VASSILIKO INDEPENDENTPOWER PLANT LTD

SUBJECT Technical questionnaire for the combined cycle power plant

INSTRUCTIONS

In the space provided in the right column please provide your notes, comments and if necessary data requirements. Please provide any alterations, discrepancies or alterations from the left column in BOLD letters.

COMMENT VIPP LTD has performed a technical optimization study, to assess the concept of a Combined Cycle Power Plant (CCPP) in Cyprus

CONTACT PERSONS

Miljan RadunovićProject Manager (Belgrade office)Energy System Integratorm: +381 64 8731106e: miljan.radunovic@esi.co.rs

Nikola MilutinovićProject Manager (Larnaca office)Energy System Integratorm: (+357) 96 475 773e: nikola.milutinovic@esi.co.rs

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DESCRIPTION AND MINIMUM REQUIREMENT NOTES/COMMENTS1. The project will be an energy complex with the following primary components:

Power generation system; High Voltage power distribution system; Utility systems; Process systems; Fuel oil storage tanks; LNG feeding system

2. The CCPP is designed to use heavy fuel oil (HFO) and to be readily convertible to natural gas when it is available in the future. HFO will be stored at the fuel storage facilities of the plant.

3. The project will provide generation capacity to the national grid by 2014, and will be an important component to the country’s power generation infrastructure. It is stressed that all solutions proposed aim at a high reliability in terms of functionality, safety and operability.

4. Plant Configuration4.1 Combined Cycle Power Plant (CCPP) gas turbine and generator, Heat Recovery Steam Generator (HRSG) and Steam Turbine and generator.

4.2 Cogeneration Unit (CHP), to cover the needs for cold start reserve.

4.3 The units must be possitioned and integrated into the available space as defined in Drawing 1, which is an integral part of thi Tender and attached herewith. It is necessary to provide a provisonal layout of the 4.1 and 4.2 units in your submussion. PLEASE NOTE THAT SYMILAR UNIT LAYOUT HAS BEEN USED ONLY FOR REFFERENCE.

4.4 According to this plant layout, the gas turbine generator packages with the HRSG’s will be installed in open air. The steam turbine will be installed within an enclosure designed to limit noise. Water treatment plants and water storage tanks, as well as turbines and HRSG will be close together, enabling short runs for the water pipes.For security reasons, a fence will be considered around the power plant and the Vasilikos Cement plant.

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5. The electrical power output of the CCPP will be 50.92 MW (net plant output 48.009 MW) when fuelled by HFO (see Table 8.1). The heat rate will be approximately 8,246 kJ/kWh and the plant electric efficiency will be of the order of 43.66%, in full condensing mode. The plant will also have provision to supply steam to the cement works for process heat which will have the affect of increasing cycle efficiency and reducing the available electrical power.One gas turbine, with a nominal base load power output at ISO conditions (15oC and 60% relative humidity) of approximately 39 MWe and one steam turbine with a nominal power of approximately 16.7 MWe at ISO condfitions shall generate power and supply electrical power from turbine alternators. The export voltage to the existing VCW sub-station is 11.5kV.

HFO will be supplied by tanker to a leased bulk storage tank(s) of up to 20,000 tons capacity at an existing commercial storage facility and from there to an existing on-site untreated storage tank with a total capacity of 700 tons. The untreated fuel will then be pumped by liquid fuel pumps into the HFO treatment plant and then to an existing treated HFO storage tank of 400 tons capacity.

Process and utility systems have been designed for simplicity and for ease of operation and maintenance, with simple subsystems and control loops.

6. Natural Gas fueled CCPP

The electrical power output of the CCPP will be 52.8 MW (net plant output 51.2 MW) when fuelled by NG (see Table 4.3). The heat rate will be approximately8,644 kJ/kWh, and the plant electric efficiency will be of the order of 41.65%One gas turbine, with a nominal base load power output at ISO conditions (15oC and 60% relative humidity) of approximately 39.9 MWe and one steam turbine with a nominal power of approximately 12.9 MWe at ISO conditions shall generate power and supply electrical power from turbine alternators. The export voltage will remain 11.5 kV.

Fuel to the CCPP is to be supplied as pressurised

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natural gas as and when it is available in Cyprus.Again, as it was mentioned before process and utility systems have been designed for simplicity and for ease of operation and maintenance, with simple subsystems and control loops.

7. Design Basis

The design of the unit has been based on the general requirements listed below:

HFO tank storage capacity : 1 x 3,000 m3 and 1 X 500 m3

Design life: 25 years CCPP power plant capacity: 50 MW natural

gas/HFO fuelled CCPP power plant nominal voltage / frequency: 11

kV / 50 Hz

8. Systems description

In the following paragraphs the CCPP systems description will be presented.

The CCPP shall be consisted of the following systems: Power generation system; High Voltage power distribution system; Utility systems Process systems; Fuel oil storage tanks; NG feeding system

9. Power generation systemCombined Cycle Process Description

The combined cycle process is in general the most efficient fossil-fuelled power generation process of today.

The core part of the process is one or more gas turbine(s) that are operating on HFO or compressed natural gas. Power is generated from an alternator coupled to the gas turbine shaft. The hot exhaust gases (at typically 537oC for natural gas and 551oC for HFO for the present case) from the gas turbine is then used to generate steam in a heat recovery steam generator (HRSG). The steam produced here is in turn used for generating more electricity by steam expansion in one or more steam turbines connected to alternators. The output from both the gas turbine and

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the steam turbine electrical alternators is combined to produce electricity in a very efficient matter.

10. Overall efficiency

The proposed combined cycle process MINIMYM performance data are tabulated in (HFO TABLE) and (NG TABLE). ATTACHED

NG TABLE shows an overall efficiency before taking power used for all auxiliary electrical consumption into account. Depending on which of the auxiliary systems are in use, the net electric efficiency of the complete CCPP will vary between roughly 43 and 45 percent.NG TABLE shows an overall efficiency before taking power used for all auxiliary electrical consumption into account. Depending on which of the auxiliary systems are in use, the net electric efficiency of the complete CCPP will vary between roughly 41 and 43 percent. The quoted efficiency on natural gas is reduced in part because the HRSG is designed for higher stack temperatures that are needed because of sulphur content in the HFO. Investigations are taking place to design a HRSG that will be capable of simple cost effective conversion to natural gas operation at efficiency levels in the 43% to 44% range

Please provide your notes on the Tables a separate page

11. Gas Turbine

The VIPP CCPP will be based on the gas turbine which is a single shaft, annular combustor, heavy-duty gas turbine with hot end drive. It can burn both gaseous and liquid fuels and can be used both in open cycle and combined cycle operation.

Firing heat duty, HFO LHV (MWth) 112.907t/h 9.798

Firing heat duty, NG LHV (MWth) 122.925

The Turbine will be equipped with a ten-chamber combustion system (burners) for burning HFO and will be readily convertible to natural gas. With steam injection into the combustion chambers, the NOX concentration in the exhaust gas will be reduced,

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resulting also in higher power output but slightly lower efficiency.

Generally, the gas turbine unit including generator and auxiliaries will be based on the manufacturer’s standard design to secure the advantages of a standardized packaged product. The control equipment will be located in an air-conditioned building. The GT generator packages will be installed in a separate gas turbine container.

The starting system for the GT will be an electric motor and a torque convertor.

The main MINIMMUM REQUIRENENTS data for the gas turbine are listed below.

12. Compressor

The compressor will be a multistage axial flow design with modulating inlet guide vanes. Interstage extraction will be used for cooling and sealing. High strength stainless steel blading material will be provided. The blading material in the compressor will have high corrosion resistance

13. Combustion System

The combustion system—which contains fuel nozzles, liners, transition pieces, X-fire tubes, flame detectors and spark plugs—consists of 10 reverse-flow combustion chambers arranged concentrically around the periphery of the compressor discharge casing

Steam is injected into the compressor discharge air stream around each of the fuel nozzles to reduce flame temperature, which leads to a reduction in NOx emissions. The quality of steam for injection must comply with GEK101944: Requirements for Water/Steam Purity in Gas Turbines; typical supply conditions of the steam would be 325 psig with a minimum of 50°F superheat. Steam injection will increase the gas turbine output and reduce heat rate (improved heat rate) The quantity of steam required will depend on the desired NOx level required, the fuel used, and the ambient conditions. The steam injection provides NOx emission control by modulating the steam injection rate proportional to fuel consumption.

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The steam injection system consists of steam flow control and regulating valves and control plus monitoring devices located off base in the operator’s steam piping. The steam from this off-base source is supplied in a controlled flow to the turbine’s steam injection manifold. The steam is then injected directly into the combustion can, serving to lower combustion temperatures thereby reducing NOx production

14. Turbine Section

The turbine section will have three stages The rotor will be a single shaft, with high torque capability incorporating internal air-cooling for the turbine section. The turbine buckets (rotating blades) will be changeable in sets or individually without any field balancing of the rotor.Turbine materials, coating and cooling systems enable reliable operation at high firing temperatures. This achieves high gas turbine specific power and high efficiency for combined-cycle systems.

15. Generator

The generator will be designed and constructed for continuous GT drive, and will withstand without harm all normal conditions of operation, as well as transient conditions such as system faults, load rejection and mal-synchronization. Temperature detectors will be installed in the generator to permit the measurement of the stator winding, gas temperatures, etc16. Gas Turbine Control System (MK V)

The turbine control must be considered here. It is also a suitable platform for integrating all power island and balance of plant controls.

17. Gas turbine generator unit

Gas turbine generator unit includes the gas turbine package consisting of:The gas turbine compartment:

multi-stage (17 stages), axial flow compressor; modulated inlet guide vanes; three-stages turbine; multi-chambers combustion system; ignition system with spark plugs and UV flame

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detectors; borescope openings for maintenance inspection; seismic type vibration sensors on bearing caps

for protection; proximity type sensors for shaft line

displacement monitoring; thermocouples for measuring exhaust

temperature; thermocouples on bearing drains; thermocouples on bearing metal; inlet plenum and exhaust diffuser; exhaust frame blowers; on/off line compressor wet washing system; water injection system for NOx control

The auxiliary systems: lubricating oil system; hydraulic oil system; liquid fuel system; gas fuel system; atomizing air system; water injection for NOx level reduction

Couplings: gas turbine dry flexible diaphragm type load

coupling; connected to generator with solid coupling; load gear box mounted between the gas turbine

and the generator; lubrication system integral with the gas turbine GT rotor turning gear with electrical motor

Gas Turbine Packaging enlarged acoustic enclosure around gas turbine

compartment; compartment ventilation and heating; hazardous area classification; gas detection system; fire detection and protection system with thermal

detectors

Generator General Information: totally enclosed water-to-air cooled (TEWAC)

generator; 50 Hz generator frequency; generator voltage approx. 11 kV; 0.85 power factor (lagging); SCR approximately: 0.45 to 0.5;

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Xd’’ approximately 14%; class “F” armature and rotor insulation; Cylindrical forged steel rotor with Class F

insulation; “B” temperature rise, armature and rotor winding; temperature monitoring device for windings,

cooling air path, bearings, cooling water, etc.

The gas turbine generator unit control equipment will be located into an air-conditioned Turbine Control Compartment (TCC) designed for outdoor installation and consisting mainly of:

turbine control panel; Triple modular redundant (TMR); Local (I) processor (computer); Single remote (I) processor; One (1) Mark V per stage link; RS232 serial link (modbus); Mark V to (I) connection <15 m (50 ft); Demand display; Extended I/O; Customer input contacts; Customer output contacts; Normal start/normal load; Normal start/fast load; Speed matching, synchronization and check; Generator manual synchronization; Generator synchronizing module; Isochronous control; Droop control; Constant adjustable droop; Power factor calculation and display; Load limiter; Base load only; Preselected load – manual set point; Trip signal display; Bearing metal temperature readout and alarm Fire protection discharge – time delay; Vibration alarm readout and trip (seismic only); Redundant sensors for critical measurements; Combustion monitor; Wheelspace temperature readout and alarm; Generator stator over-temperature protection; Generator coolant and stator temperature

indicator

Off-base unit mechanical auxiliaries including the inlet air system with:

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Turbine Inlet Air System Up and over configuration Inlet air compartment with: Three stage Coalescer + pre-filters + high efficiency Support structure Instrumentation Inlet system pressure differential indicator Inlet system pressure differential alarm Inlet silencing 2.4 m Perforated stainless steel construction Inlet duct section Inlet elbow Inlet expansion joint Inlet transition piece from duct to plenum Structural support Zinc rich paint on outside and inside of inlet

plenum

The gas fuel off-base system including: shut off and vent valve skid; gas piloting system

The HFO fuel forwarding system including: Fully lagged enclosure for outdoor installation Located at fuel tank Dual inlet liquid fuel strainers Single unit, one (1) ac motor-driven pump and

one (1) black start dc pump Pressure regulating valve Liquid fuel heater Flow meter

Fire protection for gas turbine unit including: one (1) HP CO2 bottle rack inside a air-

conditioned storage container; unit fire detection and protection panel; unit fire protection panel

Washing skid(s) including: Compressor on- and off-line washing skid

Off-base unit mechanical auxiliaries including the inlet air system with:

air filter; ducting and inlet silencer; supporting steel structure

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The gas turbine MINIMUM performance and technical data are AS FOLLOWS:CompressorNumber of stages 17Type of rotor construction Multi-disk with Hirt serration and central tie rodNumber of stages of variable inlet guide vanes 1Combustion systemCombustion chamber type AnnularNumber of combustion chamber 1Number of burners 10Burners type Hybrid (diffusion / premix)Type of igniters Spark plugsNumber of igniters 1 per burnerType of flame supervisory elements Flame sensorsNumber of flame supervisory elements 2Type of NOx reduction method for fuel gas

Steam injectionType of NOx reduction method for fuel oilSteam injectionTurbineNumber of stages 3Type of rotor construction Multi-disk with hirth serration and central tie rodTurbine temperatureInlet ISO temperature at base load 1,094 oC +/- 10 oCGas turbine speedNominal speed 5,413 rpmRange of allowed speed 5,142 – 5,575 rpmOver-speed protection threshold 5,846 rpmDuration of start-up and loading (in open cycle at ISO condition)Time to reach full speed no load conditionfrom standstill 5 minTime to reach base load from synchronisation 17 minTurning gearType Hydraulic ratchetSpeed in turning operation naOperating period required after shutdown24 hoursStarting systemType Electric motor plus torque converter systemNominal power 1,400 kWSpeed 5,413 rpmAllowed number of start-up 4 (2 hours interval required after fourth start)

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. Performance characteristicsFUEL NG (5) HFO (6)Amb. Temp. (oC) 15 15Amb. Press. (mbar) 1,013 1,013Amb. Rel. Hum. (%) 60 60Load (%) 100 100Exh. Press. Drop (mbar) 0 0Power Output (kW) (4) 52,801 54,203Efficiency (%)(1,4) 35.38 34.83Exhaust gas mass flow (kg/s) (2) 141 142Exhaust gas temp. (oC) (3) 537 538Exhaust gas compositionO2 (%vol) 13.52 13.42N2 (%vol) 73.21 71.77Ar (%vol) 0.8817 0.8642CO2 (%vol) 3.09 4.207H20 (%vol) 9.289 9.703SO2 (%vol) 9.289 0.0365

18. Co-generation Unit

Please provide the data for the specified engine: Number of cylinders Bore/Stroke Engine speed Frequency Mechanical output Electrical output, cosø = 0.8 Mean effective pressure Specific fuel consumption Fuel consumption Charge air cooler Lube oil cooler Jacket water cooler Exhaust mass Exhaust gas temperature Lube oil consumption Nom el efficiency, cosø = 0.8

19. Gas Turbine driven Alternator Sets

The power production system of the power plant comprises of one gas turbine, accompanied by two-pole air-cooled turbo-generator.The generator is of a conventional design for use with gas turbines, air-cooled, 2-pole machine with

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cylindrical rotor, ventilated in closed circuit employing air-to-water heat exchangers located in the lower part of the stator frame.

The gas turbine alternator will operate on 50 Hz frequency and 11 kV voltage. Step-up transformer is necessary for achieving a voltage level high enough for power export to the national grid. Please provide thr folowing data:

Description Rated output Rated power factor Rated voltage Voltage variation rate Rated frequency Frequency variation range Rated current Rated speed Overspeed (test for 2 min.) Phase number / Phase connection Excitation system type Excitation current at rated load Excitation voltage at rated load Stator / Rotor winding cooling type Ambient temperature range Cooling water temperature range Air temperature at coolers outlet (rated

conditions)

20. Heat Recovery Steam Generators (HRSG)

In order to obtain a higher efficiency of the power plant system the hot exhaust flue turbine gases will be utilised for steam generation in the Heat Recovery Steam Generators (HRSG). The design comprises one heat recovery boiler for the gas turbine. The HRSG design will be based on a 25-year plant life, 200,000 hours operating timeThe Heat Recovery Steam Generator (HRSG) will be horizontal flow, natural circulation, installed downstream of the exhaust duct of the Gas Turbine. The HRSG receives the hot flue gas from the Gas Turbine itself and produces steam at two different pressure levels.

The boiler will be a dual pressure, non-reheat unit consisting of a high-pressure (HP) section and a low-pressure (LP) section. Each section has a superheater,

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steam drum, evaporator and economizer. The economizer, evaporator, and superheater have finned tubes that extend into the gas turbine exhaust gas path. The finned tubes absorb heat from the gas turbine exhaust gases and utilize it to heat water and/or steam in their tubes (Figure 7.8).

Heating surfaces will be built into the non-cooled flue gas duct. The duct containing heating surfaces will be supported by structural steel. The HRSG supporting steel will be equipped with stairs and galleries. The duct will be provided with inter-stage inspection manholes. Flue gasses from the GT outlet are led into the inlet duct, through the diverter duct section and shaped inlet duct to the boiler and from the boiler to the stack. The flue gas ducts will be supported by the steel structure and reinforced by a sufficient number of stiffeners. The flue gas ducts will be provided with inter-stage inspection manholes and covered with thermal insulation, so the outlet temperature will not exceed 60°C. The HRSG will be equipped with all fittings and instrumentation to ensure safe boiler operation

Please provide the following data: Number of HRSG’s Kind of HRSG Live steam pressure (HP) Live steam temperature (HP) Live steam capacity (HP) Steam pressure (LP) Steam temperature (LP) Steam capacity (LP) Flue gas temperature at stack

21. 7.6.3.1 HRSG stack

The HRSG stack height is 27m above the ground level and it will be made of carbon steel. This is an adequate height for pollutants to be dispersed uniformly in the atmosphere and meet the environmental requirements. The stack will be complete of flue gas sampling ports and warning lights. A cold flue gas will be covered with thermal insulation as well as a silencer to comply with the plant noise requirements.

The sound pressure level from all the equipment for one HRSG shall not exceed 85 db(A) at a distance of

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1 meter from the equipment face and 1.5 meters above the ground and personnel platforms.

The HRSG drums and superheaters are equipped with officially approved spring-loaded safety valves to prevent unacceptable over pressurisation. For IP, and LP economiser water relief safety valve will be provided at economiser inlet.

All drain and vent lines of the HRSG are equipped with double isolation valves. Drains are proposed for all the high, the intermediate and the low pressure systems of the HRSG, in order to empty the boiler in about one hour.

All drains required for operation of the HRSG including those associated with the steam drum level gauges, level alarms and those from each of the economiser and evaporator bank manifolds will be routed to the blow-down tank. Drains from the superheater banks, which are required to operate during start-up of the HRSG, are equipped with one motorised on/off valve.

All equipment with an external temperature higher than 60°C during operation will be thermally lagged. Thermal lagging protects all parts against excessive thermal losses, the surrounding against heating and operators against dangerously hot surfaces. Lagging will be of mineral wool and covered by thin sheeting. The external temperatures of all boiler parts will not exceed 60°C.

The degasified feedwater will be propelled by the feed pumps from the feedwater tank to the boiler. NH4OH will be dosed to the feedwater to attain the specified pH and hydrazine will remove residual oxygen from degasification.

The HRSG can be operated and supervised from the remote control room. The parameters which will be controlled and monitored include:Control

Water level control; HP steam temperature control

Monitoring Steam; Water trains (pressure, temperature and flow

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22. Steam Turbine (ST)The steam turbine should be supplied by a world-class manufacturer with previous proven experience supplying steam turbines and generators of similar size for the same application.

The steam turbine (ST) will be of a non-reheat type for HP and LP steam. The generator will be connected to the HP end of the turbine shaft. During normal operation, the turbine receives the HP and LP steam from the HRSG.Please provide the folowing data:

Electric output, gross 15 oC, 60% RH, HFOMW

Electric output, gross 35 oC, 66% RH, HFOMW

Electric output, gross 15 oC, 60% RH, NGMW

Outlet pressure of steam turbine bar

In emergencies and during start-up, the steam produced by the HRSG will be supplied directly to the turbine condenser through the by-pass reducing and de-superheating stations. The feedwater tank will be supplied by LP steam extracted from the ST with the necessary heating steam for de-aeration and heating of the condensate collected there. The proposed steam turbine will be operated at sliding inlet pressure to accommodate the load changes of the gas turbine and HRSG. Cooling of the generator may be by air.

Turbine casingsThe steam turbine will be of a double casing design with an axial exhaust to the main condenser. Turbine casings will be split by a horizontal parting plane into upper and lower halves: machine ground at horizontal centerline for ease of maintenance

Turbine rotorThe rotor will be machined from a solid forging, and will include a coupling flange for connection to the generator. The coupling will be designed to withstand short circuit and torsional critical speed conditions. Mechanical type turning gear will be fitted at the turbine-generator coupling. It will typically include the following features and specification:

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Mechanically attached, aerodynamic impulse type buckets

Peened tenon attchment of shroud bands to bucket tips

Integral thrust runner Designed for thermal cyclic operation

BearingsThe turbine rotor will be carried on two journal bearings. The journal bearings will be horizontally split. Inspection of the bearings will be possible without removal of the rotor. They are replaceable without removing turbine casing upper half.Vibration will be monitored by one Bently Nevada probe assembly per bearing, whilst bearing temperatures will be measured by thermocouples.

Lubrication oil systemLubricating oil is delivered for the turbine as well as for the generator bearings. An emergency oil pump, driven by a DC electric motor, will maintain the supply of lube oil should there be a loss of AC voltage. Start-up of the emergency pump will be automatic. Lubricating oil is cooled down in one of two shell and tube type oil coolers (one is full capacity stand-by) designed per TEMA C. They are mounted vertically on end of reservoir. They are designed for fresh cooling water with maximum conditions of 48oC and 125 psig. The lubricating oil will be cleaned by the duplex type mesh filter fitted in the discharge line. Fouling of filter elements is checked by measuring the pressure differences over the filter mesh inserts.

23. Turning gearThe turning gear of the steam turbine will be used:

After turbo-generator shutdown, to ensure uniform cooling of the turbine rotor

Before start-up of the unit, prior to opening the gland steam feed valves.

24. Generator

The generator will be designed and constructed for continuous operation, and will withstand without harm all normal conditions of operation, as well as transient conditions such as system faults, load rejection and mal-synchronization. Temperature detectors will be installed in the generator to permit measurements at

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the stator winding, gas temperatures, etc.

Generator main characteristics: GCAC or open ventilated Self-cleaning inlet filters (if applicable) Shaft-mounted fan 11,000 volts, 50 Hz 0.85 power factor Counter clockwise rotation (viewed from the

collector end of the generator) Phase sequence from collector end: L-C-R Generator lead exit – left end viewed from

collector end Stator winding with Class F insulation Cylindrical forged steel rotor with Class F

insulation Class B temperature rises rotor/stator

The steam turbine alternators to operate on 50 Hz frequency and 11 kV voltage. Step-up transformers are necessary for achieving suitable voltage level for power export to the national grid25. ----------26. Steam Condenser

The condensate system will deliver condensate from the condenser hotwell through the gland seal condenser to the low-pressure drum. Two (2) 100% capacity condensate pumps will take its suction from the condenser hotwell and discharge to the low-pressure drum. Any condensate system losses are normally made up to the condenser hotwell via vacuum drag from the condensate storage tank.

Condensate may also be used for: Condensate receiver flash chamber; Turbine exhaust hood spray; Chemical injection solution tanks; De-superheaters; Vacuum pump seals

The required minimum flow through the condensate pump and gland seal condenser will be automatically provided using a flow-measuring device, with transmitter, which will automatically modulate a flow control valve to circulate condensate back to the hotwell when required.

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Condenser hotwell level is automatically controlled by a split range level transmitter in conjunction with two (2) control valves. The control signal is programmed to dump excess condensate to the condensate storage tank to prevent high level, and to deliver make-up condensate to the condenser hotwell to prevent low level.

The steam condenser will operate at a steam pressure of 0.14 bar, and condenser cooling will be achieved by tertiary treated recycled water from the Limassol Sewerage Treatment Plant. The condenser cooling water is a closed loop system. Cooling water is provided by two (2) circulating water pumps that take suction from the cooling tower basin and send their discharge through the condenser and then back to the cooling tower for cooling.

The temperature of recycled water supplied to the steam condensers will be approx. 23oC in order to keep the condenser pressure at 0.14 bar. Total recycled water supply to the steam condenser will be at a flow rate of 12 m3/h.

The main technical characteristics of the cooling system are listed below.Please provide the folowing data:Type of coolerDesign water temperature oCThe charge of water m3/h

27. Auxiliary Cooling Water System

The auxiliary cooling water system is a closed-loop system. The cooling water pump(s) take suction from the auxiliary cooling water return header and pumps the water through the auxiliary cooling water heat exchanger. The water from this heat exchanger is then sent to cool:

Steam turbine lube oil coolers Steam turbine hydraulic power unit HRSG boiler feed pump coolers HRSG LP and HP circulating pump coolers

(where provided) Air compressors and aftercoolers Sample coolers

Pressure controls will automatically start the standby

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pump on falling discharge header pressure. Throttling valves are provided on the outlet of each component to balance system flows and pressures.

28. HFO Storage Tanks

The VIPP CCPP will include 2 fuel oil storage tanks with a total storage capacity of 3,500 m3 will be used to store the HFO for the operation of the plant. Approximately 30,000 m3 will be stored at VTT fuel storage farm which will be constructed close to the plant, in order to satisfy the storage capacity requirements of 90 days

29. NG Handling System

When it becomes available the power plant will use natural gas as basic fuel

30.HFO Treatment Plant

HFO when used in gas turbine power plants need to be treated because during combustion impurities can cause corrosion and deposits. Centrifuges are essential for the efficient control and removal of solids and water with salt from fuel oils.

Heavy fuel oils normally contain higher levels of harmful trace elements such as sodium and potassium. With two-stage counter-current washing systems, the degree of purity specified by the gas turbine manufacturer is attained, and the water-soluble trace metal elements are reduced to the specified limits.

The heavy fuel oil is first fed to a pre-strainer. After adding demulsifier to facilitate separation of the dilution water in the purifier, the oil is conveyed to a heat exchanger and is heated to the required temperature. The water separated from the oil in the second stage is added upstream of the first-stage mixer. The heavy fuel oil is mixed with the water in a multistage mixer. Salts in solution with the oil are extracted into the water. The oil/water mixture flows to the purifier in the first washing stage.

The solids are spun out due to the high centrifugal

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force, and the dissolved salts, together with the dilution water, are simultaneously separated out. Water is again added to the purified oil of the second-stage mixer. In the second washing stage, further purification and desalting takes place

31. Main electrical system dataThe export power plant will be located close to the gas and steam turbines.The main electrical system data for the power plant is listed herewith:

No. of gas turbine alternators 1 No. of steam turbine alternators 1 Nominal voltage on turbine

alternators/frequency 11kV/50 Hz Nominal system power 52 MW Power factor 0.85 Plant net efficiency at terminals 43.5% Nominal voltage 11 kV/50 Hz Power Plant utility, main voltages /

frequency 11/6/.44 kV/50 Hz

32. Automatic start-up

Before initiating the starting sequence, the load set point is selected, i.e. base, partial or minimum load, the unit will automatically synchronise and reach the selected load.After activating the master start switch :

The control system verifies all starting permissives;

The fuel delivery pump starts depending on the fuel selected;

The starter equipment accelerates the rotor; Ignition takes place; The main fuel system is then working. Fuel is

admitted to the burners; The starter equipment is switched off and the gas

turbine continues accelerating until it reaches its normal operating speed;

The unit automatically synchronizes, the main braker closes, the load reaches its nominal value according to the selected load set point and according to the allowed load rate.

Normal shutdown After activating the master shut down switch: The gas turbine automatically decreases its load

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according to the allowed load rate; The main braker automatically opens at few MW

power and the fuel stop valves close; The auxiliaries are shut down; The gas turbine turning operation is started.

A restart may be initiated when the ready-to-start lights are “on”, indicating system readiness. This occurs when the gas turbine begins turning gear operation.Emergency shutdown (trip)In case of emergency shut down (trip), the fuel stop valves are immediately closed and the main braker is open, the generator is disconnected from the grid, all blow-off valves open. The emergency shut down can automatically occur due to a general protection of the gas turbine or it can be manually induced by the operator (emergency button). At the control room, time, location and cause of the trip are indicated.Under-over frequency operationReferring to the grid frequency (generator speed) the following will apply:

In the frequency range between 47.5 and 51.5 Hz the gas turbine can operate without any time limitation;

In the frequency ranges 47.5-47 Hz and 51.5-53 Hz the gas turbine can operate for 30 minutes in all its life period and no more than 20 seconds each time (excluding start up, shut down, trip and load rejection transitories);

In the frequency range 51.5-54 Hz the gas turbine can operate for 20 seconds after a load rejection.

Step-up TransformersPower will be delivered to the grid through the existing substation of VCWP. Figure 7.9 shows the possible path (green is the existing line and black dashed is the suggested line) of the cable for the transportation of electricity from the power plant to existing VCW substations.

33. Electrical System

The electrical system of the CCPP consists of:Medium Voltage SystemAuxiliary power for the plant is obtained from station auxiliary power transformers connected independently to each turbine-generator bus, and each transformer will feed one bus of a double-ended medium voltage

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metalclad switchgear lineup. Each station auxiliary transformer is sized to carry the auxiliary load of an entire power block in the event that any station auxiliary transformer is out of service.

The generator bus is connected via bus duct to the primary winding of the station auxiliary transformer. The secondary winding is connected via underground cable to a medium voltage switchgear line-up located in the electrical control room of the steam turbine building.The medium voltage auxiliary switchgear will feed power to the plant medium voltage motor control centers and to the low voltage auxiliary transformers.Low Voltage SystemThe low voltage system is obtained from the medium voltage system transformers. The transformers feed two double ended line-ups of 400V switchgear. Each low voltage transformer is sized to carry the entire load of the line-up, in the event that one of the transformers is out of serviceEmergency Power SystemsThere are multiple separate DC systems included in the power plant. A dedicated 125 V dc system is contained within each individual gas turbine packaged power plant. A separate 125 V dc system provides power for plant auxiliary loads, as well as the plant control system and back-up DC power to the switchyard. A further separate 125 V dc system provides 125 V dc power for the high voltage switchyard.Motor Control Centers & Distribution PanelboardsThe Motor Control Centers (MCC) will contain full voltage, combination starters for the three-phase, 380 V auxiliary motors. Each MCC will also contain molded case circuit breakers fro those non-motor loads not requiring remote control functions, such as a feeder to a 400-220 V transformer, etc. Local panelboards will provide circuits for lighting, receptacles, and other small loads such as motor operated valves and fractional horsepower motors.Electric MotorsLarge motors (>250 HP) are connected to medium voltage motor control centers utilizing vacuum break contactors and multi-function solid-state motor protection modules. Motors 200 HP and below are connected to the 400 V motor control centers.Lighting Systems

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Outdoor lighting will be metal-halide type and will provide illumination in areas of normal pedestrian traffic, such as:

Building exteriors; Transformer areas; Walkways and stairs; Roadways

Indoor lighting will be fluorescent type except in the event that a high bay building is included under which circumstance the lighting should be metal-halide. Emergency lighting will be of the wall mounted battery pack type and will provide adequate illumination for all building egress routes.Grounding SystemAn adequate grounding system must be provided to consist of bare cables and ground rods that provide a metallic connection for all electrical apparatus to be installed in the plant in order to bond all metallic structures and other non-current carrying metal to a common ground potential. The grounding system should be connected to the switchyard grounding system in at least two (2) places.Station Fire Alarm SystemA fire detection system is provided to monitor various areas throughout the combined cycle facility. The system includes a control panel in the Central Control Room, which monitors the status of remote zone panels. The remote zone panels are located in areas throughout the facility and each one monitors the status of various detectors, pull-boxes and fire fighting flow switches. Included in each zone panel and the main control panel is a horn or bell to warn plant personnel

34. Control System

The CCPP Power Plant shall be integrated as part of the overall power grid of Cyprus. Control system interface shall be in the substation. Grid owner shall install control cables from substation interface to CCPP power plant systems. Grid owner control system revisions are not included other than complete access to signal and control information needed for implementation.Signal transfer shall be through fibre optic cables wound into HV cables from substation to control room in order to guarantee a proper interface between

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CCPP power block and power distribution system.All major power plant control options shall be accessible from the control room. Mimics showing the complete power plant status shall be an integrated part of the existing power grid control system.The control system will include:

On screen control; On screen mimics showing all breaker status and

measurements; Presentation on screen and on print of all alarms

and status signals; Log database for alarms and status; Power and energy logs for power plant system

and utility systems; Maintenance schedules (optional); Regulation options for power supply system

according to grid requirements; Set values for all major parameters including

protection devices; Load sharing interface; Managing from CCPP control room of upset and

transient in the Electrical Grid; Readout of fiscal metering station located in

VCWP electrical substation; Monitoring of CCPP operating mode and

monitoring of grid status from CCPP control room

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35 Utility systems

Blow-off systemThe axial compressor of the gas turbine is designed to run at the rated speed of the turbine generator. Since during start-up and shut-down the speed is below the allowed speed range, air must be extracted from selected compressor location in order to prevent compressor surge.

Two blow off lines are connected to compressor stage 5, one to compressor stage 10, and one to compressor stage 15. The blow off lines open into the exhaust gas duct downstream of the gas turbine.The blow off valves have a pneumatic actuator.

The compressed air used as working medium for the blow off actuators is taken from the compressed air tank. The tank is filled with an external air compressor system.

During start-up the blow off valves are closed according to the speed (for fuel gas start-up) or according to speed and power output (for fuel oil start-up).At shut down or trip, all blow off valves open at nominal speed, when closing the fuel stop valves.

Blowdown systemOne blowdown tank, piping and valves is supplied for the HRSG. It will receive blowdown water/steam drains from the HRSG.

Lube-systemThe lube oil system supplies oil to the compressor and turbine bearings of the gas turbine, the gearbox and to the generator bearings. The supplied oil performs several functions: firstly, it forms a film which prevents metal-to-metal contact between shaft journals and bearing shells, thus reducing friction. Secondly, the flow of oil removes heat from the bearing areas. Lube oil is also used to drive the turning gear. In addition it provides jacking oil to lift the shaft at low speed.

The oil tank is used for collection, extraction and de-aeration of the lube and jacking oil. The lubricating

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oil is filled into the tank via a strainer.

Several pumps are provided to ensure supply of lube oil to bearings at the required pressure. Main lube oil pump supplies the lube oil system during normal operation. The system is also equipped with auxiliary oil pump and emergency oil pump. All these are vertical centrifugal pumps, single-stage design. The main and auxiliary oil pumps are driven by three-phase motors, the emergency oil pump is driven by a DC motor (motor starter is not included).

Downstream of the main and auxiliary lubricating oil pumps, the lube oil enters a cooler in order to dissipate the heat. A constant temperature at the inlet bearings is achieved controlling a part of lube oil which bypasses the cooler by a thermostatic valve.

Downstream of the cooler, a duplex filter is located and it holds back any foreign material. One filter only is in operation, whereas the other is in standby.

The lube oil is supplied to the bearings via orifices. The lube oil flows from the bearings back into the lube oil tank through return lines. To protect the bearings, the bearing metal temperatures are measured directly and monitored.

In order to lift the rotor at low speed and to avoid metal-to-metal contact, a jacking oil pump is provided. The jacking oil pump is vane pump driven by a three-phase motor.

The turbine gear is a hydraulic motor which is connected to the gas turbine shaft by a mechanical overrunning clutch. It is actuated by lifting oil from the jacking oil pump by a solenoid valve and a pressure control valve. After every shut-down the shaft must be cooled down for 24 hours by means of the turning gear. Thereafter, the turning gear is operated for 2 minutes every 6 hours to prevent the shaft from bowing. The turning speed is approx. 150 rpm. The turning gear is not required for gas turbine start up. The lube oil system is furthermore provided with a barring gear, which is used for manually turning the turbine shaft, during maintenance or in

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case of emergency.

The lubricating oil tank is arranged between the GT air intake casing and the generator. All components for the lubricating oil supply are installed on the top of the tank except the lube oil cooler.

Fuel gas systemThe fuel gas system supplies the burners with clean and filtered fuel gas and controls the amount which flow into the combustion chambers corresponding to the demand of start-up, operation and shut-down.

The fuel gas must be supplied in dry and clean condition at the fuel gas skid inlet. A strainer prevents particles from damaging the downstream components. The first shut off valve is the emergency stop valve. Its function is to enable or disable the flow of natural gas to the combustion chambers on start-up and shutdown of the gas turbine. It is closed during disturbances when immediate interruption of the gas turbine operation is required (GT trip).

Downstream of the emergency stop valve, the fuel line divides in two branches: the premix line and the pilot line. In each line a control valve is placed. The control valves have also the purpose of second isolating device. Between stop and control valves a vent is located in order to discharge the pressure when the fuel gas system is not in operation (GT standstill).

The pilot gas control valve is used to produce the main flame during GT start up with gas and to accelerate the GT up to full-speed no load. During load operation, it produces a support for the premix flame. The premix control valve is kept to a fixed position during GT start up. After the GT is synchronised to the grid, the premix control valve adjusts the fuel gas quantity to be sent to the premix burners.

The gas turbine is started up mainly with pilot gas, after synchronisation it is loaded directly in premix mode, i.e. the premix control valve opens and the pilot control valve goes to a fix position to sustain

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the premix flame. Strainer, stop and control valves are arranged in compact form (fuel gas package).

Compressor Cleaning SystemThe system is used to remove deposits from compressor blading. Deposits reduce the gas turbine power output and efficiency. Jet nozzles (2) and spray nozzles (20) are uniformly distributed around the circumference of the compressor inlet guide vanes.

A centrifugal pump draws cleaning fluid detergent and/or demineralised water from tank to the Jet nozzles and to the spray nozzles. A manual shut off valve is provided upstream of each nozzle type. A filter prevents clogging of the nozzles. Two type of compressor cleaning are available: OFF line and ON line cleaning.

OFF line cleaningThis procedure is performed by shutting down the gas turbine and keeping it in turning gear operation for about 6 hours. Then the speed is run up to 600 rpm by the start up converter. The pump is activated and the manual valves of nozzles opened. The detergent is injected through the first two row of compressor moving blades by the jet nozzles and then by the spray nozzles which generate a spray flow. The drain valves are opened. After the rinsing procedure, the speed is increased at nominal speed to dry. At the end of the procedure, the pump is disconnected, all the manual valves (to nozzles and drains) closed.

ON line cleaningThis procedure is possible at load of about 70% (base load with opened inlet guide vanes). The drain manual valves must remain closed and the jet nozzles are not to be used. On line cleaning is only permissible with spray nozzles. The on-line washing is not suggested. It can be done only if strictly necessary.

The compressor cleaning system is a portable unit consisting of a tank (300 litres), a centrifugal pump, a strainer, a connection hose.

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Plant Drains

Various high pressure drains including those from the stop valve and the steam supply to the steam seal regulator will be taken to the condensate receiver. Drain lines required for start-up of the steam cycle should be fitted with motor-operated shut-off valves. Various drains which are not highly essential to start-up but are required steam piping drains may be fitted with steam traps.

Drainage SystemThe drainage system removes the fuel oil not ignited during a false start-up and discharges the water after off line compressor cleaning operation.

In case of fuel oil false start-up, i.e. no flames appear after ignition, the unburned fuel oil is discharged into a disposal tank. For this purpose, two solenoid valves are provided. The fuel oil drain after false start-up is automatically performed by opening the solenoid valves, when the turbine speed drops under a certain value.Other water drain valves are provided. They are manually actuated. They must be opened in case of off-line compressor cleaning. For gas turbine operation they must be in the closed position.

All the solenoid and the manual valves are located under the combustion chambers and the turbine.

Site DrainsThere are two types of site drains, those emanating from areas that should not be contaminated with oil and those which may be contaminated with oil.Non-contaminated building drains and storm drains are sent to the terminal point either by gravity flow or pumping as required, and are connected to the VCWP central drainage system.

All possible contaminated drains are sent to the oily water disposal tank by gravity flow or pumping (as required). The collected oily waste will be delivered to a licensed collector for proper treatment.

Hydraulic Oil SystemThe hydraulic oil system has the purpose of

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positioning the fuel oil and the fuel gas control valves according to the fuel controller requirements, opening or closing the fuel emergency stop valves when the system is started or stopped. In addition, the system immediately closes the emergency stop valve in case of faults which demand immediate gas turbine shut-down (trip).The control device which adjusts the hydraulic oil supply to the actuator is directly mounted on the valve actuators so that each valve is a very compact unit.

Two accumulators serve the purpose of ensuring that sufficient hydraulic oil quantities are made available anytime.

The hydraulic oil system includes the following elements:

Hydraulic oil tank : it is in stainless steel, baffled, sized for 5 minutes retention, it is provided with level and temperature monitors. The hydraulic oil tank includes the following components.Main hydraulic oil pump : it is horizontally mounted, AC motor driven, positive displacement. It has a pressure-dependent control system which continuously adjusts the amount of hydraulic oil to be supplied to the valve actuators. It is always in operation when the gas turbine is in operation.Auxiliary hydraulic oil pump : it is horizontally mounted, AC motor driven, positive displacement (identical to the main pump). It is in stand by during normal gas turbine operation, it is switched on in case of main hydraulic pump failure, during the diffusion- premix switching, during the start up and shut down.Two filters : at the delivery side of each pump there is a simplex filter (nominal filtration 5 |.im).Two accumulators : they supply the valve actuators with hydraulic oil in the event that both pumps have a failure, in this case they ensure a safety shut down of the gas turbine.Cooling fan : when the hydraulic oil temperature exceeds a certain value, the fan is started up until the temperature reaches again its normal value.

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No additional hydraulic oil heating is required as the main and the auxiliary hydraulic oil pumps are put in operation when the oil temperature drops under a certain value.

The hydraulic oil supply station is connected to each actuator via one oil supply line, one oil return line and one oil leakage line.Temperature, pressure and level of the hydraulic station supply unit are continuously monitored.

The fuel control valves have identical actuators, each provided with servovalve and two pilot solenoid valves, each equipped with position transmitter (LVDT).The fuel gas emergency stop valve, the fuel oil return emergency stop valve, the fuel oil emergency stop valves have identical hydraulic actuators, each provided with limit switches and two pilot servo-valves.

Flushing water system

The flushing water system has the task of supplying the volume of flushing water (demineralized water) required for various tasks. Flushing water is required to clean and purge the fuel oil diffusion and premix line after operation in order to avoid coking of fuel oil residues. In addition, flushing water is also injected during changeover from fuel oil diffusion mode to premix mode to cool the premix burners.To fill the purge water tank, the purge water system must be connected to the plant's demineralized water supply.

The system consists of a plastic water tank, a water strainer, a water pump located downstream of the strainer and a solenoid valve. The pump is a positive displacement type with a constant delivery rate of approximately 1.4 litre/sec.

Downstream of the solenoid valve, the circuit divides in three branches: one for the fuel oil feed line to the diffusion burners, one for the fuel oil feed line to the premix burners and one for the fuel oil return line. Solenoid valves enable or disenable the flow of flushing water to the respective sections.

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The washing water system includes the following components:

Flushing water tank: the volume of the tank (160 liter) is sufficient for performing all cooling and flushing operations of a single fuel oil operating cycle in the vent of a failure of a tank filling system; the tank is provided with a vent.A pressure transducer on the drain line on the bottom on the tank measures the water level in the tank. The pressure signal commands the open/close position of the filling solenoid valve.

Filter: it prevents particles to pass and affect the fuel oil burners; the mesh size is 250 um.

Water pump: it is a positive displacement pump with a 25 bar nominal pressure, equipped with pressure control valve required for starting the pump, installed in the branch line and with a safety valve. The monitor MBN81CP001 controls the water pressure in the supply line.Three solenoid valves one for the fuel oil diffusion feed line, one for the return line, and one for the fuel oil premix fed line.

The washing water system is operated in four cases: by switching over from fuel oil diffusion operation

to premix operation, premix burner nozzles are to be cooled;

after switching over from fuel oil premix operation to diffusion operation, premix burners are to be washed in order to residual oil from the burners and from the ring pipes;

After switching off the fuel oil system, diffusion burners are to be washed for the same above reason;

By switching over from natural gas operation to fuel oil operation, the return-flow pipe of fuel oil diffusion burners is to be filled before the return-flow cut-off valve opens.

Ignition systemThe main fuel of the gas turbine must be ignited on gas turbine start-up by means of ignition flames. For this purpose each burner is equipped with a spark

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plug.

According to the selected fuel for start-up, the ignition fuel is:

fuel gas taken directly from the fuel gas supply line, when the start-up fuel is “fuel gas”,

propane, taken from a tank, when the start-up fuel is “fuel oil”. In case of fuel gas start-up, the ignition system is not activated.

The ignition gas system (used only in case of fuel oil start-up) consists of a tank, two solenoid valves, pressure control and relief valve. When the ignition speed is reached, the solenoids valves are opened in order to allow the ignition gas flow to the burners and at the same time all transformers are supplied with power. Pressure switches check the ignition gas pressure during the ignition phase.

Solenoid valves and pressure switches are located close to the gas turbine.

Water supply and treatment systems

Water supply and treatment shall be provided for the CCPP to serve the following consumers:

service water system; drinking water system for power plant and

residential area; de-mineralized water system; fire fighting water system

The total water demand of the power plant, including potable and recycled water is estimated to 13,2 m³/h.

Drinking water will be supplied from the potable water network of the VCWP. Service water and de-mineralized water shall preferably be supplied from the recycled water (tertiary treated) of the Limassol Sewerage Treatment Plant.

The de-alkalized water is stored in four demi-water storage tanks with a storage capacity of 200 m³ each. Adequate storage capacity (dead storage) will also be provided to serve the fire fighting system. Service water is taken directly from this storage

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facility without any further treatment. The needed de-mineralized water for the CCPP is provided by treating water in a reverse osmosis (RO) plant (15 ton/h capacity) to reduce its conductivity and to remove organic impurities. Then it is suitable for further treatment in a mixed bed ion exchanger plant for use as make-up water in the CCPP.

Water treatment systems

De-mineralization (DM) plantAn optional demineralized water system, or a supply of suitable boiler make-up water is required. The make-up water should contain not more than 0.1 parts per million (ppm) dissolved solids, 0.05 ppm dissolved silica and have a conductivity of not more than 0.25 micromohms.

The demineralized water system, if provided will be skid mounted and provided with piping, valves, instrumentation and controls for automatic/manual operation. The unit is provided with anion and cation exchange units, degasifier, mixed bed exchanger, transfer pumps, acid and caustic regeneration systems, and instruments and controls.

The output from the emineralizer flows to the demineralized water storage tanks. Demineralized water system drains are neutralized, settled and drained to a site battery limit where they will have to be properly disposed of.

Chemical dosing and samplingFor regulation of the correct chemical operating parameters of the boiler feedwater and hence the required steam quality for the steam turbine and for protection of the internal surfaces of the boiler tubes, chemical dosing stations shall be installed, consisting of three separate subsystems that serve :

the HRSG; the condensate system and a separate subsystem that provides corrosion

inhibitor into the auxiliary cooling water system is required.

Final specification of the chemical feed system is dependant on the HRSG/OTSG selection and other

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process requirements.

The three subsystems feeding the condensate system and HRSG / OTSG are phosphate injection, oxygen scavenger injection and amine injection. The phosphate injection system will convert calcium and magnesium salts to their respective phosphate compounds which are then removed by the HP steam drum blow-down. The oxygen scavenger is required to minimize corrosion in the condensate system while the amine is used to maintain a high pH level. The corrosion inhibitor system feeds the auxiliary cooling water header tank with a chemical required to minimize corrosion in the system.

For regulating water and steam quality, sampling stations shall be provided and installed at a convenient location for on-line analysis. It shall include:

pH meter for measuring feedwater alkalinity conductivity meter residual oxygen measurement device.

Mode of operation of all treatment plantsThe CWTP, RO plant, evaporation exchangers of the DM plant, dosing system and dosing plants shall be equipped with fully automatic control systems. For the DM plant, this shall enable the regeneration cycle of the mixed bed ion exchanger to be started and run fully automatically following starting by the operator. Standby trains shall be put into operation automatically. Control and monitoring of the plant shall be from the Central Control Room with provision for manual intervention locally.All instrumentation needed for safe and satisfactory operation and supervision of the plant shall be provided.Other systems

Emissions Monitoring EquipmentEmissions monitoring equipment may be provided if required to monitor the exhaust of the gas turbine and report levels of contaminates such as sulphur dioxide (SO2), carbon monoxide (CO), nitric oxides (NO), and others as specified by the project. The equipment is usually housed in a dedicated enclosure near the plant exhaust stacks.

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Water Sampling / Monitoring PanelA water sampling panel is supplied to monitor the condition of the boiler feedwater, condensate water and steam conditions. Oxygen content, ph levels and others as required are monitored to assist the operator in determining the requirements for the plant chemical injection system.

Cranes, lifts and hoistsAccording to individual needs for maintenance purposes, respective mobile cranes, hoists and/or other lifting tackles will be foreseen.

Instrument and service air systemFrom a centralized compressed air system, clean dry air for pneumatic instrumentation and compressed air for pneumatic tools and maintenance purposes shall be supplied. Instrument air is required for the various air-operated valves and instruments in the power plant while service air is used for such things as power tools. Instrument air is dried by air dryers such that it has a dew point of -40 F.

The normal supply of instrument and service air during normal plant operation is from the discharge of the gas turbine compressor. A portion of this air is the directed to an air receiver.

Compressed air for start-up and back-up is supplied by two (2) 100% reciprocating compressors.

Before entering the air receiver, the gas turbine’s compressed air is pressure reduced by a pressure control valve and cooled via an aftercooler. A pressure control valve located on the service air distribution system is included to ensure that air cannot flow to the service air distribution unless the pressure in the air receiver is high enough to satisfy the requirements of the instrument air system. This ensures the the instrument air system requirements will always be satisfied prior to allowing for the service air requirements.

Air directed to the instrument air system passes through the instrument air dryer skid. Here, air

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passes through filters and a dryer prior to entering the instrument air distribution system. There are two (2) dryers on the skid. One dryer is operating while the other is regenerating itself.

Should the air supply from the gas turbine compressor be inadequate or unavailable, air is supplied via one of two back-up motor-driven compressors.

Auxiliary steam and condensate return systemAn auxiliary LP steam header shall be provided for the power plant.The auxiliary steam system supplies the following systems:

ejector for evacuation of each condenser gland steam for the steam turbine pipe cleaning during commissioning and other consumers.

During start-up, steam is generated in the auxiliary boiler, while during normal operation the LP steam header will be supplied from the HRSG. The auxiliary boiler shall be fired by diesel or fuel gas.

Nitrogen systemThe nitrogen system shall consist of bottle racks with a sufficient number of bottles for purging of sections of the gas pipeline system during maintenance and in emergencies. For this purpose, purge connections on the pipes shall be provided at convenient locations.

Firefighting, detection and alarm systemWater for firefighting is taken from the raw water/firefighting storage tanks. These tanks shall be designed so that the storage capacity required for firefighting is always maintained, which means it cannot be used for other purposes.The firefighting water system shall comprise the following major components:

firefighting water pump station with 2 x100 % electrically driven pumps connected to a power supply fed by an emergency diesel set as emergency power supply

underground main piping system (ring system) with:

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o isolating valves for sectionalizing;o connection lines to the various service areas;o outdoor hydrants of underground types for

connection to main pipe;o indoor water hose reels at various service

areas;o foam/water hydrant facilities for fuel oil tank

area and for other areas, if applicable according to the bidders’ requirements.

Further firefighting, protection and detection systems comprise:

spray water systems, such as for oil-filled transformers, lube oil facilities, etc.

CO2 systems for electrical facilities, if applicable according to the bidders’ requirements

mobile fire protection equipment firefighting control system fire alarm and detection system (with a main

panel in the central control room).

Ventilation and air-conditioning systemsAir-conditioning

An air-conditioning system shall be provided as a minimum for the following buildings or parts of buildings, to maintain a suitable environment for personnel, controls and computer equipment:

central control room; electric, switchgear rooms; workshop; administration area; etc.

Refrigeration systemChillers shall be provided for cooling of the supply air of all air-conditioned buildings. The chillers and circulation pumps shall be located outdoors, adjacent to the main consumers.

Ventilation systemEquipment for adequate ventilation shall be installed as it is required.

Chemical laboratoryFor various purposes of the plant and to ensure and monitor the required quality for the different flow media as well as to identify any contamination from leakage, a chemical laboratory shall be provided.

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Its main task will be analysis of: water samples from the different sampling

stations for steam, blowdown, feedwater, condensate and cooling water;

HFO, fuel gas, and lubricating oil sewage and wastewater Corrosion protection For corrosion control of ferrous metals in

contact with: soil, water or buried or immersed concrete

Cathodic protection systems will be installed (i.e. for relevant equipment within the power plant boundary as well as for ferrous gas and water pipes), if no other suitable

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