaluation of competing vendors was based on consideration of a combination of factors with the awareness that the new system will probably be in place for decades until the current facility is retired, said Stodden. We had to be confident of the vendors support during this extended future time period.

    With the vendor selected, system details were then examined. The initial bid was based on 4-20 mA protocol but replaced by FOUNDATION fieldbus (FF) as advantages of FF emerged. The plant has five generating units with a total capacity of 253 MW (two 22 MW, one 44 MW, one 60 MW, and one 105 MW).

    The City Utilities of SpringfieldJames River Power Plant Replaces Legacy Control System

    3

    Plant InformationPlant name: James River Power PlantLocation: Springfield, MO, USAProject type: Control system revampingPlant type: Coal and gas fired power plantOutput: 253 MW (2 x 22 MW, 1 x 44 MW, 1 x 60 MW and 1 x 105 MW)Order date: March 2006Completion: April 2007

    CENTUM CS 3000

    System Configuration

  • 5 Power 6

    Plant DetailsType of boiler: Down-shot coal-firedBoiler: 922 t/h, Mitsui Babcock Energy Ltd., UK (Doosan Babcock)Steam turbine: General Electric, USASteam temperature: 541CSteam pressure: 17.0 MPaGross unit output: 600 MW (300 MW x 2 units)

    Systems DeliveredDistributed control system for boiler control, burner management, balance-of-plant control, etc: CENTUM CS 3000Human-machine interfaces: 10 screens per unitField control stations: 15 controllers per unitTotal hardwired I/O: 16,400Field devices: Yokogawa transmitters

    Customer SatisfactionNguyen Khac Son, PPCs Chief Executive Officer, said, We are very happy to be using the Yokogawa CENTUM CS 3000 process control system. We are now operating nonstop without any major problems, using Yokogawas system and field transmitters. We are operating near capacity almost every day and are sending this power to the national grid. Continuous operation is a very important point. He continued, The CENTUM CS 3000 is the brain of this power station and the field transmitters are important sensors for monitoring all power plant equipment and processes. We have a good relationship with Yokogawa Vietnam and look to working with them in the future.

    The Challenges and the Solutions1. Steady power supply and safe operationPower demand from the national grid is high, and the Pha Lai 2 power station covers a significant percentage of that. It needs to provide a very steady supply of power 24 hours a day, 7 days a week, all through the year. Yokogawas highly reliable CENTUM CS 3000 DCS makes this possible.

    In addition, Yokogawa transmitters installed in the power island area are contributing to the high overall reliability of this power station.

    The CENTUM CS 3000 provides integrated control of the power stations steam turbine control system, water treatment PLC, wastewater treatment PLC, ash handling PLC, burner management system, and coal handling system, enabling the data from these systems to be monitored in real time on graphic displays. This gives plant operators all the information they need to take quick and effective action whenever needed, thus ensuring the safe operation of the plant and the stable supply of power to the national grid at all times.

    2. Environmentally optimized operationCoal-fired power plants produce significantly more greenhouse gasses than plants that rely on natural gas and other fuels. Thanks to the fine-tuned boiler combustion control configured in the CENTUM CS 3000 system and the use of an oxygen monitoring system that can precisely track the oxigen concentration in the flue gas, it has been possible to optimize the combustion process under varying load conditions and keep CO2 emissions at this plant well within regulatory guidelines. In addition, a Yokogawa solution has made it possible to monitor and strictly control the CO, NOx, and SOx values in the flue gas and the pH value of the water from the plants cooling towers. In these ways, the Pha Lai 2 power station is maintaining a sustainable operation.

    3. High fidelity power plant training simulatorFor effective operation and engineering staff training, the training simulator uses the test features of the CENTUM CS 3000 to simulate the power plant. The operator training interface accurately replicates the plant control console and graphical interface.

    Vietnam

    Yokogawa CENTUM CS 3000 Ensures a Stable Supply of Power to Vietnams National Grid Pha Lai 2 Thermal Power Joint Stock Company

    Plant InformationPlant name: Pha Lai 2 Power StationLocation: Hai Duong, VietnamProject type: NewPlant type: Coal (anthracite) fired power plantOutput: 2x 300 MWOrder date: 1999Completion: 2002

    Executive SummaryWith a power generating capacity of 600 MW, Pha Lai 2 is the largest coal-fired plant in Vietnam. As part of a master plan by the Vietnam Ministry of Industry to meet rapidly rising demand for power by doubling the countrys generating capacity, the power station was constructed at a cost of $540 million by Electric of Vietnam (EVN). Located approximately 65 km northeast of Hanoi, Pha Lai 2 and the adjacent Pha Lai 1 power station (a Russian-built facility with eight 220 t/h coal-fired boilers and four 110 MW turbines) are owned and operated by a wholly owned EVN subsidiary, Pha Lai Thermo Power Joint Stock Company. (PPC). It is estimated that the two power stations supply approximately 80% of Hanois power. In accordance with the Ministry of Industrys master plan, no more than 20% of their power is allotted to private power companies, and the remainder goes to EVN.

    In 2002, Yokogawa successfully designed, installed, and commissioned a CENTUM CS 3000 distributed control system (DCS) for the Pha Lai 2 power station, and it has operated to date without any significant problems. Along with the Yokogawa DCS, a full replica plant simulator was installed to provide plant operator training. The DCS and all related systems are maintained by Yokogawa Vietnam under the terms of an annual maintenance contract.

    Central control room

    Steam turbine unit 1

    Unit 1 overview graphic display

    Station staff training on the simulator

    Unit 1 air and flue gas overview graphic display

  • Power

    design in detail. As a result, no one completely understood the actual workings of the plant.

    However, the Mongolian government had an urgent need to rehabilitate this large plant and thereby secure this major lifeline for its people. The customers specific requirements were as follows:1. Full automation of the boilers, burners, and balance of plant facilities2. Change from an analog control system to a modern digital control system 3. Use of a power plant simulator to train operators and achieve a smooth transition to screen-based operations.

    The ChallengesThe original combustion system used indirect firing, with pulverized coal being transferred from a storage silo whenever the boiler was started up. With the exception of feed water control, all the boilers and mill burners were manually controlled by operators. There were many equipment problems and a high risk of explosions, and combustion was extremely low.

    In addition, there were just a few of the original blueprints dating back to when the plant was built in the 1980s, and none showed the boiler

    Executive SummaryIn Mongolia, temperatures fall as low as -40 in mid-winter. The heat and electricity generated by Thermal Power Plant No. 4 (TES4) in the capital city of Ulaanbaatar is an important lifeline for the people living there. This is the largest coal fired power plant in Mongolia and it generates 70% of the electricity for Mongolias central energy system and 65% of the heat energy used by the Ulaanbaatar district heating system.

    TES4 was built many years ago and has been severely affected by the scarcity of spare parts for its legacy systems. Plant shutdowns were a frequent occurrence due to equipment malfunctions and accidents, disrupting the supply of heat and power. In addition, the plant caused severe air pollution due to inefficient control of coal combustion. Efforts to correct these problems were also hampered by the loss of many of the plants original blueprints and other design related documents.

    To solve these problems, the Mongolian government decided to execute a plant revamping project in two phases using an official development assistance (ODA) loan. Phase one for boilers one to four started in 1998 and was completed in 2001. Phase two for boilers five to eight started in 2001 and was completed in 2007. For this project, Yokogawa delivered control systems and field instrumentation for all eight boilers.

    The SolutionsFirst of all, information had to be gathered that would provide a starting point for the automation design. This was followed by conversion to a direct firing boiler combustion system in which pulverized coal is directly loaded into the boilers and the replacement of the old mill burner control systems with a Yokogawa DCS.

    Automation of boilers, burners, and balance of plant facilities and changeover to a new boiler combustion systemTo meet the customers requirements for changing the old indirect combustion system to a direct combustion system, a Yokogawa project team of Russian, English, Mongolian, and Japanese speakers conducted a detailed investigation of the original boiler combustion control system and coordinated its activities with a new burner vendor. They had to crawl around every nook and cranny of this plant to create a piping & instrument diagram (P&ID) and a cabling drawing that accurately described the plant configuration. This was dirty and challenging work and it took many days to complete. Finally they succeeded in bringing together the documentation needed to design the automation for the plants boilers, burners, and balance of plant facilities and change to a direct firing boiler combustion system.

    Replacement of conventional analog control system with state-of-the-art digital control systemWith the completion of both phases of this project, the control of all eight boilers has been integrated with a Yokogawa CENTUM CS 3000 DCS. The operator stations were changed over from conventional analog panels to a modern graphical user interface, and this has improved the efficiency and safety of plant operations. In addition, a Yokogawa Exaquantum Plant Information Management System was installed to enable remote monitoring of all boiler operations from the administration building, which contributes to correct and prompt plant operation management. As for the system architecture, a redundant remote optical network was used for the I/O system to reduce the cabling cost and improve safety and reliability.

    Power plant simulator improves skills and eases transition to screen-based operationsTogether with a state-of-art DCS, a power plant simulator was provided that operators can use to upgrade their skills. This made possible a smooth transition from the conventional analog control panels to an all-new graphical user interface.

    The 4th Thermal Power Plant

    Mongolia

    Modernization of Large Thermal Power Plant Maintains a Key Lifeline for the People of Mongolia

    7 8

    Plant InformationPlant name: Thermal Power Plant No. 4 (TES4)Location: Ulaanbaatar, MongoliaProject type: ModernizationPlant type: Coal-fired power plantOutput: 580 MW (1 x 80 MW and 5 x 100 MW) 8 x 420 t/hOrder date: 1996 (Phase one), 2002 (Phase two)Completion: 2001 (Phase one), 2007 (Phase two)

    TES4 in winter TES4, lifeline for Mongolia New central control room

    Old plant drawing

    Original boiler control panel

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    The 4th Thermal Power Plant

    Mongolia9 10

    13.9

    10.3

    7.3

    4.8 4.8 4.84.0

    3.9

    2.8

    1.9 1.7

    0

    4

    8

    12

    16

    Kilo

    ton

    1997

    1998

    1999

    2000

    2001

    2002

    2003

    2004

    2005

    2006

    2007 Year

    276

    222

    205

    127

    82

    102

    6347

    6964

    37

    0

    50

    100

    150

    200

    250

    300

    1997

    1998

    1999

    2000

    2001

    2002

    2003

    2004

    2005

    2006

    2007

    Year

    87% reduction From 1997 to 2007

    88% reduction From 1997 to 2007

    ResultsReduction of boiler trips and accidentsOne by one, the eight boilers were changed over to the new control system and resumed operation, starting at the end of 1998. Reliability and safety have both been dramatically improved as a result of a steady decline in the number of boiler trips and accidents. With production up and oil consumption down, it has been possible to significantly reduce energy imports from Russia.

    Reduction of CO2 emissions through improved combustion efficiencyWith the reduction of boiler trips and plant accidents, boiler combustion efficiency has been dramatically improved. In addition to ensuring a stable supply of heat and electricity to the city of Ulaanbaatar, this has made it possible to generate more electricity from the same amount of coal. The amount of oil consumed for plant restarts has also been decreased, further reducing CO2 emissions.

    Technical transfer to TES4The Yokogawa project team worked together with TES4s engineers from start to finish of this project, providing them the opportunity to improve their skills in such areas as engineering design and commissioning. A number of the boiler control systems were successfully replaced by the TES4 engineers. This transfer of power plant engineering expertise was one of the main aims of this ODA project, and this ensures that the skills and know-how are in place to sustain operations at this plant.

    Customer SatisfactionMore than a year after phase one was fully completed, one of the four boilers caused a trip. Yokogawa dispatched engineers immediately and made every effort to solve the problem. The investigation found that the boiler trip was caused by a malfunction in one of the conventional components left over the old plant control system. Even though a Yokogawa product was not at fault, the companys engineers provided the TES4 engineers the support they needed to get the plant safely operating again.

    Mr. Tseveen, Executive Director of TES4, says, Seeing is believing. Whatever beautiful things sales people say, I will not believe until I see them at work. When we experienced the plant trip, I learned what makes Yokogawa different from others. I admire their sincerity and devotion toward customers.

    Number of hot start Heavy oil consumption (Kilo ton)

    Mr. TseveenExecutive Director of TES4

    Fuel consumption per electricity generation (g/kWh)

    g/kWh

    Fuel consumption per heat generation (g/kWh)

    kg/Gcal

  • 11 Power 12

    Plant InformationPlant name: Location: Project type: Plant type: Output: Order date: Completion:

    Executive SummaryMacquarie Generations Liddell Power Station is located near Muswellbrook, NSW, approximately 200km north of Sydney in the Hunter Valley. It comprises four coal-fired boiler steam turbine generator sets, each unit of 500MW capacity.

    The project consisted of the replacement of all existing process controls and monitoring and protection systems on each unit as well as the common station plant equipment. In addition, a substantial part of the field devices were replaced or new loops installed. Complete design and installation services were also included in the scope, and were provided by Yokogawa Australia in conjunction with alliance partner Downer-RML. An Exaquantum Process Information Management System was installed to handle the normal data history, comprising 20,000 tags per unit plus an additional 20,000 tags for the system common components, making a total of 100,000 tags for the complete system.

    The first unit controls were implemented in the new control system in 2002, followed by the common station plant controls. Thereafter, each subsequent unit will be installed progressively, culminating in final completion in 2004.

    The entire project is being conducted under an alliance contract, with the alliance partners comprising Macquarie Generation, Yokogawa Australia, and Downer-RML as the installation contractor. The alliance arrangement includes the concept of a target price which is the estimated cost price for completing the work, and which is agreed to by all partners after the completion of the up-front engineering specification. Payment is made by Macquarie to the alliance partners on the basis of how close the final cost is to the target price, and whether a set of Key Performance Indicators are met or exceeded.

    The CENTUM CS 3000 distributed control system controls all aspects of the project, including all associated plant units. Yokogawas Sydney and Melbourne offices joined forces on the pursuit of the project with the engineering being performed by the Sydney office.

    System DetailsSystem: CENTUM CS 3000Total I/O: approximately 30,000System Configuration: 12x HIS, 20x Screens, 2x EWSOther: Exaquantum Information Management systemScope: System, project management, design, configuration engineering, installation, commissioning services

    Macquarie Generation

    Australia

    Liddell Power Station revamped successfully Macquarie Generation

    11

    Plant InformationPlant name: Liddell Power StationLocation: New South Wales, AustraliaProject type: Plant revampingPlant type: Coal-fired power plantOutput: 4 x 500MW Order date: 2000Completion: 2004

  • 13 Power 14

    System DetailsOutput: 2 x 1,050 MWControl system for environmental control facilities: CENTUM CS

    Executive SummaryOne of Japans largest coal-fired power plants, with advanced environmental protection measures

    - Supplies electricity to a wide area in western Japan (Kansai, Chugoku, Shikoku, and Kyushu)- Has the largest coal-fired generation units in Japan, each with an output of 1,050 MW- Protects environment by removing NOx/SOx emissions and ash dust, and recycling fly ash- Integrated control and monitoring of the environmental facilities, supported by Yokogawas highly-reliable CENTUM system and state-of-art large displays

    BackgroundThe Tachibanawan Thermal Power Station is owned by Electric Power Development Co., Ltd. and is located in Anan City, Tokushima Prefecture. With two 1,050 MW generating units, it is one of the largest coal-fired power plants in Japan. The station entered commercial operation in 2000 and supplies electricity to a wide area in western Japan through four power utilities that serve the Kansai, Chugoku, Shikoku, and Kyushu regions.

    The plant is well known not only for its stable electricity supply but also its environmental protection measures. The plant layout was optimized to keep the site size to a minimum, and colors were selected that matched the scenic surroundings of the Seto Inland Sea area. Part of the fly ash from the combustion process is recycled to make cement. To prevent air pollution, state-of-art environmental control facilities such as Flue Gas Desulfurization (FGD) systems were installed, removing NOx, SOx and ash dust. In 2004 this plant received ISO14001 certification, demonstrating that its environmental protection measures meet international standards.

    The Challenges and the SolutionsIntegrated operation of large environmental control facilitiesThe environmental control facilities at this plant consist of FGD, electric precipitator, coal handling, ash handling, and waste water treatment systems. This large application with more than 30,000 data items is monitored and controlled by Yokogawas CENTUM CS integrated control system. With a remote I/O architecture that minimizes cabling, highly reliable dual-redundant fiber-optic cables, and communication links with plant auxiliary sub-systems, the CENTUM system achieves highly-reliable, single-architecture monitoring of all facilities.

    Mouse operation and large displaysFor safety and efficiency, plant operators can perform input with a mouse and monitor operations on two 100-inch displays. Yokogawa has optimized the operation of these large displays through the development of individual screens, frames, and alarm functions. For example, in an emergency, a guidance message pops up on a screen and easy-to-understand video/audio prompts enable operators to quickly verify associated systems and instruments. This customized operator interface helps to ensure that the plant operates smoothly and safely.

    Calculation system for environmental management systemFor the effective management of the FGD and waste water treatment facilities, a calculation system was embedded in the CENTUM control system. The system also includes an operation management function that reduces operating costs and extends equipment life, a forecast calculation function, and a reporting function. This supports highly-reliable and efficient management of the environmental control facilities.

    Since entering commercial operation in 2000, the environmental control facilities at the Tachibanawan Thermal Power Station have been managed effectively by the CENTUM control system, achieving a stable electricity supply with minimal impact on the environment.

    Control Solutions for Environmental Control Facilities Tachibanawan Thermal Power Station, Japan Tachibanawan Thermal Power Station

    Japan

    Plant InformationPlant name: Tachibanawan Thermal Power StationLocation: Tokushima, JapanProject type: NewPlant type: Flue gas desulfurizationOutput: 2 x 1,050 MW Order date: 1997Completion: 2000

  • Power 1615

    Itoigawa Power Plant

    System DetailsSystem: CENTUM CSTotal I/O: Aprox. 1,500System configuration: 4 x HIS, 1 x EWS, 4 x FCDScope: System, project management, design, configuration engineering, commissioning services

    Japan

    Flexible Control Solution for IPP Generation Facility with CFB Boiler

    Executive SummaryFlexible operation of circulating fluidized bed (CFB) facility by independent power producer (IPP)- 149 MW coal-fired power plant operated by IPP- First use of circulating fluidized bed (CFB) boiler by IPP in Japan- Fly ash recycled at adjacent cement plant- Daily operation in swing mode and shutdown/startup responding to shifts in electricity demand- Controlled by Yokogawas CENTUM system

    The Challenges and the ResultsFlexible response to shifts in electricity demandTo adjust to shifts in electricity demand, the customer runs the Itoigawa Power Plant in swing mode. During the daytime hours of high electricity demand, the plant is run at up to 100% of its capacity, with output being adjusted flexibly in response to commands from a central load dispatching center. At night the plant is operated at just 40% of its capacity.

    Automatic shutdown/startup capabilityYokogawa fully implemented the operation logic for its highly-reliable CENTUM CS control system to match frequent load changes and provide a high degree of flexibility in the systems operation.

    The CENTUM control system also supports automatic shutdown/startup to keep to a minimum the manual checks performed by operators. They are only required to check the master control sequence for stopping and starting the plant facilities, which ensures a safe, smooth shutdown and startup.

    Since commencing commercial operation in July 2001, the Itoigawa power plant has been operating reliably and efficiently under its Yokogawa CENTUM control system while employing CFB technology to generate environmentally friendly electricity.

    BackgroundThe Itoigawa Power Plant was constructed adjacent to a cement plant in Itoigawa City, Niigata Prefecture, and is operated by an IPP that supplies electricity to Tohoku Electric Power, one of Japans major power companies. The use of a 149 MW coal-fired CFB boiler in this power plant is a first for an IPP in Japan, and this effectively reduces NOx emissions. This power plant also recycles at an adjacent cement plant the fly ash that is the byproduct of coal combustion.

    Plant InformationPlant name: Itoigawa Power PlantLocation: Niigata, JapanProject type: NewPlant type: Circulating fluidized bed boilerOutput: 149 MW Order date: 1999Completion: 2000

    Daily operation example in swing mode

    Plant automatic sequence monitoring

    Control room

  • 17 Power 18

    System DetailsSystem: CENTUM CSTotal I/O: 43,410 (DIO: 37,300, AIO: 5,840)System configuration: 51 x FCS, 3 x EWS, 29 x operation monitors, 4 x alarm monitors, 2 x CCTV, 3 x sequence-of-events manager/visual annunciator systems, 2 x on-line performance monitoring systems, 3 x historian systems

    Executive SummaryThe Tuas Power Station and its associated facilities are located on reclaimed land along the western shore of Singapore. The station occupies an area of approximately 75 hectares and is being built in two stages.

    Stage I of Tuas Power Station is comprised of two 600 MW oil-fired steam-generating sets. The power station entered commercial operation in March 1999 when the first of these units was fully commissioned.

    As part of its work in stage I of this project, Yokogawa supplied the CENTUM CS integrated production control system (DCS) for the plants very large power generation units. Yokogawa Electric Asia Pte. Ltd., Singapore produced the control system in Singapore and carried out all engineering work.

    In addition to supplying Instrumentation & Control (I&C) equipment, Yokogawa handled system design/engineering, configuration, project management, commissioning services and maintenance.

    The Tuas Power Station successfully entered commercial operation on schedule and the plant owner has attributed this in part to Yokogawas good performance in delivering both products and services.

    The development of Stage II comprised of four-block combined cycle power plants was completed in September 2005, which brought the Station to its licensed capacity of 2,670 MW.

    Singapore

    Tuas Power StationSafe and Efficient Power Plant Operation

    Plant InformationPlant name: Tuas Power StationLocation: Tuas, SingaporeProject type: NewPlant type: Gas and oil fired power plantOutput: 1,200 MW (2 x 600 MW)Order date: July 1995Completion: March 1999

    A full-scope, high-fidelity training simulator supplied by Yokogawa enabled a simulator training in all aspects of operating complex plant systems and has made a significant contribution in raising the skill levels of the highly motivated Tuas Power Station workforce.

    Yokogawa also designed the Tuas Power Stations central control room (CCR), which has won praise from users for its good operating environment. Our CCR design methodology emphasizes the importance of sound ergonomic design in reducing operator errors and facilitating the smooth running and control of processes.

    Central control room designed by Yokogawa

    Replica simulator showcase

  • Power 20

    Korea South East Power Co., Ltd.

    Plant DetailsOwner: Korea South East Power Co., Ltd. (KOSEP)Output: 2 x 800 MWPlant efficiency: 43.5%Operation mode: Base load & cycle operation Fuel: Bituminous coalBoiler type: Supercritical pressure, once through, single reheatTurbine: Tandem compound, HP, IP, and LP turbine, single stage reheat, condensing typeGenerator: Cylindrical rotor, hydrogen and water cooled, three-phase synchronous generatorSimulator system: Yokogawa full-replica plant simulator (main computer + instructor system + DCS)

    Executive SummaryFaster, smoother plant commissioning The customer has successfully brought online a greenfield 800 MW supercritical power plant using a Yokogawa full-replica plant simulator to ensure a fast and smooth plant commissioning process.

    The full-replica plant simulator was used for: - Control system validation prior to DCS commissioning - Operator training

    Thorough Off-line Control ValidationThe simulator was delivered on-schedule to the site in September 2002, twelve months before the boiler was to be fired up for the first time. In collaboration with the DCS manufacturer and Yokogawa, the customer proceeded to test and validate the DCS configuration on the simulator, conducting an I/O checkout, drive checks, sequence checks, control module checks/tuning, alarm/trip setting, and DCS response checks as well as tests in which malfunctions and other abnormal situations were simulated. This enabled thorough validation of the control configuration prior to DCS installation at the site, thereby minimizing the final tuning work. A significant number of potential plant trips and incidents where there was potential for damage to the plant were identified and resolved before the initial plant startup, ensuring a safe and smooth plant commissioning process.

    The Challenges and the ResultsTo ensure that the commissioning process for its new plant went smoothly, KOSEP turned to Yokogawa and its TechComm Simulation subsidiary for a full-replica training simulator solution.

    The purpose of this full-replica training simulator was twofold:- To conduct a thorough, off-line test and validation of the DCS configuration prior to the control systems actual loading and commissioning at

    the plant. - To aid in the initial/refresher training of plant operators, which was conducted in parallel with the plant commissioning.

    To achieve these objectives, the simulator was required to fully stimulate DCS functions and emulate turbine, generator, and electrical control functions. Yokogawas full-replica simulator met the customers requirements with high accuracy (> 99% steady state; >95% dynamic state), calculation of models at less than 250msec per cycle, and the ability to perform performance tests and a wide variety of simulations including startups, shutdowns, and load changes under normal, abnormal, and emergency operating conditions.

    BackgroundIn Korea, steadily growing demand for electricity together with limited indigenous energy resources and a heightened environmental awareness have required additional power generation facilities with improved efficiency and environmental performance. Korea South East Power Co., Ltd. (KOSEP), a wholly owned subsidiary of the government-owned Korean Electric Power Company, constructed two new 800 MW supercritical coal-fired units in Yonghung, Korea to generate highly efficient, environmentally friendly electricity.

    800 MW Supercritical Coal-fired Power Plant Achieves Smooth and Rapid Plant Commissioning Using a Full-replica Plant Simulator

    Korea19

    Custom-made Operator trainingThe thorough control system validation on the simulator also provided a suitable training environment for plant operators. The simulator aided in the initial training for plant operators and refresher training for experienced operators under a wide variety of normal, abnormal, and emergency operating conditions. In parallel with DCS commissioning, KOSEP plant operators were well trained under the new control environment, reproducing custom-made flexible operating scenarios on the simulator. This avoided mistakes that could have occurred if the operator had not been familiar with the new system, thereby ensuring safe and smooth plant operation.The simulator also has the flexibility and expandability to accommodate future improvements in plant performance. The simulator continues to be an effective tool for the customer to optimize operational procedures and the plant logic/system.

    Plant InformationPlant name: Yonghung Thermal Power Plant (Units 1 & 2)Location: Yonghung, KoreaProject type: NewPlant type: Coal-fired power plantOutput: 2 x 800 MW (supercritical) Order date: 2001Completion: 2004

    Central control room

    Power plant simulator

  • 21 Power 22

    System DetailsSystem: CENTUM CS 3000/UOI (BBE) CENTUM CS 3000 (BBG)

    System configuration: 4 x operator stations(BBE) 1 x engineering workstation 2 x UOI (Cimplicity) servers 4 x field control stations 2,600 inputs/outputs 1,800 communication Signals

    System configuration: 1 x engineering stations (BBG) 6 x operator stations 4 x control stations 1,500 inputs/outputs 2,500 communication signals 1 x OPC Server

    Spain

    Bahia de Bizkaia Electricidad Bahia de Bizkaia Gas

    Combined Cycle Power Plant with Regasification Facility Realizes Stable Power Supply

    The Challenges and Results1. High availability (BBE and BBG)Both facilities aim to have high availability. The field-proven CENTUM CS 3000 distributed control system (DCS) ensures this by enabling the control and monitoring of the entire BBE power station. The BBG regasification facility is designed to operate 24 hours a day, 365 days a year without having to be shut down for maintenance. Yokogawas highly reliable CENTUM CS 3000 DCS offers a high degree of redundancy that contributes to the entire plants high availability.

    2. Unified operation of multivender control systems (BBE)At the BBE power station, General Electric Company gas and steam turbines have been installed and are controlled by the companys own turbine control system. The electrical equipment of the power station is controlled by another venders system. With its Unified Operator Interface (UOI), Yokogawas CENTUM CS 3000 enables the seamless operation of each of these control systems. With the UOI solution, all of the actions required for the operation, management, and maintenance of turbines, the heat recovery steam generator (HRSG), and the balance of plant and electrical controls can be carried out from a single operator interface. The UOI also eliminates the requirement for operators to master the operation of multiple systems.

    3. Flexible operation and reduced start-up time (BBE)The BBE power station is capable of working both at base load and at partial loads, which provides flexibility in the plant operation. In addition, to reduce the start-up time, 100-percent-flow by-passes were designed to start the gas turbine and the HRSG individually without starting up the steam turbine. The Yokogawa DCS for which the Spanish engineering company Siemsa Notre S.A. (SIEMSA) fully implemented the above operation logic has steadfastly supported the safe plant operation and smooth startup.

    Background of the Project In Spain, the demand for electricity and imported natural gas has been rapidly increasing, a trend that is anticipated to continue for years to come. To augment the countrys energy supply, several new LNG regasfication plants as well as combined cycle gas turbine plants have been constructed in Spain.

    Customer SatisfactionThe SIEMSA engineer commented, We appreciate CENTUM CS 3000s operationality and system reliability. With the UOI solution, the DCS controls use the same HMI system as the turbine and electrical control system, and there is no need for a dedicated communication gateway and separate screens. This significantly reduces the engineering time and costs.

    About the Bahia de Bizkaia Plant - BBE and BBG To achieve a stable supply of gas and electricity for the country, the Spanish government decided to build the Bahia de Bizkaia Plant. Located in Bilbao, this plant consists of Bahia de Bizkaia Electricidad (BBE), an 800 MW gas fired combined cycle power station, and Bahia de Bizkaia Gas (BBG), a regasification facility with regasificators having a total capacity of 2.7 billion cubic meters.

    The Bahia de Bizkaia Plant was one of the most significant power projects to be carried out in this region. The project was led and financed by Ente Vasco de la Energia, Repsol-YPF, British Petroleum, and Iberdrole S.A., with the total investment of approximately 600 million euros.

    Plant InformationPlant name: BBE & BBG PlantsLocation: Bilbao, SpainProject type: NewPlant type: Combined cycle power plantOutput: 800 MWOrder date: 2001Completion: 2003

  • Power

    About the ProjectThe Bucurresti Vest Combined Cycle Heat and Power Plant (CCHP) is located in the Romanian capital of Bucharest and supplies both electricity and heat to this city. Sited next to two existing 125 MW plants, it was built to meet Romanias rising demand for electric power.

    The owner of the plant is SC Electrocentrale Bucureti SA (ELCEN), a major energy supplier in Romania that accounts for approximately 20% of the nations power generation capacity. ELCENs thermal power plants generate over 2 gigawatts (GW) of electricity, of which 1 GW is supplied directly to the city of Bucharest.

    The Bucuresti Vest CCHP consists of a GE 9E gas turbine that generates up to 135 MW, a heat recovery steam generator (HRSG) manufactured by Austrian Energy and Environment, and a SKODA steam turbine that generates up to 60 MW.

    The main contractor for this plant construction project was the Combined Cycle Division of VA Tech Hydro AG (integrated into the Andritz Group in 2006). VA Tech Hydros scope of supply included the complete electrical systems and instrumentation and control, all auxiliary plant units such as gas supply, and all structural engineering. Yokogawa provided the CENTUM CS 3000/UOI distributed control system (DCS), ProSafe-RS Safety Instrumented System, and the Exaquantum Plant Information Management System, as well as engineering, installation, commissioning, and operator training services.

    The project was executed in a professional manner. The construction period was kept short less than 30 months net to facilitate a rapid return on investment.

    Yokogawas state-of-theart plant control system contributes significantly to high degree of plant automation and plant reliability.

    CENTUM CS 3000 R3/UOI Improves Reliability and Efficiency by Integrating Systems Controls at Bucuresti Vest Power Plant

    Customer SatisfactionVA Tech Hydro chose Yokogawas automation system for this project because of the demonstrated capabilities of the CENTUM CS 3000 control system in power plant applications and its compliance with the relevant VGB guidelines. An additional factor leading to this decision was this systems use of redundant Profibus cards in keeping with the Profibus decentralized periphery (DP) concept and its support of IEC60870 communication profiles.

    The design and structure of the CENTUM CS 3000 DCS for this new power plant met this customers high expectations in terms of availability and operational reliability.

    At the operator desk in front of the HMI operator station, the merits of Yokogawas UOI solution become obvious:

    - It's easy to navigate through the power plant control and turbine control processes as both are represented in a similar manner and run on the same visualization platform. The process graphics that were prepared for this project are excellent overall, with well structured and detailed process overview and operator displays.

    - The Consolidated Alarm List software helps operators quickly identify cause and effect relationships in power plant and turbine control.

    Romania

    SC Electrocentrale Bucuresti SA

    System DetailsControl systems: CENTUM CS 3000/UOI, ProSafe-RSNumber of I/O points: 6,900 (1,300 hard wired, 3,600 via Profibus, 2,000 via other bus protocols)System configuration: 4 UOI viewers, 2 engineering stations, 2 UOI servers, 1 Exaquantum server, 1 SOE server, 1 IEC server, 4 50 plasma screens, 8 FCS, 1 safety control station (SCS)

    23 24

    The Solutions1. Single Operator InterfaceThe CENTUM CS 3000/UOI provides a single operator interface for the operation, management, and maintenance of the plants turbines, HRSG, balance of plant (BOP) facilities, and electrical systems.Yokogawas unified operator interface (UOI) makes this possible. It was developed by Yokogawa to provide a common control platform for the CENTUM DCS and the GE Mark VI gas turbine control system. All data from the GE Mark VI turbine control system, Siemens Simatic steam turbine control system, and other plant systems can be accessed from the CENTUM CS 3000/UOI. No gateway is required.

    The Bucureti Vest CCHP is operated and monitored from four operator stations that are located in the central control room and provide access to more than 90 process graphics. Each of these stations has four monitors that can display four separate graphics. In addition, there are four 50 operator displays.

    The turbine graphics and other system graphics are shown right. With these graphics at the CENTUM CS 3000/UOI stations, operators can monitor and control all the plants different systems with the same look and feel.

    2. Automatic Plant Start-up and Shutdown For the new CCHP, Yokogawa configured block sequences for automatic plant start-up and shutdown. The heating plant units that supply up to 190 MW of thermal energy to Bucharests district heating network were also automated to ensure a high degree of flexibility in responding to fluctuations in demand.

    The power plant can be operated in an accentuated electrical mode or in an accentuated thermal mode that requires the calculation of complex mathematical equations. This computation can be handled by the DCS field control station (FCS) and does not need to be outsourced via OPC or other means.

    3. Advanced Alarm Management Alarm management at this power plant is done with Yokogawas Consolidated Alarm List software. This manages both DCS and turbine controller alarms as well as alarms from subsidiary controllers and safety systems, using the sequence of events (SOE) signals to timestamp these events with millisecond accuracy.

    ata Highway for Mark VI Control Bus (Vnet IP)

    CENTUM CS3000 FCS(s)(for HRSG)

    CENTUM CS3000 FCS(s)(for BOP)

    UOI Server(s)(CIMPLICITYServer)

    CENTUM CS3000 Builder PC

    Siemens S7(for Steam Turbine)

    Mark VI(for Gas Turbine)

    Configuration PC

    Unified Operator Interface (UOI)Unified Operator Interface (UOI)

    UOI UOIUOIUOI UOI

    Ethernet

    Data/Message fromHRSG/BOP Project

    Data/Message fromTurbine Project

    CIMPLICITY Servers

    Turbine Control by General Electric Company

    Turbine Control by General Electric Company

    HRSG/BOP and Safety Controlby Yokogawa

    HRSG/BOP and Safety Controlby Yokogawa

    UOI viewers(CIMPLICITY)

    ProSafe RSSCS(s)(for safety)

    ata Highway foff r Markk VI

    Siemens S7(foff r Steam Turbineee))))

    Mark VIGas Turbinnnee))))

    tionPC

    CIMPLICITYTTServers

    Unit Data Highway for Mark VI Control Bus (Vnet IP)

    CENTUM CS3000 FCS(s)(for HRSG)

    CENTUM CS3000 FCS(s)(for BOP)

    UOI Server(s)(CIMPLICITYServer)

    CENTUM CS3000 Builder PC

    Siemens S7(for Steam Turbine)

    Mark VI(for Gas Turbine)

    Configuration PC

    Unified Operator Interface (UOI)Unified Operator Interfaff ce (UOI)Unified Operator Interface (UOI)

    UOIUOI UOIUOIUOIUOIUOIUOI UOIUOI

    Ethernet

    Data/Message fromHRSG/BOP Project

    Data/Message fromTurbine Project

    Data/Message fromHRSG/BOP Project

    Data/Message fromTurbine Project

    CIMPLICITY Servers

    Turbine Control by General Electric Company

    Turbine Control byGeneral Electric Company

    TTTuuuuurrrrrbbbbbiiinnnnneeeee CCCooooonnnnntttttrrrrrooooolll bbbyyyyyGGGeeeeennnnneeeeerrrrraaaaalll EEEllleeeeeccccctttttrrrrriiiccccc CCCooooommmmmpppppaaaaannnnnyyyyy

    Turbine Control by General Electric Company

    HRSG/BOP and Safety Controlby Yokogawa

    HRSG/BOP and Safef ty Controlby Yokogawa

    HHHRRRRRSSSSSGGGGG/////BBBBBOOOOOPPPPP aaannnnnddddd SSSaaaaafffffeeffff eeettffee tttyyyyy CCCooooonnnnntttttrrrrrooooolllbbbyyyyy YYYYYoooookkkkkooooogggggaaaaawwwwwaaaaa

    HRSG/BOP and Safety Controlby Yokogawa

    UOI viewers(CIMPLICITY)

    ProSafe RSSCS(s)(for safety)

    Plant InformationPlant name: Bucuresti Vest Combined Cycle Heat and Power Plant (CCHP)Location: Bucharest, RomaniaProject type: ModernizationPlant type: Coal-firedOutput: 186 MW (electrical), 197 MW (thermal)Order date: May 2005Completion: March 2009

    (Electrical plant overview) (Condensate system)

    (Gas turbine startup) (Steam turbine by-pass control)

  • 25 Power 26

    Monthly electricity demand

    Customer SatisfactionAccording to the Plant Manager, The system allows operators to clearly see the plants status and know what is going on. With this information, our operators can take quick action whenever there is a problem with a gas or steam turbine or with an HRSG. When there is a problem with the transmission lines or some other part of the national grid, the plant is immediately put into island mode and provides electricity only to its local customers. We are very pleased with the performance of Yokogawas CENTUM CS 3000 at our power plant.

    Plant DetailsGas turbine: 2 x 40 MW, GEHRSG: 2, AlstomSteam turbine: 60 MW, Alstom System DetailsDistributed control system: CENTUM CS 3000 Total I/O: 1,500 Field devices: Yokogawa pH meters, conductivity meters

    The Challenges and the Solutions1. Highly efficient operationThe national grid operated by EGAT needs a steady supply of electricity at all times, and the same is true for the Rayong Industrial Park. The CENTUM CS 3000 plays a core role by controlling and enabling the monitoring of all processes at the EGCO Cogen plant.The gas and steam turbine control systems as well as the PLCs controlling the water treatment and chemical injection facilities are all integrated with the CS 3000 system through a Modbus interface. The CS 3000 system has access to both horizontally and vertically integrated data from throughout the plant, allowing EGCO Cogen to calculate the efficiency of each gas and steam turbine as well as each of the HRSGs in real time.Operators have constant access to plant performance data and a daily report showing the hourly base performance figures can be printed out. The performance data is utilized to plan maintenance and improve control strategy. Currently, the plants overall efficiency is about 60%.

    2. Steady and safe operationBased on monthly requests from EGAT, EGCO Cogen supplies a steady flow of electricity to the national grid. EGCO Cogen also supplies load of 40 MW to the Rayong Industrial Park. To meet these requirements under a variety of circumstances, the CS 3000 system has the following control functions:2-1) Automatic start-up and shutdown sequences2-2) Automatic load sharing and plant optimization2-3) Load shedding control2-4) Voltage and power factor control2-5) Island operation when disconnected from the national grid2-6) Plant performance monitoring

    Each operator workstation has function keys that allow quick access to a target process from the plant overview graphic display. With certain sequences, clear and easy-to-understand operation procedures are displayed. Operators thus have all the information needed to take quick and timely action whenever needed, making this a very safe plant.

    Executive SummaryThe Electricity Generating Public Company Limited (EGCO) was the first independent power producer (IPP) to be established in Thailand as the result of an initiative by that countrys government to allow broader private sector investment in the power sector. EGCO was incorporated on May 12, 1992 by the Electricity Generating Authority of Thailand (EGAT), and over the next three years it became a public company and was listed on the Stock Exchange of Thailand (SET). Operating as a holding company, it invests in power generation and supply and provides comprehensive operation, maintenance, engineering, and construction services to the power industry and other industries in Thailand as well as other countries. Furthermore, the company searches for good growth opportunities that are related to its core energy business.

    EGCO Cogeneration Co., Ltd, an EGCO Group company, operates a combined cycle power generation plant at the Rayong Industrial Park. The plant uses natural gas from PTT to power gas turbines that generate electricity. Heat recovery steam generators (HRSG) use waste heat from the turbines to produce steam for a steam turbine that generates additional electricity. Sixty percent of the generated electricity goes to the national grid (EGAT) and the remaining 40% is utilized by companies at the Rayong Industrial Park.

    To control these processes at the EGCO Cogen power plant, Yokogawa Thailand installed a CENTUM CS 3000 process control system in 2002. This facility has operated without any major system failures since then.

    Thailand

    Fully Automated Power Plant Supplies Steady Flow of Electricity to Thai National Grid EGCO Cogeneration Co., Ltd.

    Plant InformationPlant name: Cogeneration plant Location: Rayong, ThailandProject type: NewPlant type: Combined cycle cogenerationOutput: 140 MW (2x 40 MW electrical and 1 x 60 MW electrical)Order date: 2000Completion: 2002

    Central control room

    HRSG graphic display

    Plant performance screen

    EGCO Cogen operators

    Main process overview

  • 27 Power 28

    The Challenges and the Solutions1. Steady power supplyWith 90% of this plants generated power going to the Thai National Grid, which is owned and operated by the Electricity Generating Authority of Thailand (EGAT), it is vital for the production control system to be highly reliable. EGAT sends a power demand pattern every month (see the right figure) to the power station and it must generate electricity accordingly. With an availability that exceeds 99.99999%, Yokogawas CENTUM CS 3000 system has been key to meeting this requirement.

    2. Operational data visualization for safe operationThe Yokogawa CENTUM CS 3000 controls and monitors the plants HRSG units and its balance of plant (BOP) facilities. Other vendors systems such as the gas turbine and steam turbine control systems are all integrated through Modbus interfaces with the CENTUM CS 3000 system, so almost all plant data can be viewed at the CENTUM CS 3000 human machine interface (HMI) stations. Operators can clearly see in real time the status of the compressors and all other equipment throughout the plant, and thus have the information they need to take quick and effective action when necessary. This data is also used to facilitate equipment diagnosis so that engineers can schedule maintenance at the most appropriate time and ensure safe operation.

    3. Sustainable power generationThe replacement of this plants legacy control system has enhanced performance in a number of ways. This includes steady improvement in the heat rate (BTU/kWh), as the graph in the lower left shows.

    Signals from a variety of analyzers are also monitored by the CENTUM system to control emissions. The continuous measurement of CO and O2 concentrations allows operators at this power plant to fine tune the air-fuel ratio and thereby boost combustion efficiency and reduce NOx emissions.

    Executive SummaryA 126 MW gas fired cogeneration power plant built by Thailands Samutprakarn Cogeneration Co., Ltd. began generating electricity on August 23, 1999. Ninety MW of its output is supplied to the Thai National Grid, with the remainder going to local companies. The plant operates 24 hours a day, seven days a week, and is shut down for 35 days once a year for maintenance. A major overhaul is done every six years. For improved efficiency, this power plant was designed to have more than one thermodynamic cycle, and uses both gas and steam turbines. Two GE gas turbines burn fuel to produce heat energy and generate electricity, and the waste heat is used to produce steam that passes through an Alstom steam turbine to generate additional electricity.

    The gas fuel for this plant comes from a PTT gas separation plant, which receives gas via an undersea pipeline from wells in the Gulf of Thailand. The plants boilers utilize heat recovery steam generators (HRSG) with a capacity of 80 t/h (max.120 t/h) and a maximum allowable steam pressure of 65 bar. The steam temperature is 500 degrees Celsius.

    The decision by Samutprakarn Cogeneration to upgrade this plants legacy distributed control system was made because it was proving difficult to procure spare parts from the system vendor. Yokogawa Thailand successfully installed the CENTUM CS 3000 system on schedule and on budget.

    Thailand

    Replacement of Legacy System with CENTUM CS 3000Ensures Steady Supply of Electricity to Thai National Grid Samutprakarn Cogeneration Co., Ltd.

    Customer SatisfactionKitpoat Srasomsub, Maintenance Manager, had the following to say about the plants new control system: We have been very happy with Yokogawas CENTUM CS 3000 since introducing it in 2007. The system is very reliable and there have been no major problems with it. We have the important mission of providing a steady supply of electricity to both the EGAT national grid and local companies 24 hours a day, seven days a week, throughout the year. We are always striving to improve efficiency and reduce emissions through the visualization of all plant data.

    Plant InformationPlant name: Samutprakarn Cogeneration PlantLocation: Samutprakarn, ThailandProject type: Control system revampingPlant type: Gas fired cogeneration power plantOutput: 126 MWOrder date: 2005Completion: 2007

    Central control room

    Mr. Srasomsub

    Power generation overview

  • Power 3029

    Australian Gas Light Company

    System DetailsSystem: CENTUM CS 3000/UOI

    Scope: (Hallett) Interface to GE SPEEDTRONIC Mark V turbine controllers Balance of plant (BOP) control Interface to ALSTOM SCADA Interface to electricity market network for load dispatch

    Scope: (Somerton) Interface to Triconex turbine controllers Balance of plant (BOP) control Interface to electricity market network for load (NEMMCO) dispatch

    The SolutionIn these projects for AGL, Yokogawa Australia cooperated closely with the Groups Singapore factory to develop and deliver a fully engineered control system on specification and on schedule.

    For its Hallett and Somerton plants, AGL selected Yokogawas CENTUM CS 3000 together with its Unified Operator Interface (UOI). The system platform in the UOI is the GE Fanuc CIMPLICITY Human Machine Interface (HMI) system, which fully integrates the controllers for the turbine and balance of plant (BOP) auxiliaries and uses the same screens/formats in both the turbine and BOP HMI displays. The CIMPLICITY HMI used in the UOI is a SCADA based design that fully supports AGLs requirement for remote operation capability. For the Hallett plant, AGL also introduced an automatic turbine optimizer. This embedded system automatically schedules and selects turbines to flexibly meet peaking market demands.

    Australia

    Unified Operator Interface Enables Remote Operation AGL Hallett & Somerton Power Stations, Australia

    Executive SummaryThe Australian Gas Light Company (AGL) was established by private interests in New South Wales in 1837 to light the streets of Sydney with coal gas. Today, AGL is Australias leading energy provider. AGLs wholesale and retail marketing businesses sell natural gas, electricity, and associated products and services.

    Electricity consumption is growing rapidly in southern Australia. In response to growing summer demand in South Australia, AGL built a power station in 2001 in Hallett, South Australia, and completed construction of another power station the following year in Somerton, Victoria. Both are peak power plants that help reduce the likelihood of power blackouts and keep electricity prices stable during periods of peak demand.

    The ChallengeTo respond to these pressing needs, AGL required the following:

    Remote control and operation

    The 12 gas turbines in the Hallett plant and the 4 gas turbines in the Somerton plant needed to be remotely controlled from an existing control center in Melbourne.

    Fast-track construction

    Each plant construction project was placed on a fast-track three-month completion schedule so that they could be operational by the summer of 2002. All system equipment had to be delivered and installed within this timeframe.

    Flexible operation

    The turbine control system had to have the capability to flexibly meet the intermittent power needs of a peaking power station.

    Plant InformationPlant name: AGL Hallett and Somerton Power StationsLocation: South Australia (Hallett) and Victoria (Somerton), AustraliaProject type: NewPlant type: Gas turbineOutput: 200 MW (Hallett) 150 MW (4 x 37 MW) (Somerton) Order date: 2001Completion: 2002

    Remote control and operation

    CENTUM CS 3000/UOI

  • 31 Power 32

    System DetailsDCS: CENTUM CS 3000Total I/O: Approximately 2000System configuration: Dual LCD operator stations, engineering work stations with virtual test function, field controllers, I/O with HART, sequence of events I/OScope: Distributed control system including control system software, factory acceptance, commissioning assistance

    Predicted reliability being achievedThe Honourable Donna Camsfield, Minister of Energy, at the Cogen Plant opening on Dec.2, 2005, said in part, Todays plant opening is another step in Ontarios cogenerational potential and another example of the Greater Toronto Airport Authoritys significant record of environmental leadership. She cited benefits of cogeneration to include: Adds more capacity added to the power grid Produces high combined fuel efficiency Helps control industry costs mitigates electricity cost increases Improves transmission and system reliability Helps replace coal thus creating a cleaner environment Increases the number of facilities that recover quickly or even continue to operate in the event of power interruption.

    Comments by those associated with the plant and echoed by other industry and government groups visiting the Toronto facility about two such tours per month since installation attest to the central focus of system reliability. The GTAA facility and its Yokogawa control system qualify on all counts.

    BackgroundCanadas Toronto Pearson International Airport, along with millions of people in Eastern Canada and eight US states, suffered a severe electrical power outage in 2003. This catastrophic failure made it painfully apparent that the airport neededa reliable, independent source of electricity. Round-the-clock reliability was simply an absolute must, but the economics of such a system had also to be carefully considered.

    These two factors reliability and costs have now been met by a cogeneration power plant design using twin GELM6000PD aero-derivative gas turbines, each capable of producing 42 MW. Exhaust from the turbines passes through steam generators which run a third steam-driven generator capable of 33 MW output. Remaining plant heat can be used to heat/cool the airport buildings. Economics were addressed in this generous design to allow sale of excess power generated to the Ontario power grid. A Yokogawa CENTUM CS 3000 control system, selected after careful evaluation of system reliability for various vendors, completes the plant.

    Those involved with the Cogen plant have been very pleased with reliability of the Yokogawa control system, states Henry Oberhauser, Senior Manager, Utilities for Greater Toronto Airports Authority (GTAA). The only substantial system outage occurred due to sub-standard process water supplied by a sub-contractor. We feel Yokogawas claim of seven 9s reliability which translates to less than one minute of downtime in 40 years is well on its way to reality.

    1GTAA operates Pearson Airport, an international gateway with 65 airlines via 82 gates in three terminal buildings. A fourth terminal is currently beingdesigned. The airport generates $14-billion in annual revenues, $2.8-billion tax revenues and provides 135.000 jobs. It has 16,000 parking spaces.

    2SNC-Lavalin, one of the leading groups of engineering and construction companies in the world, has office across Canada and in thirty other countries. It is at work in over 100 countries.

    The PlantThe airport is owned by the GTAA1, which hired outside firms to help design, build, and operate the plant. The airport, by meeting the twin requirements of a coincident demand for electricity and thermal power along with access to fuel (natural gas), was an ideal candidate for a Cogeneration system. In early 2001, GTAA had constructed a Central Utility Plant for the airport; it replaced a legacy plant torn down as various airport facilities were being added. The plant supplied steam for heating and chilled water for cooling the airport terminals.This new plant can supply steam needs but also allows the optional operation of the plants steam boilers in standby mode while using steam from the Cogen system. The plant was constructed in 2003. A year later the Yokogawa control system was commissioned.

    An interesting facet of the design is the use of two once-through steam generators (OTSGs) supplied by Innovative SteamTechnologies (IST) of Cambridge, Ontario. These units offer several advantages over conventional designs. They are efficient,flexible and capable of full operation from cold starts within less than 30 minutes. They start, run and finish dry. Conventional-pass stacks, diverter valve systems and stack silencers are not needed.An OTSG is basically a heat exchanger composed of a series of tubes whose boiler water is simultaneously heated, evaporated and superheated. Heat recovered in the OTSG supplies the steam turbine at its required temperature and pressure.

    Yokogawa CENTUM CS 3000 control systemEncompassed by the Yokogawa monitoring and control system is the entire Cogen plant including the two OTSGs. Startup, operation and shutdown of the OTSGs is fully automatic. The complex logic involved was developed by close cooperation of Yokogawa, IST and SNC-Lavalin2

    engineers.

    Not shown but also in the control room is an engineering station. It allows access to technical drawings and related information such as applicable codes and standards and other engineering information. It includes a system simulator used in operator training and to examine and test changes in the CS-3000 logic. This logic can be modified through this station. A HART plug-in allows diagnostics for HART I/O. Naturally, access to the station is fully protected and limited to only the plants certified engineers.

    A monthly printout both tabular and graphical by a companion J.D. Edwards software package, using selected inputs from the Yokogawa files, provides maintenance guidance. Since installation of the Yokogawa system, no major maintenance has been required.

    Steve Sadecki in the Cogen Plant control room with multiple flat-screen displays. Control is provided for plant balance and unit operations. Monitors provide rapid and complete displays of all system assets. Says Sadecki, The display formats are very well thought out and extremely operator friendly. It took me, and fellow operators, less than a week of training to be completely familiar and comfortable with the system even though none of us had previous experience withYokogawa equipment.Steam fed to the OTSGs must be of ultra-high quality. Steam monitoring and water purification control is included in the CENTUM system.

    Canada

    Greater Toronto Airports AuthorityToronto Airport Cogen Plant Focuses on Reliability

    Plant InformationPlant name: Cogeneration plant at Pearson International AirportLocation: Toronto, ON, CanadaProject type: Control system revampingPlant type: Gas fired cogeneration plantOutput: 117 MW (2 x 42 MW electrical, 1 x 33 MW thermal)Order date: 2004Completion: 2005

  • 33 Power 34

    Customer SatisfactionSeree La-Ongutai, acting general manager, said, We are producing electricity and steam for the whole airport terminal, adjacent hotel and Thai Airways facilities. It is very hot in Thailand all through the year, so the airport always needs a stable utility. We very much appreciate the reliability of Yokogawas CENTUM CS 3000, which is the cooling of all our airport facilities here. So far the plant has operated with great stability, availability and safety, and I believe this is due in good part to the integration of the systems sequence logic functions and the dynamic graphic displays on the human machine interface (HMI). We are striving to save energy in the whole facility, so we would like to work together with Yokogawa for continuous improvement.

    Plant Details- Gas turbines: 2 x 41MW, IHI- HRSG: CMI- Steam turbines: 12 MW, Shin Nippon- Steam absorption chillers: 21,000 refrigerant tons- Electric chillers: 12,480 refrigerant tons- Steam generation: 126 t/h- Steam temperature: 430 deg C- Steam pressure: 60 bar

    Systems Delivered- Distributed control system: CENTUM CS 3000 - Total I/O: 1841- Field devices: Yokogawa magnetic flowmeters

    The Challenges and the Solutions1. Steady and safe supply of power and steamDCAPs mission is to ensure a steady supply of electricity and steam to the airport terminal, a hotel nearby, and a Thai Airways catering facility. The steam is supplied to steam absorption chillers at east and west of the airport terminals that drive the cooling systems at the airport complex and the airline catering facilities. The airport receives power over a main line from the DCAP power plant and a line from the Metropolitan Electricity Authority (MEA). There are four operation modes to meet any cases for power requirement and steam requirement situations. Full operation including steam chillers Half operation including steam chillers Half block + steam chiller operation Aux. boiler + steam chiller operation

    The operation procedures carefully configured in the CENTUM CS 3000 ensure smooth transfers between these modes. Regarding gas and steam turbine control, the turbine suppliers installed the respective controllers; however, they receive major settings from the CENTUM CS 3000 via a Modbus interface as master setpoints and all process data in the turbine systems can also be monitored by the CENTUM CS 3000. Safe and steady supply of electricity to, and air conditioning at, the entire airport complex is thus assured all year round.

    2. Environmentally optimized operationsNatural gas supplied by PTT Public Co., Ltd. powers DCAPs main gas turbines and auxiliary boilers. Even though natural gas is low in emissions, the CENTUM CS 3000 system tracks and displays the relevant process data. The data are linked to a continuous emissions monitoring system (CEMS) through a plant network that is connected to the governments systems. Data on NOx, SO2, CO, O2, and opacity are sent twice a day. The water used in this plant is also carefully monitored and controlled to keep it within recommended limits.

    Executive SummaryDistrict Cooling System and Power Plant Co., Ltd. (DCAP) operates a power plant near Bangkoks Suvarnabhumi International Airport that supplies electricity and steam to the Bangkok International airport main terminal, a hotel nearby and a Thai Airways catering facility. The DCAP plant has two 41 MW gas turbines, two heat recovery steam generators (HRSG, 63 t/h each), and one 12 MW steam turbine. In average, 50 MW electricity is transferred to the Airport of Thailand (AOT), 30 MW is selling to the national grid (EGAT)and total left MW is utilized in this DCAP power plant. The steam is sent to 10 steam absorption chillers located at the airports main terminal, east and west, about 2 km away from DCAP facility .

    To be a steady supply of electricity and steam to Suvarnabhumi International Airport, which operates 24 hours a day / 365 days around a year, is most important issue for DCAP. Yokogawa Thailand successfully installed a CENTUM CS 3000 distributed control system, field transmitters and magnetic flowmeters. The facility is in operation without any problem since 2004.

    Thailand

    CENTUM CS 3000 Ensures Stable Supply of Electricity and Steam to Bangkoks Suvarnabhumi Airport District Cooling System and Power Plant Co., Ltd.

    Plant InformationPlant name: District cooling system and power plant at Bangkok's Surarnabhumi airport Location: Samutprakarn, ThailandProject type: NewPlant type: Combined cycle cogenerationOutput: 94 MW (2 x 41 MW electrical, 1 x 12 MW thermal)Order date: 2002Completion: 2004

    Central control room

    Plant overview

    Chiller overview

    Process overview

    Continuous emissions monitoring system

  • 35 Power 36

    Kraftszer Kft

    Hungary

    About the ProjectThe plant is located at Fredi t in Budapest. The main contractor is Kraftszer Kft., a Hungarian engineering company that has built a number of CHP plants, and the plant will be operated by Zugl-Therm Energiaszolgltat Kft.

    The Fredi power plant consists of three (3) Wrstil 18V34SG gas engines rated for an electrical output of 18 MWe, three (3) heat exchangers for each engine that supply the hot water for the district heating system, and auxiliary systems for such functions as fuel and air supply. Natural gas is the main fuel for the power plant.

    The hot water is distributed by Ftv Rt., the main district heating utility in Budapest.

    Although the emphasis is on the supply of hot water for district heating, the generated electricity is also supplied to approximately 20,000 households on the public power grid. In Hungary this kind of CHP plant is required to have a minimum total efficiency of 65% per month and 75% per year.

    Customized STARDOM & FAST/TOOLS Plant Management Solution Helps Fredi CHP, Hungary Operate Optimally

    System DetailsControl system: STARDOM FCN and FAST/TOOLS SCADA systemNumber of I/O points: 2,500Field instruments: EJA530A x 9, EJA110A x 13, EJA120 x 2, YTA70 x 2, non-Yokogawa products x 116, manometers x 100Installation: March 15, 2005Start-up: April 4, 2005Commissioning: April 20, 2005Training: May 15-16, 2006

    Executive SummaryThe Fredi Power Plant project is a showcase for the use of SCADA and STARDOM in a power sector application, and it posed certain unique operation and control requirements. A FAST/TOOLS SCADA system was seamlessly integrated with a STARDOM automation system, providing the information needed by power plant managers, operators, and maintenance personnel to efficiently monitor the plants operation and analyze its performance. A history database integrated into FAST/TOOLS collects and stores the measured and calculated parameters.

    The system covers approximately 16,000 items, collects data, creates shift/daily/weekly reports, and makes monthly calculations. The collected and calculated data is kept for the lifetime of the plant. Through this project, Zugl-Therm Energy Supply Ltd. has achieved the following:

    Easy set point definition for all plant power generation operations The heat produced by the entire plant and the electrical set points for the engines can be defined in an Excel file every 24 hours, with 15

    minute resolution, and this data can be easily exported into the FAST/TOOLS system.

    Stable electric power generation The superior control system can respond flexibly to changing heat demand, focusing on the operational conditions of the gas engines.

    Power plant optimization The control system supports on-line calculation of both plant and gas engine efficiency, enabling adjustments for optimal operation.

    Control of electric power generation based on net performance The control application in STARDOM can automatically calculate the in-house power consumption of the power plant. With this function, the

    plant can more accurately control the required amount of power to be supplied to the national grid operator.

    The Challenges and the Solutions1. Easy set point definition for all plant power generation operations

    The district heating set points are defined in Excel and sent to the district heating company. As shown below, the Excel data can be imported into FAST/TOOLS with just one mouse click. Plant operators can see the actual daily plant set points on screen.

    This system is used for the electrical set points as well. In this case the plant manager has to define the set points for each of the three gas engines. Please refer to the Excel sheet below.

    2. Stable electric power generation

    The automation system realized in STARDOM can also recalculate the set points for each gas engine in the event of a malfunction such as a trip of a gas engine. If one of the gas engines shuts down, the other two gas engines will increase power output to compensate.

    3. Power plant optimization

    STARDOM calculates the efficiency factors for each gas engine and for the entire power plant, and provides data that operators can use to make the plant operate economically and efficiently.

    Scope/Special Features of the Control SystemThree fully redundant STARDOM field control node (FCN) stations control different parts of the plant, including the electrical system, district heating system (including the gas engines connected to the PLCs), and air system.

    Redundancy is realized at different levels in the FCN controllers such as the power supply, CPU, communications between the nodes, and I/Os. One of the most important criteria is the 10 msec time stamping of electrical signals.

    The STARDOM controllers manage the plants measuring and supervisory control activities, governing approximately 550 hardwired I/Os. Via serial communication lines (MODBUS, IEC-103), they collect an additional 500 signals; 1,500 signals are connected through redundant OPC interfaces.

    Plant InformationPlant name: Furedi Power PlantLocation: Budapest, HungaryProject type: NewPlant type: Gas fired combined heat and power plantOutput: 34.5 MW (3 x 6 MW electrical, and 1 x 16.5 MWt)Order date: 2004Completion: 2005 Set points of No. 1 gas engine

    Set points of No. 2 gas engine

    Set points of No. 3 gas engine

    Sum of the set points

    One click export into FAST/TOOLS

  • 37 Power 38

    PetroChina Company Limited

    Customer SatisfactionLiu Jian Ming, Director of the Utility Control and Instrumentation Department said, Every day we are trying to improve operations at our plant and to reduce both coal consumption and CO2 emissions, because one of our targets is to achieve sustainable manufacturing. We very much appreciate that Yokogawa supplies very reliable products and systems, and has been working together with us to provide support. Of the many vendors that are supplying products and services for this PetroChina utility plant, Yokogawa is one of the best.

    The Challenges and the Solutions1. Safe and steady operationThe utility plant operates non-stop throughout the year, ensuring an uninterrupted supply of steam, water, and electricity to the main process facilities. In response to boiler master signals that are issued in real time by the production scheduling center, the four boilers must adjust their output to match shifts in demand for steam by the processes and the turbines that generate electricity for the complex. With its highly reliable dual redundant CPUs and seven 9s availability, Yokogawas CENTUM CS 3000 production control system maintains steady control of the boilers and ensures that operations can continue nonstop without any major system problems.

    Standard process graphics, process overview, trend, operator guidance, and alarm summary displays are all designed with safe operation in mind, and can be accessed quickly and smoothly by operators, giving them a comprehensive overview of operations.

    2. Total integration of informationThrough an OPC interface, the PetroChina Dushanzi refinery and petrochemical complex uses a supervisory information system (SIS) as its plant information management system (PIMS). All process data from throughout the complex are gathered by the CENTUM CS 3000 system and the GE PLCs used in the water and ash treatment processes. Based on this process data, boiler efficiency, coal consumption, rate of electricity generation, and many other kinds of useful data from the boilers can be accessed by the engineers at their desks, without having to visit the central control room. The CENTUM CS 3000 system is a very steady platform and provides a very convenient process monitoring environment.

    The integration of information allows PetroChina Dushanzi to reduce its consumption of water, coal, and other resources. In many different performance statistics, it is ranked number one in the PetroChina Group.

    Executive SummaryAt a cost of 30 billion yuan ($4.4 billion), PetroChina, China's largest oil producer, constructed a large refinery and petrochemical complex on a 455 hectare parcel of land in Dushanzi, a city in Chinas Xinjiang Uyghur Autonomous Region. Using mainly high sulfur crude oil from the Kazakhstan-China pipeline, the complex processes 10 million tons of crude oil and produces 1 million tons of ethylene per year. As such it plays an important role in the China-Kazakhstan energy cooperation strategy.

    The utility plant that provides steam, electricity, and water to this complex include five 440 t/h circulating fluidized bed (CFB) boilers, three 100 MW turbines/ generators, and chemical and water treatment systems.

    The complexs CFB boilers use brown coal as a fuel and are designed to keep CO2 emissions to a minimum. Normally, four of the complexs five boilers are in use and the remaining boiler is kept on standby and undergoes maintenance.

    For the utility plant at this important industrial complex, Yokogawa China successfully installed a CENTUM CS 3000 integrated production control system and the Plant Resource Manager (PRM) package.

    China

    Yokogawas CENTUM CS 3000 and PRM Assure Utility Supply for Dushanzi Refinery & Petrochemical Complex

    Plant InformationPlant name: Utility plant for refinery and petrochemical plantsLocation: Dushanzi, Xinjian Urghur Autonomous Region, ChinaProject type: NewPlant type: Circulating fluidized bed boilerOutput: 5 x 440 t/h, 2 x 220 t/hOrder date: June 2006Completion: January 2010

    Refinery Petrochemical plant

    SIS boiler operation display

    The PetroChina Dushanzi head office

    Total system configuration

    SIS

    Boiler (CENTUM CS 3000)

    Water treatment(GE-PLC)

    Ash treatment(GE-PLC)

    Production scheduling center

  • 39 Power 40

    Customer SatisfactionEBAC believes that the engineering complexity and innovation involved in installing 21st century control systems technology in an old plant was quite remarkable. Not only did the project increase the reliability of electricity supply, it reduced plant stress and decreased its maintenance costs. This was accomplished by optimizing the use of raw fuels. The successful outcome of this control system modernization project will allow the Morwell power generation and briquetting facility to operate well into the future while meeting anticipated economic and emissions standards.

    Peter Morrow, General Manager of EBAC (left) and Philip Nicholson, Principal Engineer of Yokogawa Australia (center) accepted the PACE Zenith Award from Jeremy Needham of Mitsubishi Electric, the sponsor of the Transport, Power and Infrastructure category.

    Energy Brix Australia Corporation

    Australia

    Yokogawa Australia Undertakes Extensive Replacement and Upgrade of Power Plant Control and Monitoring Systems

    Executive SummaryEnergy Brix Australia Corporation (EBAC) commissioned Yokogawa Australia Pty. Ltd. to modernize the Morwell Power Station and Brown Coal Briquetting Plant by replacing their control and monitoring systems with a modern Yokogawa CENTUM CS 3000 distributed control system (DCS) and a range of field instruments.

    EBAC is a long established electric utility in Morwell, which is in the coal rich Latrobe Valley region approximately 150 kilometers east of Melbourne, Victoria. The Morwell Power Station has an installed generating capacity of 180 MW and was built in the 1950s by the State Electricity Commission of Victoria to generate power for the national power grid. The Morwell Station also provides process steam to the adjacent brown coal briquette factory.

    This extensive modernization of the Morwell Stations control systems by EBAC and Yokogawa Australia was completed in 2008.

    EBACs goals for undertaking this extensive DCS upgrade were to:

    Reduce station operating and maintenance costs Generate additional power for export Improve plant operating flexibility Provide modern conditions for plant operators Reduce plant emissions

    Following the successful completion of this complex and challenging project, Yokogawa Australia and EBAC were jointly awarded the prestigious 2009 PACE Zenith Australia Industry Award for their leadership in the application of technological excellence and innovation.

    The PACE Zenith Awards were established in 2004 and are presented to Australian industry annually for outstanding achievements in technological excellence and innovation. Yokogawa Australias projects have previously won awards in 2005, 2007, and 2008.

    The Challenges and the SolutionsThe application of modern DCS technology at the Morwell Power Station was highly successful in achieving EBACs objectives. This project accomplished the following:

    Optimized the use of labor by enabling a preventive maintenance approach Optimized the plants operating configuration by allocating turbine loads, allowing the station to operate at continuous maximum

    capability Coordinated station control (range and pressure and process steam pressure), which in turn allows maximum plant flexibility by optimizing

    boiler and turbine loading to take account of fuel quality variation, plant condition, and briquette factory process steam demand Optimized the consumption of brown coal fuel and minimized flue gas discharge by fully automating combustion control on all boilers Minimized the consumption of fuel oil, improved furnace stability, and reduced plant stress and operating costs as a result of the

    automation of brown coal combustion Reduced thermal stress on the plant as a result of automating the boiler final steam temperature control Significantly improved plant safety by automating drum level control and furnace temperature control Increased operational flexibility and improved station response to load demand variations by fitting modern digital governors to all

    five turbine generators Increased consistency of plant operations and reduced rate of load variation Reduced maintenance costs through tighter control and more consistent/less stressful operation by reducing the number of significant

    excursions outside plant design parameters Significantly increased continuous MW load output from the available capacity while minimizing steam wastage and improving

    operating efficiency by automating steam consumption across all turbines and condensers Introduced a new screen-based operator interface that allows operators to monitor plant operations while relying on automation systems

    to maintain the plant in a stable and controlled condition throughout all steady state, load change, and plant upset conditions

    CENTUM CS 3000 control system cabinet

    Low pressure condensing turbine generator

    CENTUM CS 3000station operator consoles

    Plant InformationPlant name: Morwell Power StationLocation: Victoria, AustraliaProject type: Control system revampingPlant type: Coal-firedOutput: 180 MWOrder date: 2005Completion: 2008

  • 41 Power 42

    PNOC-EDC

    Philippines

    System DetailsControl system: CENTUM CS 3000 & PRMNumber of I/O points: 112 points (14 segments)Products: EJX430A (52 units), EJX110A (52 units) and CA71 (1 unit)System configuration: FF for advanced field instrumentation Standard-configuration transmitters for the geothermal application: EJX430A-FAS3G-917DN/A/X2/D4/M11 EJX110A-FAS3G-917DN/A/X2/D4/M11 PRM for optimal plant asset management WAN for remote data monitoring

    Customer SatisfactionPNOC-EDC was very satisfied with Yokogawas performance in the NNGP. The Company earned the customers trust with its project management expertise and local engineering capabilities. This project is part of the governments efforts to reduce dependency on oil through the use of renewal energy sources. The NNGP was inaugurated by no less than the President of The Philippines, Ms. Gloria Arroyo, who was accompanied by key officials in the power sector.

    Executive SummaryThe Northern Negros Geothermal Project (NNGP) was a breakthrough for Yokogawa. After a long selection process, PNOC-EDC awarded the contract for a Fluid Collection Re-injection System (FCRS) control system to Yokogawa. This attested to the Companys capabilities as a major automation vendor.

    There were several key factors for this success, including:

    1. Yokogawa had a strong track record in the region of executing projects involving FOUNDATION fieldbus (FF) technology, which had been selected for the control system. This was critical in gaining the trust and confidence of the PNOC-EDC. The coordination and cooperation between Yokogawa Engineering Asia Pte. Ltd. and other Yokogawa companies showed PNOC-EDC that Yokogawa was the best partner for automation of the FCRS control system. Another advantage was that Yokogawas infrastructure in the Philippines ensured long-term support.

    2. The contract included not only CS 3000 Vnet/IP, field instrumentation from Yokogawa and other suppliers, PRM, and engineering, but also construction. Yokogawas project management expertise was another important success factor.

    Through this project, PNOC-EDC obtained: State-of-the-art FF technology Plant Resource Manager (PRM) field device management system Remote data monitoring capability via wide area network (WAN)

    The Challenges and the SolutionsState-of-the-art FF technologyPNOC-EDC had adopted FF and was aware that there were many vendors of this technology. They needed to select the best partner for the long haul, and they did this through interviews and plant visits. After speaking with other end users of Yokogawa fieldbus products in the region, PNOC-EDC saw that Yokogawa was best positioned for a long-term relationship.

    Plant Resource Manager (PRM) field device management system PNOC-EDC recognized the importance of optimizing its operational costs and realized that asset management would be a critical success factor for attaining this objective. Yokogawas versatile PRM platform and fieldbus devices met the operational and technical requirements. With PRM, PNOC-EDC anticipates lower operational costs, effective maintenance programs, and high system availability.

    Remote data monitoring via WANCritical to the overall operation of the plant was the availability of plant information to PNOC control centers in Negros and in Manila. As part of the project, the FCRS control system was connected to a WAN by another vendor.

    Yokogawa's Reliable Control System is Running at Geothermal Power Plant in the Philippines

    Plant InformationPlant name: Northern Negros Geothermal Power PlantLocation: Negros Occidental, the PhilippinesProject type: NewPlant type: Geothermal power plantOutput: 49 MWOrder date: December 2005Completion: February 2007

    President Arroyo (Left of console)

    PRM windows

    System Layout

  • 43 Power 44

    Customer SatisfactionDr. Lovegrove explained, As a clean energy source, solar energy is a natural complement to wind and based on our climate is more available and provides most of the energy when you need it.As an example, in a large system with an array of dishes all feeding steam to a single efficient large steam turbine, each dish of this size would contribute the production of more than 100 kW when operating at full efficiency in full sunlight. Roughly speaking, up to 100 advanced energy-efficient homes could be powered by every dish. A solar field with the size of the Australian capital Territory (ACT) could power the entire country.The medium-term goal for the concentrating solar technologies is to make electricity for about the same cost as wind, which is currently around 10-12 cents a kilowatt/hour. While thats around double the cost of conventional coal-fired power stations, it may prove to be cheaper than adding carbon capture and storage to existing coal-fired power stations.Of course, the ultimate energy economics will be influenced by ruling government policy, with any moves to tax carbon impacting on fossil fuel power stations and tipping the economics more in favor of alternate energy sources in the future. We are very happy with the high reliability of Yokogawas system. This is very important to keep our solar plant running 24/365. Also, our engineers can easily configure the system at any-time. FAST/TOOLS benefits us in many ways and allows us to clearly see the entire process, giving us the information we need to take immediate action.

    Power generation flow with solar collecting dish

    The Challenges and the SolutionsThe latest dish, SG4, was completed in June 2009, and since then a great deal of effort and research by Mr. Burgess and others has gone into fine-tuning the solar tracking, sourcing computer, and communication components, testing optical performance, and installing and testing the first steam generating receiver. Yokogawa has worked closely with these researchers to optimize the performance of this system by providing a PLC SCADA system that computes the precise position of the sun to ensure millimeter perfect tracking of the sun. The system also includes safety features that, for example, will put the dish into a parked position at night and before storms to prevent damage from high winds.

    As new units are constructed at this ANU facility, the plan is to employ Yokogawas new HXS10 controller as a cost-effective means to automatically track the sun and ensure maximum efficiency of the solar reflecting dish.

    Executive SummaryLed by Associate Professor Dr. Keith Lovegrove, the Australian National Universitys (ANU) Solar Thermal Group has constructed the worlds largest solar collecting dish on the ANU campus in Canberra. This reflecting parabolic dish is 25 m wide and has 500 m2 of highly efficient purpose-built mirrors that reflect the suns rays onto a collector coil. This converts water to steam, which drives a steam turbine that generates electricity. Yokogawas FAST/TOOLS software fine-tunes the dishs ability to automatically track the sun and maximize the energy collected.

    This project had its genesis in the early 1970s, when a team lead by Stephen Kaneff and Peter Carden paved the way for the construction of the White Cliffs solar power station, with 14 comparatively small 20 m2 dishes. Convinced the idea had merit, the team at ANU proceeded to scale-up the solar generator, with the first Big Dish built in 1994 using commercially available space-frame technology. According to lead researcher Greg Burgess, the aim of the solar project has been to demonstrate that solar generated electricity is viable on a commercial scale. Their thinking is that building fewer large dishes, which can be easily replicated in the field, is more economic than building lots of smaller ones.

    Planning is underway for the construction of a pilot solar generating plant that will prove out the concept already demonstrated by the existing solar generator dish. Mr. Burgess also sees other potential applications for super-heated steam produced by reflected solar energy. Such is the intensity of energy generated by the dishs efficient design that when concentrated it can melt through solid aluminum, stainless steel plate, and even the hardest ceramic known.

    Yokogawa Australia is involved in this exciting solar energy project, which may provide the key to future solar energy projects in Australia.

    Australia

    Yokogawa PLC and FAST/TOOLS SCADA ControllAustralian National Universitys Big Dish Australian National University

    Plant InformationPlant name: ANU's Solar Thermal Group Location: Canberra, AustraliaProject type: NewPlant type: Solar thermal plantOutput: 100 kW/dishOrder date: 2009Completion: 2010

    Left to right: Mark Biggin, Yokogawa Australia;Mr. Burgess, ANU: Dr. Lovegrove, ANU

    Steamgeneration

    Steamturbine

    FAST/TOOLS

    Field operation center

    Solar collecting dish

  • 45 Power 46

    Customer SatisfactionNEP Solars Chief Executive Officer, Johan Dreyer, an engineer with experience as a project manager for one of Australians largest commercial and industrial construction companies, said, It is very important to control costs and ensure reliability for solar energy to achieve its potential in Australia. The critical part of the solar system is the ability to accurately track the sun. We need to focus exactly on one point (the solar tube), and the tracking needs to be very accurate. Yokogawas HXS10 solar tracking controller makes this possible. Mr. Dreyer went on to say, The efficiency of the mirrors is such that the system can capture enough solar energy to cool even on a partly cloudy day. In full sun, direct normal insolation using this type of system can be as high as 1000 watts per square meter.

    Flowmeters and temperature sensors such as those produced by Yokogawa can determine how much energy is being converted into thermal energy to monitor the efficiency of the entire system.

    NEP Solar will next use the Yokogawa HXS10 and the related FAST/TOOLS on a desalination project in Spain and at a dairy processing plant in Switzerland.

    The Challenges and the SolutionsAccurate sun tracking and visualization of all process dataThe critical part of the efficiency of the concentrated solar system is the ability to very accurately track the sun and adjust the angle of the reflectors on two axes to capture the maximum incident solar rays. When NEP Solar became aware of the advantages of Yokogawas new HXS10 solar tracking controller and the FAST/TOOLS SCADA system, it could see the advantages of using the solar tracking controller to replace common PLCs in future projects. The HXS10 is capable of accurately positioning the troughs in line with the sun, and the FAST/TOOLS software provides detailed performance and status information on the solar field to maximize output. FAST/TOOLS can even tell an operator that there is too much dust on the troughs (important as dust diminishes output). NEP Solars solar collector utilizes a specially coated aluminum mirror, which is mechanically polished to an extremely reflective finish as high as 92% rivaling the highest quality heat-sag glass mirrors. The lightweight, composite sandwich construction mirror panels and tracking system are robust to maintain tracking and focus for optimum conversion efficiency. They are also strong and can withstand winds up to 108 km/h in the parked position.

    Executive SummaryYokogawa Australia has supplied its breakthrough HXS10 solar tracking controller to NEP Solar one of the pioneers of solar energy in Australia for use in a solar cooling project.

    NEP Solar of Warriewood on Sydney NSW grew out of companies that were involved in wind farm development, but later became a pioneer of novel solar applications such as the first solar cooling project in Australia in 2004. NEP Solars local projects to date include a solar cooling demonstration project under the Renewable Energy Development Initiative (REDI) at the Commonwealth Scientific and Industrial Research Organization (CSIRO) Energy Centre in Newcastle, and a solar cooling demonstration project funded under New South Wales Government's Sustainable Energy. Research Development Fund (SERDF) in Padstow, partly funded under the New South Wales governments SERDF.

    One of NEP Solars latest projects is a commercial installation of a solar field to drive a chiller for part of the GPT Charleston Square shopping complex in the regional city of Newcastle north of Sydney. The 345 m2 PolyTrough 1200 solar field is mounted on a rooftop above a cinema complex. The chiller uses the heat from the solar field and a concentrated salt solution in which water gets absorbed and re-absorbed, exchanging heat in the process. The chilled water from the absorption chiller feeds into the shopping centers return cooling loop to reduce the amount of energy expended to further cool the water for the centers air conditioning system.

    Australia

    Yokogawas HXS10 Solar Tracking Controller Optimizes Conversion Efficiency at Australian Solar Cooling Plant NEP SOLAR Pty Ltd.

    Plant InformationPlant name: Solar cooling PlantLocation: Charlestown, AustraliaProject type: NewPeak Thermal Power: 200 kWOrder date: 2010Completion: 2011

    FAST/TOOLS main overview screen with wind compass

    Mr. DreyerEmployees of Yokogawa AustraliaJoint exhibit with NEP Solar at All-Energy Australia

    exhibition in October 2011

    Overview of solar cooling process

  • 47 Power 48

    Customer SatisfactionChanapai Sahudsa, A.T. Biopowers Engineering Manager, had the following to say about Yokogawas solutions: This is the first plant to be approved by the Thai government under the Clean Development Mechanism (CDM) defined in the Kyoto Protocol. We are very happy to be using Yokogawas system and products at this rice-husk-fuelled boiler plant, the worlds largest of its type. We are always looking for ways to improve its operation and make the combustion process more efficient. We always appreciate the solutions provided by Yokogawa Thailand.

    Plant detailsPlant type: Thermal powerGenerating capacity: 22.5 MW (internal 2.5 MW)Fuel: Rice husksDaily fuel requirement: 500 - 600 tons at maximum capacityBoiler: 91 t/h, 65 bar, MacburneySteam turbine: Shin NipponDaily water requirement: Approximately 2,200 m3

    Precipitator system: Electrostatic precipitator capable of detecting 99.5% of particulates

    The Challenges and the Solutions1. Stable combustion controlThe burning of the ground rice husks in the boilers furnace chamber is a complex process that must be carefully controlled. Fuel oil-fired burners heat the combustion chamber. Once this chamber reaches 700-800 degree C, ground rice husks are fed from a service silo to a fuel-air mixing system, where this mixture is compressed by air from a primary service fan and blown through the burners into the center of the combustion chamber. Adjustable vanes on the burners circulate the fuel-air mixture to maintain optimum combustion at 800-900 degree C. At the same time, compressed outside air that has been drawn in by a forced draft fan and heated in an economizer is directed into the lower part of the combustion chamber in order to keep the ground rice husks in a suspended state and ensure complete combustion. Once the ground rice husks are burning steadily, the supply of fuel oil to the burners is gradually reduced and then stopped completely. With the pressure inside the combustion chamber in balance with the outflowing flue gases, the heat from the flue gas generates 480 degree C steam that drives the steam turbine. The flue gases are then released through the economizer to recover the remaining heat.

    Steam from that has passed through the turbine is cooled down by a condenser as a condensate. This condensate is transported as drops of water back to the boiler to be recycled as steam. Meanwhile, the heated cooling water that was used to condense the steam is cooled down in a cooling tower for reuse. This system is thus a closed-circuit type cooling system.

    Yokogawas CENTUM CS 3000 system handles all of these sequences as well as the control of feed water, steam temperature and pressure, and drum level, and uses sensory inputs from a Yokogawa zirconia oxygen analyzer to optimize combustion of the fuel in the furnace, thereby assuring the stable year-round supply of electricity to the national grid. And when the power plant switches to island mode, the system adjusts the boiler firing rate to decrease the supply of steam to the plants steam turbine, thereby decreasing power production to a level that meets the plants own requirements. All of these sequences are also configured in the CENTUM CS 3000 system. Graphic displays at the control stations give operators a clear view of what is going on throughout this system at any given time, ensuring that they have all the information needed to take quick and decisive action whenever intervention is required.

    2. Emissions monitoringAfter combustion in the furnace, the heavier particles fall down to the inclined bottom of the furnace and are swept out through an ash port by a screw conveyer for removal. Lighter particles mixed with flue gases are carried out of the combustion chamber through a flue port. An induced draft fan draws these flue gases into groups of electrostatic precipitator (ESP) that trap the lighter fly ash particles before the flue gases pass up the stack for discharge into the atmosphere. This flue gas is monitored by the Yokogawa CEMS, which measures CO, CO2, O2, NOx, and SOx concentrations for reporting to the government on a weekly and monthly basis. All water used in the plant is analyzed by a pH meter and conductivity meter so that it can be kept within an allowable range.

    Thailand

    Thai SPP Uses CENTUM CS 3000 to Improve Efficiency of Biomass Power Plant A. T. Biopower Co., Ltd.

    Plant InformationPlant name: A. T. Biopower Co., Ltd. Location: Pichit Province, ThailandProject type: NewPlant type: Biomass Power PlantOutput: 22.5 MWOrder date: 2004Completion: 2005

    Burner management displayCentral control room

    Executive SummaryIn 2005, A.T. Biopower Co., Ltd. built a biomass power plant in Pichit, Thailand. Using ground rice husks as its fuel, this plant generates 22.5 MW of electricity, of which 20 MW is sold to the Electricity Generating Authority of Thailand (EGAT). The plant was built with the support of the Thai governments Ministry of Energy, which is promoting the construction of power plants by small power producers (SPP) that utilize hydro, biomass, or thermal cogeneration technology. In addition to promoting the use of renewable energy sources, this policy aims to reduce the countrys dependence on imported fuel. At present, about 90% of the electricity generated in Thailand comes from power plants that rely on non-renewable fossil fuels, namely, oil, coal, and natural gas. If no effort is made to find and develop new energy sources, it is estimated that the countrys coal and natural gas reserves will be completely exhausted in the next 30 years. The use of modern technology to generate power from rice husks and other kinds of agricultural waste will not only contribute to the countrys energy independence, but will also help reduce environmental pollution and provide employment opportunities for the local community.

    For A.T. Biopowers biomass cogeneration power plant, Yokogawa Thailand successfully installed the CENTUM CS 3000 production control system, field instruments, and a continuous emission monitoring system (CEMS).

    Continuous emission monitoring system

    Mr. Sahudsa

  • 49 Power 50

    Customer SatisfactionThe integrated control system allows JWD to manage the operation of each of its windmills and provide a steady supply of power to the national power grid. JWD plans to begin constructing wind farms outside Japan, and to this end is working together with Yokogawa and Tokyo Densan to develop the necessary high-speed systems and equipment. Through this development of renewable energy facilities, JWD hopes to make a lasting and significant contribution to the building of a more sustainable society.

    Plant details Windmills: 34 x 1,500 kWBattery: NaS type, 2 MW x 17 sets with 17 sets of AC/DC convertersTransmission capacity: 51 MWTransformer: Primary - 154 kV/60 MVA, secondary - 22 kV/60 MVA

    The Challenges and the SolutionsSteady power supply by reliable control systemTo ensure a stable supply of power to the national grid even when power production dips as the result of low wind speed, the Rokkasho wind farm utilizes large-capacity NaS batteries.

    The STARDOM network-based control system and FA-M3 range-free controllers play an important role in smoothing out the supply of this power to the grid. A power monitoring and control system and a battery control system are both configured in the dual redundant STARDOM controllers. FA-M3 range-free controllers are utilized to monitor and control each windmill. Controllers from other vendors are integrated with this system via an OPC interface. Factoring in the fluctuations in power production as a result of varying wind conditions, a power generation scheduling system calculates operation plan parameters and a power output pattern, based on which instructions are issued to each FA-M3 controller. The actual power output can be monitored on a trend graph. The operating status of each of the 34 windmills and the charge status for each of the 17 battery units can also be monitored together with various other types of operation data.

    This power monitoring and control system carries out the following main functions:

    1. Operation planning and monitoring Using the power generation scheduling system, operators can access the weekly operation plan data, based on which they can draw up an operation plan for the next day. At their stations, operators can view graphic displays showing the power sales target, power generation plan, and battery charge-discharge plan.2. Associated power monitoring Operators can view data on total power output for the entire facility, battery charge status, and transformer operation status.3. Windmill monitoringFor each windmill, data on power output, wind direction and speed, and operating status is displayed.4. Battery monitoring For each battery, the charge-discharge rate, charge status, and operation status are displayed.5. Remote monitoring and controlOperations can also be monitored and controlled wherever network access is available.

    Executive SummaryAmidst growing concerns about the depletion of fossil fuels and the effects of climate changes caused by rising CO2 emissions and other factors, there is a growing push to generate power from wind, solar, biomass, and other renewable energy sources and thereby create a more sustainable society.

    Japan Wind Development Co., Ltd. (JWD) is a specialist in wind power generation technology with vast knowledge and expertise in this field. JWD is building and providing all necessary support services for a nationwide wind power generation network.

    In May 2008, JWD completed construction of a wind farm near Rokkasho village in Aomori Prefecture, in northern Honshu. This smart grid wind farm is the first facility of its type to use sodium sulfur (NaS) batteries to store electricity for supply to the national power grid. These batteries are charged at night, when the demand for power is lower, and the stored electricity can be supplied to the grid together with the electricity generated by the wind turbine during the daylight hours. This ensures a steady supply of power to the grid even during those periods when power production falls as the result of low wind speed.

    To control the transmission of power from the Rokkasho wind farm to the national power grid, Tokyo Densan, a Yokogawa representative and systems integrator, successfully installed STARDOM network-based controllers and FA-M3 range-free controllers.

    Japan

    STARDOM and FA-M3 Ensure Smooth Supply of Power to Grid by Wind Farm Equipped with Large-Capacity NaS Batteries Japan Wind Development Co., Ltd.

    Plant InformationPlant name: Japan Wind Development Co., Ltd. Location: Rokkasho, Aomori, Japan Project type: NewPlant type: Wind power generationOutput: 34 x 1500 kWCompletion: May 2008

    Total system configuration

    Central control room

    Battery

    Charging

    Power

    Charging

    Time

    Smoothedpower to

    national grid

    0 7 12 18 23

    Power generation by windmills

  • 51 Power 52

    Customer SatisfactionIn his comments to Yokogawa, Danny Coulston, General Manager of the Lakeside EFW facility, touched on the following points:Everyone at Lakeside EFW is pleased with the high reliability of the Yokogawa systems and their

    ease of operation and engineering.The new plant was designed to meet the requirements of the European Waste Incineration

    Directive, which mandates tight controls on the atmospheric release of dioxins, heavy metals, acid gases, nitrogen oxides, particulates, and other products of the combustion process. This reduces environmental impact and protects human health, and the facilitys emissions of dioxins and other health related pollutants are low compared to common air pollution sources such as outdoor burning and vehicle exhaust.

    Lakeside EFW well recognizes the importance of water conservation and has designed the facility so that all process water and water from maintenance activities is collected in a tank to be reused as "gray" water for non-critical purposes.

    The company has built an education center that extends out over a nearby lake. This is used to educate the public on the efforts that Lakeside EFW is making toward a sustainable future.

    Waste to Energy overview flow

    The Challenges and the SolutionsLakeside EFW is continually looking for ways to operate this incineration facility more efficiently. Waste is trucked to the facility, with the vehicles being weighed on entry into the site and again on exit to calculate the amount of delivered waste. Grab cranes mix the waste in a 7,500 ton capacity bunker to obtain a more controllable calorific value, then load the waste into a hopper from where it is pushed into the incinerator by hydraulic rams. The initial firing of the boiler is achieved using an approved low sulfur diesel. Once the waste is burning inside the incinerator, the diesel burners are switched off and the waste becomes the fuel.

    Superheated, dry steam created from the boiler process is used to drive a steam turbine, which in turn drives a generator set. The generator produces enough electricity to power the Lakeside facility and export 34 MW onto the National Grid. Spent steam from the turbine is condensed and pumped back to the boiler, making a closed-loop steam/water circuit. The facility has also been designed so that off-site district heating (combined heat & power - CHP) can be provided to local consumers in the future.

    The bottom ash from the waste incineration process is transported by moving belts to dedicated bunkers. Ferrous metals are removed from the bottom ash for recycling. The ash is removed from the site and processed into an approved aggregate material for road building and construction.

    The hot gases from the incineration process that were used to heat the water contain various compounds and chemicals that need to be treated. These gases and chemicals are cleaned in a flue gas treatment process. This uses slaked lime to absorb sulfur gases and HCl, activated carbon to absorb dioxins and heavy metals, and ammonia to reduce NOx gases. The air is subsequently passed through a bag filter before it is released from the stacks. The emissions are monitored in real time using state-of-the-art, independently calibrated measuring instruments to ensure compliance with permitted emissions limits.

    With the integration of the Yokogawa CENTUM CS 3000 and ProSafe-RS systems, operators in the central control room enjoy ready access to operations throughout the plant. Ergonomically designed CS 3000 human interface stations (HIS) provide a window into all of this facilitys processes, giving operators real-time access to all the information they need to make quick and timely decisions.

    Executive SummaryAs existing fossil fuel reserves have become unviable or unreliable, the challenge of providing a secure energy supply for power generation within the UK has increased significantly in terms of both financial and environmental cost. At the same time, landfills lack the capacity to handle the increasing amount of household and municipal waste. While efforts to reduce, re-use, or recycle waste have made some headway, other options have had to be explored. One such effort underway that is making a valuable contribution toward providing a balanced and secure energy portfolio for the UK involves the extraction of energy from residual (non-recyclable) waste.

    Lakeside EFW Ltd. operates an energy-from-waste (EFW) facility near London that is staffed by experts in energy recovery technologies who are working hard to ensure the plant remains efficient, technologically up to date, and above all, safe. The plant has the capacity to consume 410,000 tons of household and municipal waste per year and exports at least 34 MW per hour to the countrys National Grid. This process diverts the majority (over 97%) of waste from landfill.

    Lakeside EFW uses a mass-burn process to generate high temperatures that are then used to produce high pressure steam. The steam in turn drives a turbine to produce electricity. Residues and flue gases are carefully treated to minimize the release of environmental pollutants. The facility operates under strict environmental controls, within the guidelines of the waste incineration directive (WID) and an environmental permit administered by the environment agency.

    For Lakeside EFW, Yokogawa UK installed a CENTUM CS 3000 distributed control system and a ProSafe-RS safety instrumented system to automate control of the facilitys boilers, burners, and balance of plant facilities. The facility has operated safely with no major system failures since coming online in 2008.

    UK

    Modern Waste to Energy Facility in UK Uses CENTUM CS 3000 and ProSafe-RS Lakeside EFW

    Plant InformationPlant name: Lakeside EFWLocation: Lakeside, UKProject type: NewPlant type: Stoker boilerOutput: 34 MWOrder date: January 2007Completion: April 2008

    Central control room

    Incoming waste Incineration Generation of electricity

    Lakeside Education Center

  • 2010

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    VigilantPlantSuccess StoryCollection

    00A01A53-01E

    TrademarksAll brand or product names of Yokogawa Electric Corporation in this bulletin are trademarks or registered trademarks of Yokogawa ElectricCorporation. All other company brand or product names in this bulletin are trademarks or registered trademarks of their respective holders.

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