2-1 Tech Spec Ashuganj R0

5. MECHANICAL SYSTEMS 5.2 HEAT RECOVERY STEAM GENERATOR

MITSUBISHI

Bangladesh Ashuganj CCPP

Specification No. MP-A2292

5 - 2 - 1

This document contains information proprietary to Mitsubishi Heavy Industries, Ltd. It is submitted in confidence and is to be used solely for the purpose for which it is furnished and returned upon request. This document and such information is not to be reproduced, transmitted, disclosed or used otherwise in whole or in part without the written authorization of Mitsubishi Heavy Industries, Ltd.

CONTENTS

5.2.1 INTRODUCTION

5.2.2 GENERAL

5.2.3 STEAM DRUM

5.2.4 HEAT TRANSFER TUBES, CONNECTING PIPES, HEADER AND VALVES

5.2.5 STEEL STRUCTURES

5.2.6 STAIRWAYS AND PLATFORMS

5.2.7 CASING

5.2.8 INSULATION

5.2.9 DUCTWORK AND STACK

5.2.10 SAFETY VALVES


MITSUBISHI



5 - 2 - 2


5.2.1 INTRODUCTION

This section describes of the Heat Recovery Steam Generator (HRSG) for Ashuganj CCPP project in Bangladesh. We will supply one HRSG which will generate steam by the heat of the exhaust gas from one MITSUBISHI 701F gas turbines.

5.2.2 GENERAL

The hot exhaust gases, which are discharged from the gas turbine, are channeled through an HRSG in order to heat incoming feedwater and subsequently generate saturated and superheated steam. The exhaust gas exits the HRSG through an exhaust stack. HRSGs contain an array of equipment, including interconnected banks of tubes, steam drums, headers, connecting pipes, and other components. The tube banks within the HRSG are arranged in a particular order to optimize the heat exchange process. The various tube banks included in an HRSG are economizers, evaporators, superheaters and reheaters. The tubes have fins — that is, metal projections from the outer wall of the tube that increase the surface area for the transfer of heat from the exhaust gas outside the tube to the water or steam flowing inside the tube. The steam production process starts with water entering the HRSG from a feedwater system. The feedwater first enters each (three pressure levels) economizer tube bank. The economizer heats the water to a temperature slightly below the boiling point.


MITSUBISHI



5 - 2 - 3


Water leaving the economizer enters a steam drum. A portion of the water, which flows through the evaporator tube bank, is converted into steam (or evaporated). The resulting steam/water mixture exits the evaporator tubes and enters the steam drum. Steam drums are large diameter cylindrical vessels, which are located above the evaporator banks. A steam drum’s functions are described in detail below. In the superheater, the steam is “superheated” above the boiling temperature, and then leads to the steam turbine. There are three differential pressure cycles, that is

HP cycles : High pressure cycle IP cycles : Intermediate pressure cycle (including reheater section) LP cycles : Low pressure cycle

The tube banks located within an HRSG consist of fin tubes. The hot gas turbine exhaust at the inlet flows toward the HRSG outlet of gas side, and the heat absorption of cool water temperature starts from the HRSG outlet of gas side toward the HRSG inlet of gas side.

The superheated steam then expands through the HP steam turbine — turning it and the electrical generator to which it is connected, and in the process losing both pressure and temperature. The steam is collected and flows back to the HRSG to be reheated at an intermediate pressure by passing through a reheater tube bank. This “reheat” steam then returns to power a different part of the IP turbine. When the steam has completed its work in the turbine, the steam is turned back into water in the condenser following the turbine outlet, and returned to the feedwater portion of the cycle and back to the HRSG. This condensate is subjected to a deaeration process; in which dissolved air is removed from the liquid water. This feedwater is then pressurized via


MITSUBISHI



5 - 2 - 4


feedpumps and fed to the inlet of the each pressure level economizer, where the cycle is repeated.

5.2.3 STEAM DRUMS

(1) We will supply steam drums as follows for each HRSG:

(a) One (1) high pressure steam drum

(b) One (1) intermediate pressure steam drum

(c) One (1) low pressure steam drum

(2) The purposes of the steam drums are as follows:

(a) To separate and purify the steam from the water via various drying devices and deliver the steam through a series of saturated steam pipes to the inlet of a tube bank “superheater”.

(b) To mix the incoming feedwater water from the economizer with the saturated water from the evaporator.

(c) To mix chemicals with the feedwater and direct that treated water back to the inlet section of the evaporator through a series of pipes “downcomers”.

(d) To remove part of the water through “blow-down” in order to control the boiler water solids and quality.

(e) To provide adequate storage capacity to accommodate changes in boiler load, especially during transient operations, while being able to maintain control of the aforementioned capabilities.


MITSUBISHI



5 - 2 - 5


5.2.4 HEAT TRANSFER TUBES, CONNECTING PIPES, HEADER AND VALVES

(1) The heat transfer parts of the HRSG consists are as follows:

(a) High pressure superheater section

(b) High pressure evaporator section

(c) High pressure economizer section

(d) Reheater section

(e) Intermediate pressure superheater section

(f) Intermediate pressure evaporator section

(g) Intermediate pressure economizer section

(h) Low pressure superheater section

(i) Low pressure evaporator section

(j) Low pressure economizer section

(2) The function of heat transfer parts are as follows:

(a) The economizers recover the remaining thermal energy contained in the flue gas at the evaporator outlet and heat feedwater before entering the steam drums.


MITSUBISHI



5 - 2 - 6


(b) Saturated steam is generated at the evaporator and the steam drum.

(c) The superheaters heat the saturated steam from the drum up to the specified temperatures.

(d) The reheaters heat the mixed steam with exhausted steam from the HP steam turbine and the steam from the IP superheater up to the specified temperature.

(3) The fins are spirally attached around the tubes by means of resistance welding method.

5.2.5 STEEL STRUCTURES

The steel structure is provided to support the HRSG and its auxiliary equipment, piping, ducts and platforms. The structure is designed to withstand wind and seismic forces. Erection loads and other forces resulting from expansion and/or contraction of ducts, piping, structural steel and so on are also considered.

5.2.6 STAIRWAYS AND PLATFORMS

Platforms are provided around the drums. Stairways and/or ladders are provided to access the platforms and the manholes. One main stair from ground level up to the drum level is provided. All platforms and walkways are provided with handrails.


MITSUBISHI



5 - 2 - 7


5.2.7 CASING

Heat transfer surface is enclosed by a cold casing that is lined with internal insulation and liner plate. The casing is made of welded steel sheet panels and is suitably thickened and reinforced. The flue gas path through heat transfer surface is gastight to prevent leakage and bypassing of hot gas within the casing. The casing and tube supports are designed to allow full expansion of tubes. Penetration of the casing required for piping connection or other pressure part is sealed. Access manholes are provided in the side casing at bottom header level.

5.2.8 INSULATION

The flue gas inlet duct and HRSG casing are internally insulated. And outlet duct is externally insulated. The outer surface temperature of them will be designed adequately low in accordance with manufacture’s standard to prevent scald and excessive heat loss. Studs used for attachment of insulation is adequate material in length suitable for the insulation thickness.

5.2.9 DUCTWORK AND STACK

HRSG inlet duct, HRSG outlet duct and stack are provided. For optimized flue gas distribution, the HRSG inlet duct configuration is constructed so as to reduce the velocity head and properly distribute the flue


MITSUBISHI



5 - 2 - 8


gas to heating surfaces. HRSG exhaust stack is furnished with interconnecting ductwork from the HRSG outlet. The stack is designed to withstand flow-induced vibration.

5.2.10 SAFETY VALVES

The safety valves are of spring loaded type, workshop tested and fitted on drum and superheater, and equipped with outlet silencers. They shall be capable of discharging at least 100% of the maximum steam generating capacity of the HRSG.

5 MECHANICAL EQUIPMENT 5.3 STEAM TURBINE

MITSUBISHI Bangladesh Ashuganj CCPP


5 - 3 - 1

This document contains information proprietary to MITSUBISHI HEAVY INDUSTRIES, LTD. It is submitted in confidence and is to be used solely for the purpose for which is furnished and returned upon request. This document and such information is not to be reproduced, transmitted, disclosed or used otherwise in whole or in part without the written authorization of MITSUBISHI HEAVY INDUSTRIES, LTD.

5.3.1 TURBINE OUTLINE

5.3.2 TURBINE COMPONENTS

5.3.3 TURBINE VALVES

5.3.4 GLAND AND DRAIN SYSTEM

5.3.5 CONTROL AND LUBRICATING OIL SYSTEM

5.3.6 DESCRIPTION ON THE SYNCRONOUS CLUTCH

BETWEEN ST AND GENERATOR




5 - 3 - 2


5.3.1 TURBINE OUTLINE

This unit consists of one cylinder, single axial exhaust, condensing reheat turbine

designed for high operating efficiency and maximum reliability.

The construction of the entire turbine is shown in the outline drawing, attached at

the end of this section as C00-500.

The HP steam from one set of the HP stop valve and HP control valve enters the HP

turbine through an inlet pipe.

The steam flows through the HP blading producing the power, decreasing its

pressure and temperature, and enters the HRSG.

The IP steam from HRSG enters the IP turbine through an inlet pipe and enters the

IP blading.

The LP steam from the LP stop and LP governing valves is mixed with the IP

turbine exhaust flow in the casing.

The steam flows through the LP reaction blading and flows axially through an

exhaust cone, thence to a condenser.

The low pressure element incorporating high efficiency blading, and diffuser type

exhaust, and improved exhaust hood design have resulted in a significant

improvement in turbine heat consumption.




5 - 3 - 3


5.3.2 TURBINE COMPONENT

(1) Blading

The blade path includes the single flow impulse and reaction blading in the high and

intermediate pressure part and the single flow reaction blading in the low pressure

part.

The interstage seals are of labyrinth type fitted at small diameters on the shaft thus

ensuring minimum stage leakage losses.

The reaction type blading is adopted in low pressure end part of turbine because of

its high efficiency in larger volumetric flow part. In the reaction blade path, the

steam velocity is relatively slow resulting lower friction loss, namely better

aerodynamic efficiency.

In process of the low pressure end blades design, the careful considerations are

made for the prevention of the erosion as well as for the better performance. The

moisture or drips flow in the blade paths has been investigated and the blade path

has been improved considering the test results. Beside of this, enough length of

stellite strip is attached into the leading edge of last rotating blade. All the long

blades are manufactured under severe quality control.

Blades are manufactured of corrosion and erosion resistant alloys with the high

damping coefficient for vibration, developed through the extensive research.

(2) Rotor

The material of turbine rotor has excellent creep rupture strength, high tensile

strength with excellent ductile quality. This rotor has a thrust balance piston to have

a good thrust balance opposed to a reaction force of the blades.




5 - 3 - 4


The rotor diameters are so selected to give their critical speeds properly apart from

the running speed.

The rotor surface geometry is carefully designed to give least stress concentration

for the transient thermal stress as well as the bending stress.

(3) Shaft System

The shaft system consists of one gas turbine, generator and one steam turbine, and

these parts are connected with a SSS clutch which can transmit necessary torque and

absorb shaft system thermal expansion.

(4) Casing

The structural shape of the casing and the method of support are carefully designed

to obtain free but symmetrical movements due to temperature changes and thereby

reduce the possibility of distortion to minimum.

The complete casing is made in two section, the high and intermediate pressure

section being of cast steel and the low pressure section of steel plate. Each section is

split in the horizontal plane through the axis so as to form a base and cover. During

the installation the vertical joint is made up permanently and thereafter the cover is

handled as a single piece. A complete inspection can be made by removing the cover

only and the base need not to be disturbed after installation.

The low pressure end of the cylinder is supported by feet. These supporting feet rest

on seating plate which is mounted on the concrete foundation with adjusting liners.

The position of the cylinder at this end is maintained by three keys placed between

the supporting feet and the seating plate. Two of these keys, placed transversely on




5 - 3 - 5


the transverse centerline of the exhaust definitely locate the cylinder in an axial

direction but permit free expansion in a transverse direction.

The third key placed axially on the longitudinal centerline just below the low

pressure side bearing pedestal definitely locates this end of the cylinder in a

transverse direction but permits free expansion in an axial direction. Therefore, from

a point at the key the cylinder can expand freely in any direction in the horizontal

plane at the top of the foundation seating plate.

At the high pressure end the cylinder is supported by two arms (or lugs) which are

cast integrally at the top of the base. These arms rest on a separate pedestal and are

free to slide in a transverse direction being secured only loosely by bolts. The

cylinder is connected to the pedestal by a channel beam (centering beam) and pins

placed on the longitudinal centerline thus maintaining the correct axial and

transverse position of the cylinder with relation to the pedestal.

The base and cover of the cylinder are bolted together by large studs and bolts. In

order to obtain the proper stress in each of these studs, they must be tightened

sufficiently to stretch them a definite amount.

(5) Bearings

The turbine has one journal bearing and one journal-thrust combined bearing, of

forced lubricated type.

For the journal bearing, the self-aligning spherical seated type is adopted, in order to

get good bearing alignment along the shaft.

The vertical and horizontal location of the bearing in the pedestal will be

accomplished by inserting or removing liners between individual keys and the shell.

The stop dowel in lower half of the bearing shell projects into the notch in the




5 - 3 - 6


pedestal, thus preventing rotation of the bearing relative to the pedestal. The positive

supply of the lubricating oil assure through drilled passages in the pedestal, the key

and the shell halves.

The thrust bearing is of the leveling type, which automatically distributes the load

equally among the several shoes.

The leveling plates allow the shoes to take a position so that the center of the

loading of the babbitt faces is all in the same plane by means of their rocking

motion.

The thrust of the rotor is transmitted to the shoes by the steel collar. A full

complement of shoes is provided on each side of the thrust collar to carry the thrust

in either direction.

All the bearings have an indicating dial thermocouple to measure the oil drain

temperature and a thermocouple to measure the bearing metal temperature.

The turbine is incorporated with grounding device to prevent the shaft voltage

trouble.

(6) Turning Gear

Turbine has a turning gear to maintain the good condition of gas and steam turbine

rotors while the turbine is shut down.

Turning device has necessary provisions for automatic turning gear engagement and

disengagement.




5 - 3 - 7


5.3.3 TURBINE VALVES

(1) HP Stop Valve

The turbine has one HP stop valve for quick stop and speed control at starting,

which are driven by hydraulic servomechanism.

This is an oil operated "Plug" type valve operating in a horizontal position with the

body formed as an integral part of the steam chest.

The steam strainer cylindrical in shape fits around the valve.

Testing switch for partial stroke smooth closing of the valve while unit is in

operation is provided in the central control room.

(2) HP Control Valve

The turbine has one HP control valve, which are controlled by individual hydraulic

servomotor.

The steam valve is a ring sealed plug type valve mounted on the shouldered valve

stem. The diameters of upper seat and lower seat of the valve are so designed as to

balance the steam pressure force acting on the valve. Thus the valve can be open and

closed easily at any pressure.

When in the closed position, the load of the compression spring acting through the

pin and valve stem holds the valve tightly on its seat.

The valve stem packing consists of a closely fitting bushing provided with a suitable

leakoff opening which should be connected to a zone of lower pressure as

determined by the operating steam conditions.

A shoulder is formed on the valve stem, and it seats on the lower end of the valve

stem bushing when the valve is in its fully open position. This arrangement prevents




5 - 3 - 8


steam leakage along the stem while the unit is in operation with control valves fully

open.



(3) Reheat Stop Valve

The turbine has one Reheat stop valve, which is driven by on-off control of a

servometor. Testing switch for partial stroke smooth closing of the valve while unit

is in operation is provided in the central control room.

(4) Interceptor Valve

The turbine has one Interceptor valve, which is controlled by individual hydraulic

servomotor. The steam valve is a ring sealed plug type valve mounted on the

shouldered valve stem. The diameter of upper and lower valve seats are so designed

as to balance the steam pressure force acting on the valve. Thus the valve can be

opened and closed easily at any pressure.

When in the closed position, the load of the compression spring acting through the

pin and valve stem holds the valve tightly on its seat.

The valve stem packing consists of a closely fitting bushing provided with a suitable

leakoff opening which should be connected to a zone of lower pressure as

determined by the operating steam conditions.

A shoulder is formed on the valve stem, and it seats on the lower end of the valve

stem bushing when the valve is in its fully open position. This arrangement prevents

steam leakage along the stem while the unit is in operation with control valves fully




5 - 3 - 9


open.

The steam strainer cylindrical in shape fits around the valve.



(5) LP Stop and control Valve

The turbine will be provided with one LP stop valve and one LP control valve which

are driven by hydraulic servomotors.




5 - 3 - 10


5.3.4 GLAND AND DRAIN SYSTEM

The function of the rotor steam gland sealing system is to prevent leakage of air into,

or the steam from, the turbine cylinders along the rotor ends.

This function is accomplished by the following components:

Gland Steam Controller (To be provided by Purchaser)

The purpose of the gland steam controller is to supply sealing steam at a constant

pressure to the turbine glands throughout the start-up, operation, and shut-down of

the turbine.

The controller is adjusted such that at start-up all of the gland sealing steam is

supplied from the high pressure steam supply line through the control valve.

As load increases, increment of leakage steam from high pressure gland reduces the

required external sealing steam.

When the leakage steam from the high pressure gland is in excess of the sealing

steam requirement of the low pressure gland, the control valve regulating the high

pressure steam closes, and the spill-over valve begins to open and passes the excess

steam to a zone of lower pressure in order to maintain the desired sealing steam

pressure as determined by the pressure regulator setting.

The above mentioned sealing equipment is automatically controlled, but can also be

manually controlled.




5 - 3 - 11


Drain System

The most important thing in turbine operation is to never introduce water into the

turbine.

Condensation, which may be produced in the turbine at start-up or low load, is

routed to the condenser or other equipment through continuous drain orifices and air

operated drain valves (to be provided by Purchaser).

Exhaust Hood Sprays (To be provided by Purchaser except for the spray nozzles)

Automatic sprays are provided to prevent high exhaust temperature of LP turbine.

Temperature control valves control the flow of water from the condensate pump

discharge to spray nozzles installed in the turbine exhaust hood chambers.

Overheating of the exhaust end is not expected even with no load steam and full

vacuum.

The temperature controller for the exhaust hood sprays is set to control exhaust hood

temperature to 70 °C maximum

If a temperature in excess of 80 °C is obtained, care must be taken to gradually

lower the temperature of the exhaust casing by increasing load or improving the

vacuum

The limiting exhaust casing temperature is 120 °C. If this temperature is reached,

the unit should be shut down and the trouble corrected before restarting.




5 - 3 - 12


Gland

The rotor glands are of the spring backed labyrinth type.

Refer to the following drawings for details of the gland system:

Title Drawing No.

Gland Steam and Drain Piping Diagram C00-506




5 - 3 - 13


5.3.5 CONTROL AND LUBRICATING OIL SYSTEM

The control and lubricating oil system are provided as common equipment for both

gas turbine and steam turbine.




5 - 3 - 14


5.3.6 Description on the Synchronous Clutch between ST and Generator

(1) Benefits of Using the Synchronous Clutch

MHI offers the single shaft system including the gas turbine, steam turbine and

synchronous clutch. The reason why this type of arrangement has been selected is

listed below.

(a) High Efficiency

In this shaft arrangement, the axial exhaust steam turbine can be adopted because

the thermal elongation of the steam turbine cylinder, which is absorbed by the clutch,

can be isolated within the steam turbine side and no significant thrust force and

elongation can be transmitted into the generator side.

The axial exhaust type steam turbine has an advantage on the efficiency than the

down exhaust type because the negative effect on the efficiency ,i.e. the flow

turbulence and mixing, is almost minimum in the axial exhaust type.

(b) Reduced Start-up Loss

Synchronous clutch allows the gas turbine and generator to be accelerated without

steam turbine. This allows the required starting equipment power can be minimum

and no cooling steam introduced into the low pressure blades are required.




5 - 3 - 15


(c) Easier Operation

No complicated start-up procedure is required because the last blade cooling steam

injection is not necessary.

(d) Lower Foundation Height

Because of adopting the axial exhaust steam turbine, the foundation height becomes

lower in comparison with the down exhaust type.




5 - 3 - 16


(2) Configuration and Operation

In fig.1 the complete shaft arrangement is listed. During the start-up period, the gas

turbine and generator system will be operated at first without steam turbine coupled

condition. After the gas turbine power and the appropriate steam condition from the

steam generator is established, the steam will be introduced into the steam turbine

and finally, steam turbine will be coupled with the gas turbine and generator system.

Thrust Bearing Rigid Coupling

Thrust Bearing

Synchronous Clutch

Fig.1 Complete Shaft Arrangement

Fig.2 Shaft Arrangement during the Start-up Period




5 - 3 - 17


(3) Experiences on using the Synchronous Clutch

Table1 summarizes the MHI’s experiences on using the Synchronous(SSS) clutch.

No Country Unit Name Clutch

Transmitting Power(MW)

Year in Operation

1 KOREA ILSAN #1 130 1993

2 KOREA PUCHON #1 95 1993

3 KOREA ILSAN EXTENSION 72 1996

4 PAKISTAN WAPDA 34 1984

5 JAPAN MISHIMA PAPER 1.3 1989

6 JAPAN KIRIN 3.6 1993

7 MEXICO CAMPECHE 100 2003

8 TAIWAN NANPU 90 2003

9 KOREA HWASEONG 100 2007

10 IRELAND HUNTSTOWN 140 2007

11 KOREA PAJU 100 2010

12 JAPAN SAKAIDE 100 2010

ALTERNATIVE GENERATOR PROPOSAL CASE

―――――――――――――――――――――――――――――――― ―――――

―――――――――― MITSUBISHI ELECTRIC CORPORATION―――――――――― 5-4-1

5.4. GENERATOR AND AUXILIARIES 5.4.1 Generator Generator will be designed and manufactured based on the following basic conditions;

(a) Stator winding and core are hydrogen directly cooled type and rotor winding is also hydrogen directly cooled type.

(b) Generator excitation system is static type. (c) Hydrogen sealing is vacuum-treating-type seal oil system.

5.4.1.1 Specification of Generator (a) Type Horizontally mounted cylindrical rotor, rotating field

type with explosion proof structure and for indoor installation

(b) Number of sets One (1) set (c) Applied Standard IEC 60034 (d) Rated output 567 MVA (at cooling water temperature of 31 oC) (e) Power factor 0.85 lag (0.95 lead) (f) Rated voltage 18 kV (g) Rated current 18187 A (h) Frequency 50 Hz (i) Number of poles 2 (j) Rated speed 3,000 min.-1

(k) Number of phases 3 (l) Cooling system Stator coil Hydrogen directly cooled (inner cooling) Rotor coil Hydrogen directly cooled (inner cooling) (m) Hydrogen gas pressure 0.45 MPa-g (n) Service duty Continuous (o) Short circuit ratio Not less than 0.5 at rated MVA (p) Stator coil Star (q) Connection with prime mover Direct (r) Excitation system Static (s) Insulation class and temperature rise

Stator coil Class F, IEC-B rise Rotor coil Class F, IEC-B rise

(t) Neutral grounding Resistor

―――――――――――――――――――――――――――――――― ―――――


(u) Noise level 85dB(A) at 1m away from generator enclosure surface and 1.5m above floor level

(v) Hydrogen cooler Number of coolers Two set of coolers (two sections each) Capacity 100% MVA with all sections in operation

90% MVA with one section out of service

(w)The instrument list of temperature and vibration for turbine generators are shown in Table 5.4-1.

Table 5.4-1 Instrument list

Service 1 Bearing drain oil temperature element

(turbine side of generator), Thermocouple, Single type, 1element 2 Bearing drain oil temperature element

(slip ring side of generator) , Thermocouple, Single type, 1element 3 Bearing metal temperature element

(turbine side of generator) , Thermocouple, Double type, 2elements 4 Bearing metal temperature element

(slip ring side of generator) , Thermocouple, Double type, 2elements 5 Cold gas temperature element

(turbine side of generator) ,RTD, Single type, 2elements 6 Warm gas temperature element, RTD, Single type, 2elements 7 Stator coil winding temperature element

(located between top and bottom coil) ,RTD, Single type, 6elements 8 Slip ring outlet air temperature element, RTD, Single type, 1element 9 Slip ring inlet air temperature element, RTD, Single type, 1element

10 “X” shaft vibration pick up for generator bearing (turbine side) 11 “Y” shaft vibration pick up for generator bearing (turbine side) 12 “X” shaft vibration pick up for generator bearing (slip ring side) 13 “Y” shaft vibration pick up for generator bearing(slip ring side)

―――――――――――――――――――――――――――――――― ―――――


5.4.1.2 Construction of generator (1) Rotor

The major portion of the generator rotor is machined from a single alloy steel forging. The coupling between turbine and generator is one piece steel forging with integral shaft end. The rotor coil ends are supported by floating type retaining rings, shrink-fitted over the rotor body. The retaining rings are fabricated of 18% manganese - 18% chromium stainless steel. The rotor is supported on both ends by end shield mounted bearings.

(2) Stator The generator stator frame consists of a gas tight cylindrical casing of welded plate construction that is reinforced internally by bracing in both the radial and axial directions to provide a rigid structure. The stator core consists of high quality silicon steel sheets. These sheets are punched out in sector shape and coated on both sides with an insulating varnish which is baked on. This will prevent losses caused by eddy currents in the core laminations. To prevent vibration due to magnet force from being transmitted to the frame and foundation, the stator core is supported from the frame by a flexible mounting with a number of leaf springs. This construction has great enough rigidity to support the weight of the core and withstand short circuit torque. The stator coil is constructed as double layer, half coil and end connected to form a complete winding after insertion in slots in the stator core. The conductor of each coil consists of glass sheathed rectangular copper bars. The position of these bars (strands) is Roebel transposed to reduce the eddy-current losses. To prevent corona discharge, semiconducting material is applied to the surface of the coil straight section inserted into the core slot. To achieve a uniform potential gradient at the coil ends, another semiconducting material is used, after that a protective insulating varnish is applied.

(3) Cooling system The generator is cooled by re-circulating gas cooled by gas to water heat exchangers. Cold gas is forced by the generator fans into the ventilating passage of the rotor and around the stator core through the ventilating hole or duct. This arrangement results in substantially uniform cooling of the windings and core.

―――――――――――――――――――――――――――――――― ―――――


The stator coils are indirectly cooled. The coils are cooled by hydrogen gas that flows radially in the ducts of stator core. The rotor coils are directly cooled by the gas which passes through the axial passage in the bottom of slots and radial ducts (Radial Ventilation holes) in the coil. The gas absorbs heat from the rotor coils and is exhausted to the gap. After the gas has passed through the generator, it returns once more to gas to water heat exchangers.

(4) Terminals The main leads of the generator pass through bushings mounted on the leads at the top of the exciter side of frame. These leads will be connected to the line side isolated phase busduct and neutral bus. The bushings are constructed to allow replacement, if necessary, without having to remove the generator rotor. The bushings are located with adequate spacings to enable easy connections of external leads. Dry type bushings are utilized.

―――――――――――――――――――――――――――――――― ―――――


5.4.2 Hydrogen and Carbon Dioxide Gas Control System 5.4.2.1 Principal Functions

(a) To provide a means for safely putting hydrogen in or taking hydrogen out of the generator, using carbon dioxide as a scavenging medium.

(b) To maintain the gas pressure in the generator at the desired value. (c) To indicate to the operator at all times the condition of the generator with regard to gas

pressure and purity. (d) To dry the gas and remove any vapor which might get into the generator housing from the

seal oil (e) To indicate the presence of liquid in the generator housing by an alarm.

5.4.2.2 Configuration

The hydrogen gas and Carbon dioxide gas system consists of the following components: Refer to attached diagram of ABH-F1078-01 (a) Carbon dioxide gas supply unit without CO2 gas cylinders(provided by EPC) (b) Hydrogen gas supply unit without H2 gas cylinders(provided by EPC) (c) H2 gas pressure and purity monitoring unit (d) H2 gas dryer (e) Valve station (f) Water detectors (g) Piping and valves (generator side)

―――――――――――――――――――――――――――――――― ―――――


5.4.3 Seal Oil System The Mitsubishi vacuum-treating type seal oil unit has been developed for application to hydrogen-cooled turbine generators. A large number of these units have been shipped to countries around the world and they have been well-accepted there as well as in Japan.

5.4.3.1 Principal functions (1) The unit supplies seal rings with oil to prevent the escape of hydrogen gas from a

generator, without introducing an excessive amount of air and moisture into the generator. (2) The unit keeps constant differential pressure between the supply oil pressure and the

generator internal gas pressure, and monitors continuously with an alarm indicator.

5.4.3.2 Configuration Refer to attached diagram of ABH-F2108-01

(a) Generator Gland Seals -Gland seals -Seal rings

(b) Seal oil supply unit -Drain Regulator -Oil Filter -Seal Oil Pumps (Main x1, Back-up x1, Emergency x1) -Vacuum pump -Vacuum tank -Seal Oil Cooler

(c) Loop seal tank (d) Seal oil control panel (e) Piping and valves

―――――――――――――――――――――――――――――――― ―――――


5.4.4 Excitation System 5.4.4.1 General

Thyristor-type static excitation system is applied for the excitation system. The static excitation system consists of excitation transformer, excitation cubicle, AVR panel and AC/DC busduct. The design temperature of excitation cubicle will be maximum 40 oC.

5.4.4.2 Excitation transformer

(a) Frequency 50Hz (b) Number of phase Three (3) (c) Rated capacity 5950kVA (d) Voltage rating Primary 18 kV / Secondary 770 V (e) Vector group Dd0 (f) % Impedance 7.8 % at rated transformer capacity base

(Tol.±10%) (g) Cooling method Forced Air cooling(FA) (h) Type Dry, Indoor use En capsulated dry type (i) Insulation class Class F (j) Temperature rise class Class F (k) Accessories One(1) Thermometer with One(1) alarm contact for winding temperature (l) Tap Changer Not Provided (m) Termination HV: Isolated phase busduct LV: Non-segregated busduct (n) Protection IP 31,

IP 21 Ventilation and Terminals (o) Applied Standard IEC60076

5.4.4.3 Excitation Cubicle (a) The excitation cubicle(indoor type) consists of the following panels：

-Thyristor panel -Surge absorber panel -Field circuit breaker(AC type) panel

(b) Ceiling voltage of excitation system： 2.0 times of field voltage at 100% load and 100% generator terminal voltage. (c) Degree of protection：IP 31

―――――――――――――――――――――――――――――――― ―――――


(d) Design temperature：Maximum 40 oC (e) Location：Turbine building

5.4.4.4 AVR cubicle (a) Control function - Over excitation limiter (OEL)

- Minimum excitation limiter (MEL) - Volts/Hertz limiter (VFL) - Power System Stabilizer (PSS), delta P electrical power input type

(b) Degree of protection：IP 21 (c) Location：Air conditioning room

5.4.4.5 AC/DC Busduct

(a) AC Busduct : Indoor, non-segregated metal enclosed type, IP 31, 19m (b) DC Busduct : Indoor, non-segregated metal enclosed type, IP 31, 31 m (c) Applied Standard IEC60439

Note) The data above are preliminary for tender purpose and will be subject to change after

detailed design.

―――――――――――――――――――――――――――――――― ―――――


5.4.5 Current Transformers

The following current transformers will be mounted on the generator terminal bushings for metering relaying and for automatic voltage regulator.

(a) Current ratio 25000 / 5A (b) Burden 30VA (c) Class

Line side of generator: Three (3) for protection 5P20 Three (3) for metering and automatic voltage regulator 0.2 Neutral side of generator Three (3) for protection 5P20 Three (3) for protection 5P20

(d) Applied design code IEC60044-1

―――――――――――――――――――――――――――――――― ―――――


5.4.6. Generator Neutral Grounding Cubicle

Grounding of the generator will be accomplished through connection of a grounding resistor between the neutral of the generator and plant ground. The neutral grounding equipment will prevent excessive transient voltage on the generator neutral and line terminals on an occurrence of a single phase ground fault.

(1) One (1) Discharging resister with the following ratings.

(a) Rated voltage 18/√3 kV

(b) Rated current 6.9 A

(c) Resistance 1500 ohm

(d) Time duty 10 seconds

(2) Degree of protection IP 31

(3) Applied design code IEC62271 (4) Location Turbine building Note) The data above are preliminary for tender purpose and will be subject to change after

detailed design.

―――――――――――――――――――――――――――――――― ―――――


5.4.7 Generator Control Panel

The generator control panel is prepared to supervise and control of the followings for manual/emergency operation. The control switches, indication lamps, indicators, alarm windows and so forth are mounted for Generator and excitation system and Generator synchronizing system. The quantity and type of instruments and control switches, meters and indication lamps that will be mounted on the generator control panel are shown in Table 5.4-2. The generator control panel also houses the generator automatic synchronizer and accessories. The automatic synchronizer will synchronize the generator to the transmission line by regulating voltage and frequency automatically. Synchronizing point will be two(2) points only. One(1) is HV circuit breaker and other is Generator main circuit breaker.

(a) Type Sheet steel, self supporting, totally enclosed (b) Degree of protection IP 21 (c) Design temperature Maximum 40 oC (d) Location Air conditioning room

Table -5.4-2 Mounted Device list for Generator Control Panel

Instrument and devices Quantity (per Unit) Digital meters

1 pc-Volt meter, Var meter, and Power factor meter, 1 pc-Ammeter, Watt meter, and Frequency meter 1 pc- Watt-hour meter, 1-Var-hour meter

1 set

Indicating meter for synchronizing 1-Synchroscope, 2-Volt meter, 2-Frequency meter

1 set

Auto/manual synchronizing control switches 1set Automatic synchronizing equipment 1set Synchro-check relay 1set AVR control switches 1set Generator main circuit breaker switch 1 pc Generator field circuit breaker switch 1 pc Auxiliary relay 1set Multi Transducers

1 pc-Watt, Var, Power factor, Current, Voltage, Frequency

2 pcs-Watt

1 set

―――――――――――――――――――――――――――――――― ―――――


5.4.8 Generator Protection Relay Panel The generator and excitation transformer protection relay panel will be provided with protective relay functions shown in Table -5.4-3.

(a) Type Sheet steel, self supporting, totally enclosed (b) Degree of protection IP 21 (c) Design temperature Maximum 40 oC (d) Location Air conditioning room

Table-5.4-3 Protection Relay functions to be installed in Generator Protection Relay Panel

Protective function or relay Device No Impedance 21G Generator Overexcitation (V/Hz) 24G Generator stator ground fault (100%) 27TNG Reverse power 32G Generator loss of excitation 40G Generator negative phase sequence 46G Inadvertent energizing 50/27G Generator overcurrent (Start up) 50PG Generator stator ground fault (Start up) 51GNPG Generator ground fault (DC) 51GNG Generator overvoltage 59G Generator stator ground fault(95%) 59GNG VT fuse loss detection 60G Rotor ground fault 64F Out of step 78G Generator under frequency 81UG Generator differential 87G Excitation transformer overcurrent 50/51TE

―――――――――――――――――――――――――――――――― ―――――


5.4.9 Static Starting Equipment

Static starting equipment is proposed for the start-up gas turbine unit. One (1) set of static starting system will be supplied for one (1) GT unit(Refer to attached diagram of 6126-D003). The static starting equipment consists of static frequency converter (SFC), transformer, DC reactor and SFC switch circuit control panel.

5.4.9.1 Static frequency converter (SFC) system

(a) Rated output capacity 5000kW (b) Rated output voltage 3.5kV (c) Rated output current 1021A(rms) (d) Output frequency 0.05 – 33.3 Hz (e) Rated input voltage 6.6kV+/-10% (f) Rated input Frequency 50Hz +/-1% (g) Rated input capacity 6800kVA (h) Service duty Continuous (i) Applied standard IEC-60146-1-1 (j) Protection IP 31,

IP 21 Ventilation and Terminals (k) Acoustic Sound Level 85dBA at 1m distance

(l) Design temperature Maximum 40 oC (m)Relative humidity 15-85 %RH,

Dew condensation is prohibited. (n) Type TMP- TS150 (o) Redundancy of Cooling Fan, Control, Thyristor and others Not applicable (p) Seismic Design 0.3G Horizontal (q) Generating Harmonic Current shown in Table5.4-4

Table5.4-4 Harmonic current of SFC is as follows. 5th 7th 11th 13th 17th 19th 23rd 25th

20.0% 14.3% 9.1% 7.7% 5.9% 5.3% 4.3% 4.0%

29th 31th 35th 37th 41th 43th 47th 49rd

3.4% 3.2% 2.9% 2.7% 2.4% 2.3% 2.1% 2.0%

as per IEEE paper No. PCIC-84-52

―――――――――――――――――――――――――――――――― ―――――


5.4.9.2 Converter

(a) Output capacity 5000kW (b) Input voltage 3.8 kV, 50Hz, Three phase (c) Rated DC voltage 4.0kVdc (d) Rated DC current 1250Adc (e) Cooling method Forced air cooling (f) Configuration Three-phase bridge connection (g) Type Indoor use, 6-pulse type (h) Power Fuse Not Provided (i) Cable Entry Bottom

5.4.9.3 Inverter (a) Output capacity 5000kW (b) Output voltage 3.5 kV (c) Output current 1021A(rms) (d) Rated DC voltage 4.0 kVdc (e) Rated DC current 1250Adc (f) Cooling method Forced Air cooling (g) Configuration Three-phase bridge connection (h) Type Indoor use, 6-pulse converter (i) Power Fuse Not Provided (j) Cable Entry Bottom.

5.2.9.4 DC reactor (a) Rated voltage 4.0 kVdc (b) Rated current 1250Adc (c) Reactance 9mH (d) Cooling method Forced air cooling (e) Type Dry, Indoor use (f) Core Silicon Steel (g) Insulation class Class H (h) Temperature rise class Class H (i) Accessories 1 Thermometer with 1 trip contact for winding

temperature

―――――――――――――――――――――――――――――――― ―――――


5.4.9.5 Transformer for SFC

(a) Frequency 50Hz (b) Number of phase Three (c) Rated capacity 6800kVA (d) Voltage rating Primary 6.6 kV / Secondary 3.8 kV (e) Vector group Yd1 (f) % Impedance 12 % at rated transformer capacity base (g) Cooling method Forced Air cooling (h) Type Dry, Indoor use FRP-mold, Pre-Preg (Not vacuum cast coil) (i) Insulation class Class F (j) Temperature rise class Class F (k) Accessories 1 Thermometer with 1 trip contact for winding temperature (l) Tap Changer Not Provided

5.4.9.6 SFC Control Panel

(a) Type TMEIC Standard for TMP- TS150 Indoor use (b) PLC Type MELSEC Q2ASHCPU (c) Operation Panel Type Graphic Operation Terminal (GOT)

GT1575VNBD Used for Status failure indication, and parameter

setting (d) Protection Relay Ratio Differential for SFC Transformer Protection MELPRO-Dash, CAC1-A01D2

(e) Cable Entry Bottom only (f) Protection Items

-Converter; Over current Gate amp. failure Cooling air temperature high Cooling fan failure

Thyristor mis-firing Open phase Surge absorber failure

―――――――――――――――――――――――――――――――― ―――――


Incoming air temperature high -Inverter; Over current Gate amp. failure Cooling air temperature high

Cooling fan failure Thyristor mis-firing Over voltage Low voltage

-Transformer; Ratio differential Temperature high

Cooling fan failure -DC Reactor; Temperature high Cooling fan failure -Control; Control power low voltage MCCB trip

Accelerating time delay Over speed

MELSEC failure

Note: These ratings and data above are preliminary for tender purpose only and may be changed at the detail design stage.

5.4.9.7 SFC Switch circuit control panel

This panel is prepared to control SFC switch, which consisted of circuit breaker(s) and disconnecting switch for SFC start-up operation. Following functions are included in this panel. - Circuit breaker and disconnecting switch on-off control - Select and switch the control and protection circuit between Gas turbine controller,

SFC, AVR and Generator neutral grounding cubicle.

(a) Type Sheet steel, self supporting, Totally enclosed (b) PLC type MELSEC Q02HCPU (c) Degree of protection IP 21 (d) Design temperature Maximum 40 oC (e) Location Air conditioning room

―――――――――――――――――――――――――――――――― ―――――


5.4.10. Attached Drawings And Document (1) Single Line Diagram Generator Circuit 6126-D001 (2) Single Line Diagram for SFC Circuit 6126-D003 (3) Turbine Generator Cooling Water Diagram ABH-F3010-01 (4) Turbine Generator Seal Oil Diagram ABH-F2108-01 (5) Turbine Generator Lube Oil Diagram ABH-F2123-01 (6) Turbine Generator H2 & CO2 Gas Diagram ABH-F1078-01

ELECTRICAL SYSTEMS

MITSUBISHI Bangladesh Ashuganj CCPP Specification No. MP-A2292

6-1 This document contains information proprietary to MITSUBISHI HEAVY INDUSTRIES, LTD. It is submitted in confidence and is to be used solely for the purpose for which is furnished and returned upon request. This document and such information is not to be reproduced, transmitted, disclosed or used otherwise in whole or in part without the written authorization of MITSUBISHI HEAVY INDUSTRIES, LTD.

6.0 ELECTRICAL SYSTEMS AND EQUIPMENT 6.1 GENERAL

This section covers the standard technical specification of the Turbine Control Package and Electrical Equipment supplied by MHI for this project.

(1) Standard

The Electrical Equipment will be designed and manufactured in accordance with the standards listed below:

International Electrotechnical Commission (IEC) The Institute of Electrical and Electronics Engineers (IEEE) Japanese Industrial Standards (JIS) Japanese Electrotechnical Committee (JEC) The Japan Electrical Manufacturers’ Association (JEMA) The Japanese Electric Wire & Cable Maker’s Association (JCMA) Manufacturer’s Standards Any other internationally recognized Standard, if applicable

The codes and standards applicable to individual piece of equipment will be available in detailed specification drawings which will be issued at detailed design stage after contract.

(2) Standard nominal system voltage The nominal system voltage for MHI supplied equipment (MCCs, DBs, DC

system, motors for GT, ST and Generator auxiliaries and Lighting for GT & ST Package and Turbine Control Package) will be as follows:

1) AC Low voltage bus : 400 V, 3 phase, 4 wire, 50 Hz 2) DC voltage : 220 V 3) AC distribution board : 400 V, 3 phase, 4 wire; 230 V(Bus : 240V), 1 phase, 2 wire,

50 Hz

ELECTRICAL SYSTEMS



6.2 TURBINE CONTROL PACKAGE

6.2.1 GENERAL

(1) In general, the electrical and control equipment will be pre-installed inside the specially prepared steel enclosure at factory, which will be transported and placed on foundation at site. For One (1) Single Shaft Turbine Generator Unit, MHI will provide three (3) package enclosures.

6.2.2 SPECIFICATION OF PACKAGE ENCLOSURE

(1) General The enclosure will be designed for outdoor (or indoor) installation and the enclosure will be installed adjacent to each Single Shaft Unit. A concrete foundation, stairs, handrails and platform will be provided by the EPC contractor.

(2) Enclosure The enclosure will be provided with door at both ends for access, and air conditioners are provided to maintain the temperature suitable for the equipment and systems in the enclosure. Interior lighting will be provided for operation and maintenance. And at appropriate locations, convenient receptacles will be provided. Exit sign lamps will be provided near doors for escape in emergency. Stand-by emergency lighting fixtures with self-contained one (1) hour battery will also be provided.

The door will be provided with “Anti panic handle”, and therefore it can be opened with single action from inside of the package enclosure for operator’s escape when emergency.

6.2.3 Equipment installed in Turbine Control Package

MHI will provide the Turbine Control Packages which will house the following electrical and control equipment required for the operation for the turbine and

ELECTRICAL SYSTEMS



generator set, except for BOP systems such as cooling water, compressed air system, etc.

a. Turbine Motor control center (Normal MCC and Essential MCC)

b. Turbine DC motor starter

c. Turbine DC battery and charger

d. Turbine control system

e. Turbine interlock panel

f. Turbine supervisory instrument panel (TSI)

g. Turbine engineering and maintenance station (EMS), combustion pressure fluctuation analyzer server (CPFA server) desk and Local Turbine operator station (local OPS)

h. Generator control panel (GCP)

i. Generator protection relay panel (GRP)

j. Generator AVR panel (AVR)

k. Air conditioner

l. Fire fighting including smoke type fire detectors and portable fire extinguisher

Above-mentioned equipment will be arranged in three (3) enclosures for each Single Shaft Unit. The foundation of Turbine Control Package will be provided by the Civil contractor (others). The typical layout drawing is enclosed herein. Please refer to “Layout Drawing for GT Control Package”, Dwg. No. PE60-500. Other electrical/control equipment in MHI scope listed below will have to be installed by the EPC contractor in the building and/or room prepared by the EPC contractor. Power feed to these also to be done by the EPC contractor.

in Relay room (air-conditioned):

• SFC control panel • SFC switch circuit control panel

ELECTRICAL SYSTEMS



in Turbine building: • Generator excitation transformer • Generator excitation cubicle • SFC transformer • SFC cubicle • SFC start-up switch board* • Seal oil control panel

in CCR (air-conditioned):

• Turbine operator station (OPS) • Combustion pressure fluctuation analyzer

(CPFA) and data management PC (MNG) • Accessory station (ACS) • OPC server

Abbreviations; SFC : Static Frequency Converter CCR : Central Control Room OPC : Protocol of Microsoft

* Note; “SFC start-up switch board” will not be necessary if the MHI scope is only one (1) set of turbine and generator set.

Scope of these panels and equipment may be changed as necessity for the specific project. Detailed scope and required installation condition are described in other section in our proposal.

6.2.4 MOTOR CONTROL CENTER (MCC)

(1) Motor control center (MCC) is provided for control and operation of Turbine and Generator auxiliaries. For each Single Shaft Unit, one Normal MCC and one Essential MCC will be provided. During plant normal operation, both Normal & Essential MCC will be fed with normal power, and when normal power is failed, emergency power source shall feed to the Essential MCC for the unit safe shut down. All essential auxiliaries and loads are grouped and fed from Essential MCC. And both, normal & essential power source for MCC will be provided by EPC (Others). MCC will be applied for the motors up to 90 kW.

(2) MCC will be designed for indoor installation, and will be metal enclosed and

ELECTRICAL SYSTEMS



free standing. Horizontal and vertical bus will be adequately rated. Wiring troughs will be provided. Each motor feeder in MCC will have combination starters with molded case circuit breaker (MCCB), magnetic contactor and thermal over-load relay. Indication will be provided at the front of the panel for the indication of motor run/stop. Power feeder circuits will be provided with thermal-magnetic MCCB’s. All MCCBs will have sufficient current rating and interrupting capacity as required for the intended application.

(3) DATA Applicable Standard : IEC Type : Indoor, metal enclosed, free standing type Rated Voltage : 400V, 3 Phase, 4 Wire Rated Frequency : 50 Hz Short circuit rating : 50kA Protection degree : IP 31

6.2.5 AC DISTRIBUTION BOARD

AC Distribution Board provides 400-230 V AC power supply for the turbine

control equipment, generator control/protection equipment, lighting inside GT & ST package and Turbine Control Package, cubicle space heating, air conditioning for the equipment in Turbine Control Package.

DATA: Applicable Standard : IEC Type : Indoor, metal enclosed, free standing Rated Voltage : 400-230 V, 3 phase, 4 wire Rated Frequency : 50 Hz Rated bus current : As per load requirement Protection Degree : IP 31

6.2.6 DC SYSTEM FOR TURBINE AUXILIARIES

(1) The Turbine Generator unit is provided with a DC system in order to supply

ELECTRICAL SYSTEMS



DC control power to Turbine control system, Generator protection/control system and emergency DC motors.

(2) Configuration

Each DC system will consist of 2 x 100% battery chargers, 1 x 100% Valve Regulated Lead Acid (VRLA) battery bank, distribution panel and DC motor starter panel. During normal operation of the plant the battery chargers will be supplying DC loads and float charging the battery. Upon failure of AC power, the battery will feed the loads for safe shut-down, by discharging. Battery capacity will be calculated based on IEEE 485 standard. The battery back-up time will be 1 hour. Battery will be installed in metallic self-supporting rack for indoor installation. Battery chargers will be supplied in free standing cubicles with control and indications in front of the cubicles. Battery and chargers will be sized adequately to supply intended loads.

(3) DATA For Battery:- Battery type : Valve Regulated Lead Acid (VRLA) type

(Calcium) Nominal voltage : 220 V DC Capacity : As per load requirement Discharge period : 1 hour Quantity : 1 x 100% Installation : Metallic, self-supporting racks/steel trays,

indoor. For Battery Charger:- Type : Metal-enclosed free standing, indoor type Protection Degree : IP31 Input Voltage : 400 V AC, 3 Phase, 4 wire, 50 Hz Output Voltage : 220 V DC Charging modes : Float/Equalize Re-Charging time : Will be determined after the determination of

ELECTRICAL SYSTEMS



the battery capacity Quantity : 2 x 100% charger

6.2.7 DC DISTRIBUTION BOARD

The 220V will feed control power to the Turbine Control system, Generator protection/control panel.

Applicable Standard : IEC Type : Indoor, metal enclosed, free standing Rated Voltage : 220 V DC Rated bus current : As per load requirement Protection Degree : IP 31

6.2.8 DC MOTOR STARTER PANEL

(1) 220V DC motor starter panel will provide power supply to emergency DC motors and DC control power of Turbine and Generator auxiliaries.

(2) Configuration

Each motor starter will consist of MCCB, magnetic contactor, thermal over load relay and resister-timer circuit to limit the starting current within tolerable limits. These motor starters will be controlled by receiving remote on/off commands from Turbine control system and Generator Seal oil control system. Feed back signals regarding motor on/off and control from remote available signals will be provided to Control System as required.

(3) Data Applicable Standard : IEC Type : Indoor, metal enclosed, free standing Rated Voltage : 220 V, DC Protection degree : IP 31

6.2.9 LIGHTING AND RECEPTACLE

ELECTRICAL SYSTEMS



(1) General

Lighting fixtures, convenient receptacles and lighting cables within the Turbine Control Package will be provided. The lighting fixtures and accessories will be designed, manufactured and installed within the package. The average illumination level in the Turbine Control package will be 200 lux.

(2) Lighting power will be fed from AC Distribution Board. Fluorescent lamps of suitable type will be provided. Some fluorescent lamps will be provided with self-contained one (1) hour battery as the emergency lighting.

6.2.10 AIR CONDITIONING SYSTEM

Each Turbine Control Package will be provided with two (2) sets of air-conditioners. One (1) set of air-conditioner has the capability to maintain the temperature in the Turbine Control Package at the designed temperature.

Designed inside temperature : 25 oC (dry bulb) Outside temperature : 5 oC ~ 40 oC (dry bulb)

6.2.11 FIRE DETECTING SYSTEM

(1) Fire Detecting System with detectors and alarm will be provided for

connection to gas turbine fire alarm panel.

(2) Each package will be provided with portable fire extinguishers (manual operation) to put off the fire.

6.2.12 CABLES in Turbine Control Package

MHI will provide the cables within the Turbine Control Package. The specification of power, control and instrument cables supplied for the inside of the Turbine Control Package will be as follows:

Power cable : XLPE insulated and flame-retardant PVC

ELECTRICAL SYSTEMS



oversheathed Power cable. Control cable : XLPE insulated and flame-retardant PVC

oversheathed control cable Instrument cable : PVC insulated and flame-retardant PVC

oversheathed instrument cable with copper tape shielding.

Special cable : The specification will be submitted only for information during detailed engineering stage.

Note: - Flame retardant will be applied IEC 60332-3 category A or equivalent. - Conductor size may be applied according to JCMA standard, such as 0.75

sq.mm., 1.25 sq.mm., 2 sq.mm. and 3.5 sq.mm. - The cables which are connected with the equipments/devices outside the

Turbine Control Package are not in the scope of supply. - In gas turbine package and steam turbine lagging, the insulation and sheath of

the cables will be ETEF (Ethylene Tetrafluoroethylene Copolymer) considering high temperature condition.

6.2.13 GROUNDING

All electrical equipment and metallic structures of the Turbine Control package will be connected to the grounding network. For this purpose, two (2) grounding terminals will be provided for one container. One of them will be used for grounding of the control equipment in the Turbine Control Package and the other will be used for grounding of the electrical equipment. However, grounding cable connection up to ground terminal connection from the main ground grid will be provided by EPC (Others).

6.2.14 FOUNDATION OF TURBINE CONTROL PACKAGE

The foundation will be designed and provided by EPC (Others). The conceptual design is shown on the attached drawings Dwg.no.PE60-600.

ELECTRICAL SYSTEMS



6.3 MOTORS FOR TURBINE AND GENERATOR AUXILIARIES

Rating and specifications of the motor for turbine and generator auxiliaries are as follows:

Type of AC motor : Induction Motor Type of AC motor rotor : Cage Rated voltage

-AC motor (MV) : 6600V (if in scope) -AC motor (LV) : 400 V, 50 Hz -DC motor : 220V

Insulation class : Class F (temperature rise B) (some small capacity motors, Class E / manufacturer’s standard)

Enclosure Protection : Generally IP44 (Totally enclosed type) Method of starting:

-AC motor : DOL -DC motor : Resistor

Starting current of motor -MV motor : Less than 650% of rated current

(if in scope) -LV motor : According to manufacturer’s standard

Running duty : Continuous Service factor : 1.0 Codes and standards IEC, except for the following case: Auxiliary motors purchased from Japan will conform to the following standards: General performance : IEC60034-1 Dimension : IEC60072-1&2 Material : JIS Test : JEC 2137, JEC 2120 Explosion proof : JIS C0905 / RIIS

Tolerance specified in JEC-2137 and JEC2120 will be applied for motor

ELECTRICAL SYSTEMS



characteristics. Motors purchased from other countries will comply with the originating

country standard.

Reference Drawings: Drawing Dwg. Reference 1. Typical Key Single Line Diagram Turbine Control

Package PE60-100

2. Layout drawing of Turbine Control Package PE60-500 3. Foundation of Turbine Control Package

(Single-shaft configuration) PE60-600

7 INSTRUMENTATION AND CONTROL SYSTEMS 7.1 GENERAL



7 - 1 - 1


7.1 GENERAL

The Instrumentation and Control (I&C) equipment of the Power Train is

standardized to meet the equipments requirements. The I&C System will be

designed in the following manner:

(1) The Turbine Control System will be provided for the operation of the Gas

Turbine (GT) and Steam Turbine (ST). Supervision and monitoring

function and the type and number of measuring points adequately fulfill the

requirements of the turbines.

(2) The control and supervision will be performed by the multiple process

station (MPS) that incorporates modern microelectronics technology and

plant control technology.

(3) The Turbine Control System will provide modulating control, digital

(on/off) control, monitoring, alarming and indication for the turbines.

(4) The proposed Turbine Control System is Mitsubishi’s control system,

DIASYS Netmation, which will be of an advanced distributed configuration.

The turbine control system configuration is shown on the attached drawing

below:

U-F2010: Turbine Control System Configuration.

(5) The Turbine Control System will be composed of redundant

microprocessors, and each control system will be interfaced with the other

control system (called ‘DCS’ hereinafter) by a redundant communication

datalink (OPC A&E1.0 / DA1.0 or 2.0).

(6) The Turbine Control System including Turbine Supurvisory Instrument

Panel and Turbine Interlock Panel will be installed in Turbine Control

Package.

7 INSTRUMENTATION AND CONTROL SYSTEMS 7.1 GENERAL



7 - 1 - 2


(7) Centralized supervision and automatic operation of plant start-up, shutdown,

and normal load changing can be performed by the use of operator stations

supplied by Buyer.

(8) Hardwired relay logic based turbine protection system which is proven and

standardized system based on rich field operational experiences will be

proposed.

(9) Hardwired switches for manual emergency gas turbine/steam turbine trips

will be mounted on the operator control desk in the main control room

(MCR) by Buyer.

(10) Measuring instruments will be provided as per following design

philosophy.

・ For modulating control, basically single sensor will be provided. Dual

redundant sensors will be provided for some critical control loops. At

each measuring point, sensor will be common for both control and

monitoring function.

・ In case that redundant analog sensors are provided for protection, they

will be also used for both control and monitoring function.

・ For the unit trip function, basically triple redundant sensors with 2 out of

3 voting logic will be provided.

・ Instruments will be provided as per manufacturer’s standard design.

7 INSTRUMENTATION AND CONTROL SYSTEMS 7.2 SCOPE OF SUPPLY



7 - 2 - 1


7.2 SCOPE OF SUPPLY

The following Control and Instrumentation System are included in the scope:

No. Equipment and Works Qty Remarks 1 Turbine Control System (TCS)

- Duplicated microprocessors - Duplicated network interface module - Single PI/O system (Servo modules for fuel

control valves are duplicated)

1 set

2 Local Turbine Operator Station (OPS) in Turbine Control Package - PC with VDU, QWERTY keyboard and mouse

1 set 21 inch color LCD

3 Combustion Pressure Fluctuation Analyzer (CPFA) in Turbine Control Package - Server (PC)

1 set/GT

4 Engineering Maintenance Station for TCS (EMS) in Turbine Control Package - PC - VDU, QWERTY keyboard and mouse

(common use with CPFA Server) - Color inkjet printer (common use with OPS)


5 Instruments for Gas Turbine

1 set/GT As for detailed quantities, please refer to P&ID’s

6 Instruments for Steam Turbine

1 set/ST As for detailed quantities, please refer to P&ID’s

7 Cabling and instrumentation material between field equipment and local junction boxes inside GT enclosure. - Conduit, tubing, fitting, cable and raceway

1 set/GT

8 Cabling and instrumentation material between field equipment and local junction boxes inside ST lagging. - Conduit, tubing, fitting, cable and raceway

1 set/ST

9 Turbine Operator Stations (OPS) in MCR - PC with VDU, QWERTY keyboard and mouse


7 INSTRUMENTATION AND CONTROL SYSTEMS 7.2 SCOPE OF SUPPLY



7 - 2 - 2


No. Equipment and Works Qty Remarks 10 Color laser printer in MCR

1 set

11 Engineering Maintenance Station (EMS) in MCR - PC with VDU, keyboard and mouse - Color laser printer


12 Accessory Station (ACS) in MCR - Duplicated computer package

1 set

13 Data Management PC (DMPC) in MCR - PC with color VDU, keyboard and mouse - Data storage to external media - Router

1 set

14 CPFA monitor in MCR - Client PC with color VDU, keyboard and

mouse

1 set/GT

15 Special Monitor for Combustion Turning (SMCT) in MCR - Laptop PC - Inkjet printer

1 set/GT

16 OPC Server in MCR - Dual redundant interface with DCS - Duplicated computer package - OPC A&E1.0/DA1.0 or 2.0 - Router

1 set

17 Turbine Interlock Panel - GT protection system - ST protection system

1 set Hardwired relay logic circuit

18 Turbine Supervisory Instruments

1 set As for detailed quantities, please refer to Section 7.9.1.

19 Combustible Gas Detectors

1 set/GT As for detailed quantities, please refer to Section 7.9.2.

7 INSTRUMENTATION AND CONTROL SYSTEMS 7.3 CONTROL FUNCTION



7 - 3 - 1


7.3 CONTROL FUNCTION

The TCS consists of a duplicated microprocessor based controller, single I/O (Servo

modules for fuel control valves & ST governor valves are duplicated) and CPFM &

CPFA system. All the auto/manual operations are available on OPS located in

Turbine Control Package and Main Control Room (MCR). The TCS is of an

advanced distributed configuration and its functions are explained in this section.

7.3.1 GAS TURBINE CONTROL

(1) Automatic Load Regulation (ALR)

The governor free operation or the load control operation is available based on

ALR LOAD SET from the Automatic Power Regulation (APR) control in DCS

(supplied by Buyer) or GT-OPS. In the ALR operation mode, the GTC changes

the speed and the load reference with the selection of control mode

(GOVERNOR mode or LOAD mode).

(a) Governor Free Operation (GOVERNOR mode)

When GOVERNOR is selected for CONTROL MODE, the TCS adjusts the

speed reference so that the Generator output is the same as the ALR LOAD

SET. The droop speed control is available based on the adjusted speed

reference. Simultaneously, the TCS adjusts the load reference to be the

same as the Generator output plus some bias. Then, the governor control is

available and the load control restricts the excessive increase of the Generator

output if a sudden decrease of grid frequency occurs.

(b) Load Control Operation (LOAD mode)

When LOAD is selected for CONTROL MODE, the TCS adjusts the target

load to be the same as the ALR LOAD SET. The load reference is changed

to the target load under the predetermined rate. Simultaneously, the TCS




7 - 3 - 2


adjusts the speed reference so that the Governor Control Signal Output

(GVCSO) is the same as the fuel Control Signal Output (CSO) plus some

bias.

(2) Speed Control

Speed control is used for synchronization to the grid and for the Generator’s

output control under the speed droop after synchronization. At the rated speed

and unloaded condition, the speed reference is changeable by a signal from the

auto synchronous system (ASS) or the manual command (GOVERNOR

RAISE/LOWER) from the OPS. In case of ALR, the speed reference is shifted

according to the ALR LOAD SET from DCS under the predetermined loading

rate. On the other hand, the speed reference is changeable according to the

manual command (GOVERNOR RAISE/LOWER) from the OPS while ALR is

off and the GOVERNOR is selected for Control Mode. GVCSO is the result of

proportional control calculation under the droop characteristic by following

formula.

GVCSO = K (Speed reference – Actual speed) + Bias

(3) Load Control

The target load is changed according to the ALR LOAD SET from DCS, while

the ALR is selected. On the other hand, the target load is changeable according

to the manual command (LOAD RAISE/LOWER) from the OPS while the ALR

is off and LOAD is selected for Control Mode. The load reference is shifted to

the target load under the predetermined loading rate. The loading rate will be

determined by a function of the load to avoid over firing of the combustor

(Loading rate with Reset wind up prevention Control Signal Output: LRCSO).

Load Control Signal Output (LDCSO) is the result of the Proportional and




7 - 3 - 3


Integral (PI) control calculation whose input signal is the deviation between the

actual gas turbine generator output and the load reference. Furthermore, when

the governor free operation mode is selected, LDCSO is tracked to the value

which is the sum of fuel Control Signal Output (CSO) plus some bias for the

purpose of the operation as the load limitation under droop control.

(4) Temperature Control

Temperature control is used for the protection against excessive turbine inlet

temperature. Instead of turbine inlet temperature measurement, turbine exhaust

temperature is measured at two locations for the temperature control.

Thermocouples sense the Blade Path temperature, which is the gas temperature

just downstream of the turbine's final blades and the same numbers of

thermocouples with the combustors are furnished. Thermocouples sense the

well-mixed Exhaust Gas temperature. The exhaust gas temperature reference is

determined by a function of the combustor shell pressure and the blade path

temperature reference is determined by the exhaust gas temperature reference

plus some bias. This bias will be changed to avoid over firing of the combustor

(BPT bias control). The exhaust gas temperature reference is compared with

the average value of actual exhaust gas temperatures and the blade path

temperature reference is compared with the average value of actual blade path

temperatures. When the deviation of these two signals is positive, the PI

controller output signals (BPCSO and EXCSO) are tracked to the sum of fuel

CSO plus some bias to block against over-integration or integral wind up. If the

deviation becomes negative, the PI controller output signals are to cut back fuel

CSO until a positive deviation is reached.




7 - 3 - 4


(5) Fuel Limit Control

The start up control demand signal is calculated as a function of combustor shell

pressure and turbine speed within the accelerating limit. The output of this

control function (FLCSO) is used to limit fuel flow.

(6) Minimum Selection Control

The control system selects the minimum of the control signals described above

(GVCSO, LDCSO, BPCSO, EXCSO and FLCSO) for the fuel control valve

positioning. The control output is also ensured for the “Minimum CSO

scheduler” which is the function of ignition flow, warm up, and minimum flow to

prevent flame loss.

(7) Fuel Transfer Control

Fuel transfer control is used for fuel changeover. The output of the minimum

select control, CSO is switched to either main fuel gas control signal output

(MFCSO) or sub fuel control signal output (SFCSO). If fuel gas is selected by

an operator, MFCSO is equal to CSO, and SFCSO is 0%. During fuel transfer

operation, MFCSO or SFCSO ramps up from 0% to CSO or ramps down from

CSO to 0% as per predetermined time schedule.

(8) Fuel Distribution Control

In the case of fuel gas firing, the output of the minimum selection control,

MFCSO is distributed to four CSO signals for pilot line, main-A line, main-B

line and tophat line in the fuel gas system.

Fuel gas pilot line : MFPLCSO

Fuel gas main-A line : MFMACSO

Fuel gas main-B line : MFMBCSO

Fuel gas tophat line : THCSO




7 - 3 - 5


In the case of fuel oil firing, the output of the minimum selection control, SFCSO

is distributed to two CSO signals for pilot line and main line in the fuel oil

system.

Fuel oil pilot line : SFPLCSO

Fuel oil main line : SFMCSO

Distribution ratio is determined based on CLCSO (Combustion Load Control

Signal Output), which is represented signal of turbine inlet temperature. CLCSO

is calculated in GTC based on the Inlet Guide Vane (IGV) position reference,

actual generator output and the compressor inlet air temperature. The

relationship between each CSO is shown as follows.

MFCSO = MFPLCSO + MFMACSO + MFMBCSO + THCSO

SFCSO = SFPLCSO + SFMCSO

(9) Fuel Flow Control

Distributed control signals, MFPLCSO / SFPLCSO, MFMACSO & MFMBCSO

/ SFMCSO and THCSO, are converted to each fuel flow demands by

predetermined function.

(10) Fuel Pressure Control

The differential pressure between inlet and outlet of each fuel flow control valve

shall be kept for constant value, so that fuel flow is proportional to CSO of each

flow control valve. The inlet fuel gas pressure of fuel gas flow control valves is

regulated by fuel gas pressure control valve.

The inlet fuel oil pressure of fuel oil pressure control valves is regulated by fuel

oil supply pressure control valve. The differential pressure between inlet and

outlet of each fuel oil flow control valve shall be kept, so that oil fuel flow is




7 - 3 - 6


proportional to control signal output of each flow control valve. Pressure control

valves are controlled by PI-control for the differential pressure.

(11) Inlet Guide Vane (IGV) Control

The IGV controls the inlet airflow rate to the compressor to achieve high

efficiency at partial load.

(12) Combustor Bypass Control

In order to meet the NOx emission level, the combustor bypass valves are

controlled according to the actual turbine speed or CLCSO. The

opening/closing of the bypass valve varies the compressor outlet airflow to the

Combustors to maintain proper conditions (fuel to air flow rate ratio).

(13) Automatic Turbine Start-up / Shutdown Control (ATS)

ATS perform gas turbine sequence control by receiving kick signal from

automatic plant start-up / shutdown sequence control executed by DCS.

(a) Gas Turbine Start-up

• Spin (purge)

• Light off

• Speed control to the rated speed

• Loading up to the target load

(b) Gas Turbine Shutdown

• Unloading to the minimum load

• De-synchronization

• Cooling down

• Fuel shut down

(14) Fuel Gas Temperature Control

In order to obtain high thermal efficiency, fuel gas is heated by Fuel Gas Heater.




7 - 3 - 7


(15) Load Run Back Control

The Load-Run-Back function is initiated by the following conditions in order to

avoid Combustor malfunction. The gas turbine load is decreased automatically

in the following situations:

• Combustion vibration pressure fluctuation is high

• Blade Path temperature variation is large

• Blade Path temperature trend change is large

• Generator winding temperature high

• Fuel gas supply pressure low

• Fuel gas temperature abnormal

• Evaporative Cooler pump stop

• Water injection abnormal

(16) Water Injection Control

In order to meet the NOx emission level during oil fuel operation, the water

injection flow is controlled according to generator output.

(17) CPFM & CPFA SYSTEM

CPFM: Combustion Pressure Fluctuation Monitoring system

CPFA: Combustion Pressure Fluctuation Analyzer system

(a) General

Automatic controller for combustion pressure fluctuation, CPFM & CPFA

System is an automatic tuning system designed to perform optimal operation

on the basis of a model constructed by modeling the combustion pressure

fluctuation characteristics of each individual combustor using combustion

pressure fluctuation and various plant operating data. The reliability of this




7 - 3 - 8


system is enhanced by applying the method of multiple regression analysis in

modeling the combustion pressure fluctuation characteristics and also

conducting early detection of combustion pressure fluctuation and abnormality

diagnosis of combustion pressure fluctuation sensors.

CPFM System is a device for calculating three levels (pre-alarm, runback and

trip) based on the combustion pressure fluctuation peak value and the result of

Fast Fourier Transform (FFT) analysis calculated by special input modules for

the combustion pressure fluctuation sensors. The signals of pre-alarm and

runback command are transmitted to the TCS via Unit Network, and the

signals of trip command are transmitted to Unit Interlock Panel by hardwired

connection.

CPFA System is a computer device to calculate correction value for

combustion control (pilot fuel control or combustor bypass valve control) by

using the combustion pressure fluctuation and various plant process data.

CPFA stores historical data and performs multiple regression analysis by using

these data to gain correction value and transfers the calculated correction value

to the TCS via Unit Network.

CFPM & CPFA System is combined as a part of the TCS.

When the combustion pressure fluctuation level increases and reaches the

caution level or a symptom of combustion pressure fluctuation is detected,

correction operation is carried out in the direction in which to decrease

combustion pressure fluctuation. This correction operation is terminated

when the combustion pressure fluctuation level decreases to below the caution

level.

In case the combustion pressure fluctuation level increases with increasing




7 - 3 - 9


load and rises up to the pre-alarm level or a symptom of combustion pressure

fluctuation is detected, correction operation is performed, and the load is

maintained until the combustion pressure fluctuation level decreases.

In CPFM & CPFA System, as a protection interlock of combustion pressure

fluctuation, CPFM performs a predetermined protective operation when the

combustion pressure fluctuation level exceeds the trip or runback value due to

sudden changes in operating conditions.




7 - 3 - 10


Combustion pressure fluctuation

monitoring

Exceed an alarm or trip level?

Protection Interlock (Runback or Trip)

Exceed a caution alarm level? Correction operation

Exceed a pre-alarm level or detect a symptom?

Load up now?

Load hold

Correction operation

YES

YES

YES

Turbine Control System

CPFM CPFA

YESNO

Fig. 7-1 Fundamental flow of CPFM & CPFA System

Each function is independent. Therefore, the protection function by CPFM can operate even if a problem occurs in CPFA function.




7 - 3 - 11


(b) Basic functional specification

CPFM & CPFA System is composed of the following functions, using the

method that automatically corrects control parameters with respect to the

changes in operation data:

(i) Plant data collection and analysis

(ii) Abnormality diagnosis of combustion pressure fluctuation sensors

(iii) Early detection of symptoms of combustion pressure fluctuation

(iv) Stable region estimation

(v) Automatic tuning (correction amount calculating)

(vi) Protection Interlock These functions serve to automatically estimate a stable operating point and

tune control parameters according to the combustion pressure fluctuation level

or NOx emission level. CPFM & CPFA System comprises TCS, CPFM and

CPFA as shown in Fig. 7-2.




7 - 3 - 12


Fig. 7-2 Configuration of CPFM & CPFA

Measured Data (i.e. Temp., Press.)

Tuning Parameters

TCS

Plant Data

Gas Turbine

Control (i.e. Bypass valve)

Partial Over-All FFT Analyze Band Peak/Frequency High/Low Limit of Band Sensor Abnormal

Measured Data (Combustion Pressure

Fluctuation Sensor)

CPFA CPFM

Protection Interlock




7 - 3 - 13


(c) Hardware specification

(i) CPFM

CPFM system consists of dual redundant CPU modules and special input

modules for combustion pressure fluctuation sensors.

Table 7-1 Specification of CPU module for CPFM Item Specification

CPU Hitachi SuperH RISC microprocessor SH-4 240 MHz Redundancy Duplicated OS Linux (realtime compatible) Memory 128MB, SDRAM with ECC Non-volatile memory 128MB compact flash Ethernet interface 100B-T×3ch

(ii) CPFA

Platform of CPFA is Personal Computer (PC). CPFA server will be

installed in Turbine Control Package, and CPFA client will be installed in

MCR will be provided to display the correction value calculated by CPFA

server.

Table 7-2 Hardware Specification of CPFA (server & client) Item Specification

OS Windows XP Professional English version CPU Pentium IV 2.4GHzMemory 1GB Hard Disk 160GBAccessories CD-RW (Internal)Network 100B-T×5chMonitor (for client) 20 inch color LCD (single)Peripheral (for client) Alphanumeric keyboard, Mouse




7 - 3 - 14


(iii) Special Monitor for Combustion Tuning (SMCT)

One laptop PC will be provided and installed in MCR. SMCT will be used

to monitor the combustor pressure fluctuation during combustion tuning

only.

Table 7-3 Hardware Specification of SMCT Item Specification

OS Windows XP Professional English version CPU Core 2 Duo 2.4GHzMemory 1GB Hard Disk 60GBAccessories CD-RW (Internal)Network 100B-T×3chMonitor 14.1 inch TFT (laptop PC)




7 - 3 - 15


7.3.2 STEAM TURBINE CONTROL

(1) Speed-Up Control

In a turbine start-up condition, the turbine speed is controlled by the High

Pressure-Stop Valve(s) (HP-SV control mode). A reference speed will be

calculated in a speed setting part that consists of a speed setter to set target speed,

a rate limiter to set the acceleration rate of speed, and an integrator to sum up rate

signal until output is equal to target speed.

(a) Target Speed

The TCS selects one of three predetermined target speeds:

• 2,000 rpm Heat soak speed

• 2,820 rpm Valve transfer speed

• 3,000 rpm Rated speed

NOTE: The heat soak speed will be changed if it is within the critical

speed range.

(b) Speed Acceleration Rate

The STC selects one of three predetermined speed acceleration rates:

• SLOW 75 rpm/min.

• MIDDLE 150 rpm/min.

• FAST 300 rpm/min. (normal operation)

(c) Control

The HP-SV controller will execute proportional control in accordance with

the difference between the reference speed and actual speed.

This control signal is delivered to each HP-SV.




7 - 3 - 16


(d) Program Go/Hold Operation

After setting a speed target and an acceleration rate, the turbine begins to

start. When the turbine speed reaches the target speed, it will be held at

the target speed.

During speed-up, the turbine speed is held at the present speed by

operating PROGRAM “HOLD”.

The turbine is restarted by operating PROGRAM “GO”.

(2) Close All Valves

This function will close the high pressure stop valves (HP-SV), high pressure

control valves (HP-CV), intercept valves (ICV) and low pressure control valve

(LP-CV) gradually to protect the steam valves seats in case of turbine stop or rub

check.

(3) Valve Transfer (HP-SV/HP-CV)

After rated turbine speed has been reached, turbine control mode is transferred

from “HP-SV control mode” to “HP-CV control mode”.

At first, HP-CVs will be closed gradually from full open position to no-load

position. Then, HP-SVs will be opened gradually from a few percent open

position to a full open position. During this operation, turbine speed will be

kept constant.

(4) Start up Program Open Control

After rated speed, HP-CV and ICV open up to full open position at

predetermined rate programmably. ICV positions as per HP-CV position.

Open rate is settled according to mode selection (Hot, Warm, Cold). HP and IP

TBVs are thrown into control pressure and gradually close to steam generated by




7 - 3 - 17


HRSG. LP-CV opens up to full open position at predetermined rate

programmably.

(5) Pressure Control

After initial load operation, HP/IP pressure control mode is thrown into the

HP-CV/ICV control by operating HP/IP Pressure Control “IN”. At that time,

the HP/IP pressure reference is set up at the minimum required pressure.

According to the load-up of Steam Turbine from the initial load, the HP/IP

pressure reference is set up lower than the actual HP/IP pressure and HP-CV/ICV

is full open under normal operation.

After throwing the HP-CV/ICV control into HP/IP pressure control mode, LP

pressure control mode is thrown into the LP-CV control by operating LP

Pressure Control “IN”. The LP pressure reference is usually set up at the

minimum pressure and LP-CV is full open under normal operation after steam

turbine load-up.

(6) Shutdown Program Close Control

All ST control valves close at predetermined rate programmably like the start up

program control. At first LP-CV closes to the position which keeps minimum

cooling steam for ST blade. And then HP-CV and ICV close to full close position

at predetermined rate. LP-CV fully closes at turbine stop.

In case temperature force to ST occurs during the shutdown program close

control, they keep each position at the time to prevent the temperature force from

increasing.

(7) Overspeed Protection Control (OPC)

OPC will be actuated for prevention of an over speed trip. OPC closes HP-CV,

ICV and LP-CV when one of the following situations occurs.




7 - 3 - 18


Fig.7-3 OPC block diagram

(a) Turbine speed exceeds 107.5% of rated speed.

(b) Disconnection from the grid when the plant output is over the determined

generator output. (Signals of disconnection from the grid will be provided by

others.)

(c) Fast cut back when the plant output is over the determined generator output.

Function block Element

H High monitor

FX Polyline function

OFD Off time delay

TDW Time delay wipe out

AND logic

OR logic

Turbine speed

Generator output

Generator breaker OPEN

Detection of FCB

>107.5%

OFD FX H

H

TDW

OPC




7 - 3 - 19


(8) Valve Closing Test

The valve test is performed for the purpose of confirming the safety performance

by partially closing a tested valve during load operation. Testing Valves are

divided into 5 groups as HP-SV, HP-CV, Reheat Stop Valve (RSV), ICV and

LP-SV/LP-CV. For each group, operation commands such as “ON” and

“RELEASE” are reserved. Test operations are as follows:

(a) Set “ON” on the VDU. The valve test is then started, and the Valve Test

Closing Bias is added to the position demand of the tested Valve with a

ramp function or equivalent. Thus, the tested valve is gradually closed.

(b) As soon as the test valve is closed to the predetermined partial opening,

the valve position will return to a fully-open position gradually.

(c) If the operator sets “RELEASE” during the test, the test is aborted and the

testing valve will return to a fully-open position gradually.

Fig.3-3 Valve closing test

“RELEASE”▽

OPEN

CLOSE

“ON” ▽

the tested valve position

Fig.7-4 Valve closing test




7 - 3 - 20


(9) Stress Control

The turbine stress control function minimizes the turbine life expenditure due to

thermal stresses of HP steam turbine rotor.

The thermal stress is calculated by using HP inlet steam temperature and HP inlet

steam pressure. When an excessive stress level is calculated, the ‘Loading rate’

(which is the output of stress control) will be held. Hence, the Buyer’s DCS can

suppress the GT loading rate as per the ST thermal stress condition. The next

figure shows a block diagram of stress control.

HP Inlet Steam Press.

Actual Speed

Fig.7-5 Stress Control

STRESS LEVEL

EXCESS STRESS LEVEL

Load Reference HOLD (DCS)

Rotor Stress Calculation

MonitorHP Inlet Steam Temp.

(OPS)

(OPS)

Stress Control function

Stress Control

OUT IN

7 INSTRUMENTATION AND CONTROL SYSTEMS 7.4 PROTECTION SYSTEM



7 - 4 - 1


7.4 PROTECTION SYSTEM

7.4.1 GAS TURBINE PROTECTION

The Gas Turbine protection functions are included in the Gas Turbine Interlock

Panel. A de-energized-to-trip (fail safe in case of power failure) solenoid valve is

provided as a standard design. The gas turbine trip conditions are as follows:

1 Manual emergency trip 2 Fire 3 Lube oil pressure low 4 Control oil pressure low 5 Shaft vibration high 6 GT-ST speed deviation high 7 Combustion pressure fluctuation high 8 Blade path temperature variation large 9 Blade path temperature high 10 Exhaust gas temperature high 11 Fuel gas supply pressure low 12 Bleed valve abnormal 13 Starting device trip 14 GT overspeed trip 15 ST overspeed trip 16 Exhaust gas pressure high 17 Fuel control valve abnormal 18 Low frequency 19 Condenser vacuum low 20 Thrust bearing wear 21 LP turbine exhaust temperature high 22 LP turbine last stage stational blade metal temp high 23 Electrical fault (from Generator Protection Relay) 24 Turbine Control System failure 25 External Request Trip (from DCS)

7 INSTRUMENTATION AND CONTROL SYSTEMS 7.4 PROTECTION SYSTEM



7 - 4 - 2


26 Flame loss 27 Gas leak detection trip 28 Inlet air filter differential pressure high 29 TCA cooler drain level high 30 TCA cooler feed water flow low 31 FGH drain level high 32 Main fuel oil pump trip 33 Fuel transfer load off

7 INSTRUMENTATION AND CONTROL SYSTEMS 7.5 OPERATOR STATION(OPS)



7 - 5 - 1


7.5 OPERATOR STATION (OPS)

Standard types of Human Machine Interface will be provided in Turbine Control

Package and Main Control Room. The following functions are included for

Operation and Maintenance for TCS.

(1) Monitoring/Operation for Gas Turbine and Steam Turbine

(a) Graphics (system diagram display)

(b) Control loop plate

(c) Trends

(d) Alarms

(2) Maintenance for TCS

(a) System status display

(b) Control logic monitoring and parameter tuning

Table 7-4 Specification of OPS hardware Item Specification

Manufacturer MHI Model PCLTM01 OS Windows XP Professional English version CPU Pentium IV 2.4GHz Memory 1GB Hard Disk 80GB Monitor 20 inch LCD Resolution 1280×1024 Color 16,700,000 Accessories 3.5FD, CD-RW / DVD (Internal) Network 100B‐TX×3ch Key board Alphanumeric keyboard

(OPS dedicated keyboard will not be provided)

7 INSTRUMENTATION AND CONTROL SYSTEMS 7.6 ENGINEERING MAINTENANCE STATION(EMS)



7 - 6 - 1


7.6 ENGINEERING MAINTENANCE STATION (EMS)

Engineering Maintenance Station (EMS) provides the ability to perform operations

including:

(1) Modification and creation of control logic on TCS

(2) Design of graphic displays

(3) Setting of OPS and ACS

(4) Any change up to and including configuring the entire system

EMS prepares elements for performing data execution and control and monitoring of

OPS and IEC-compliant function blocks, making it possible to configure an entire

system from a single station.

Table 7-5 Hardware Specification of EMS Item Specification

Manufacturer MHI Model PCLTM01 Redundancy Single OS Windows XP Professional English version CPU Pentium IV 2.4GHzMemory 1GB Hard Disk 80GBMonitor 20 inch LCDAccessories 3.5FD, CD-RW / DVD (Internal)Network 100B-T×3chKeyboard Alphanumeric keyboard

7 INSTRUMENTATION AND CONTROL SYSTEMS 7.7 ACCESORY STATION(ACS)



7 - 7 - 1


7.7 ACCESORY STATION (ACS)

The ACS is a system equipped with large hard disk for storing and managing large

amounts of plant data.

Functions of ACS are followings;

・Long term data management

・Long term storage of process data

・Reports

・Logs

・Printer server

Table 7-6 Hardware Specification of ACS Item Specification

Manufacturer MHI Model PCLTM01 Redundancy Duplicated OS Windows XP Professional English version CPU Pentium IV 2.4GHzMemory 1GB Hard Disk 80GBMonitor 20 inch color LCDAccessories 3.5FD, CD-RW / DVD (Internal)Network 100B-T×3chKeyboard Alphanumeric keyboard

7 INSTRUMENTATION AND CONTROL SYSTEMS 7.8 DATA MANAGEMENT PC(DMPC)



7 - 8 - 1


7.8 DATA MANAGEMENT PC (DMPC)

The Data Management PC (DMPC) is a Windows-based PC to export the plant data

from other PC to removable media such as USB memory.

For security, unused USB ports and unused Ethernet ports are locked, and taking out

data from each PC except the DMPC by using a removable media such as USB

memory and CD-R is forbidden. The communication from each PC to the DMPC is

forbidden by using the Router, and the communication from the ACS to the DMPC

is permitted by using FTP service. The communication from the DMPC to each PC

is forbidden.

The ACS automatically sends the data to the DMPC by FTP communication, and the

data can be taken out from the DMPC by using a removable media such as USB

memory and CD-R.

Table 7-7 Hardware Specification of Data Management PC Item Specification

Manufacturer MHI Model PCLTM01 Redundancy SingleOS Windows XP Professional English version CPU Pentium IV 2.4GHzMemory 1GBHard Disk 80GBMonitor 20 inch color LCD Accessories 3.5FD, CD-RW / DVD (Internal) Network 100B-T×3ch Keyboard Alphanumeric keyboard

7 INSTRUMENTATION AND CONTROL SYSTEMS 7.9 MACHINERY MONITORING SYSTEM



7 - 9 - 1


7.9 MACHINERY MONITORING SYSTEM

7.9.1 TURBINE GENERATOR SUPERVISORY INSTRUMENT

The turbine generator supervisory instrumentation system will be provided for

monitoring the machine variables necessary for proper operation of the turbine

generator.

The turbine generator supervisory system will be connected to TCS for monitoring

purposes, including displays on VDU’s and logging and data storage on ACS.

All primary detectors, monitors, alarm contacts, wiring, cable, interconnections, and

other accessories required for a complete installation will be provided.

The monitors will provide analog outputs (4-20 mA dc) and contact outputs for alarm and

trip functions. The instruments in the following table will be provided.

(1) For Gas Turbine (a) Shaft speed 6 pcs / GT (for control and protection)

(b) Shaft vibration (eddy-current type, X-Y) 5sets / GT&GEN(2 pcs for each bearing)

(c) Zero speed 1 pc / GT

(d) Key phaser 1 pc / GT

(2) For Steam Turbine (a) Shaft speed 6 pcs/ ST (for control and protection)

(b) Shaft eccentricity 1 pc/ ST

(c) Shaft vibration (eddy-current type, X-Y) 2 sets/ ST (2 pcs for each bearing)

(d) Shell expansion 1 pc/ ST

(e) Shell/rotor differential expansion 2 pcs / ST

(f) Shaft axial position 3 pcs / ST

(g) Key phaser 1 pc / ST

(h) Zero speed 2 pcs / ST

(i) SSS clutch shrinkage 1pc / ST

(j) SSS clutch disengage 1pc / ST

(k) SSS pinion clutch engage 1pc / ST

(l) SSS pinion clutch disengage 1pc / ST

7 INSTRUMENTATION AND CONTROL SYSTEMS 7.9 MACHINERY MONITORING SYSTEM



7 - 9 - 2


7.9.2 COMBUSTIBLE GAS DETECTORS

(1) Inside GT enclosure

Gas detectors for GT enclosure will be provided. Those are to detect leakage in

the GT enclosure at the GT enclosure ventilation fan outlet. Three (3) detectors

will be provided and used for GT trip function.

(a) GT enclosure 3 pcs / GT

(2) Inside GT fuel gas unit

Gas detectors for GT fuel gas unit will be provided. This is to detect leakage in

the GT fuel gas unit at the GT fuel gas unit ventilation fan outlet. One (1) detector

will be provided and used for alarm function.

(a) GT fuel gas unit 1 pc / GT

(3) GT exhaust duct

To detect the inflammable gas in the gas turbine exhaust duct, one (1) detector

will be provided. As this signal will be used only for startup condition, one

detector will be provided for the point. This condition is to prevent back firing in

the gas turbine during ignition period.

(a) GT exhaust duct 1 pc / GT

7 INSTRUMENTATION AND CONTROL SYSTEMS 7.10 FIELD INSTRUMENTATION



7 - 10 - 1


7.10 FIELD INSTRUMENTATION

The field instrumentation work applied for GT enclosure inside, ST lagging inside

and some factory fabricated skids inside (Fuel gas unit, Fuel oil unit, etc.) are

standardized. Each item of field instrumentation materials and design philosophy,

etc. is as follows;

(1) Cable

・Analogue Signal Circuit(1)････for transmitter, flame detector, intrinsically

safe circuit, etc.

600V copper conductor ETFE insulated overall copper braid shielded and

ETFE sheathed instrument cable (ETET-S)

・Analogue Signal Circuit(2)････for LVDT, RTD

600V pair/triad type copper conductor ETFE insulated individual pair/triad

copper braid shielded and ETFE sheathed instrument cable (ETET/TS)

・Control Signal Circuit････for press./level/limit switch/solenoid valve, etc.

600V copper conductor ETFE insulated and ETFE sheathed control cable

(ETET)

・Lighting Circuit

600V copper conductor ETFE insulated and ETFE sheathed power cable

(ETET)

・Thermocouple Circuit

EX type, ETFE insulated overall copper braid shielded and ETFE sheathed

thermocouple extension wire

7 INSTRUMENTATION AND CONTROL SYSTEMS 7.10 FIELD INSTRUMENTATION



7 - 10 - 2


(2) Instrument Installation

・The local instrument (transmitter, switch, etc.) will be mounted on the local

instrument stanchion or open rack.

・The local instrument inside of the GT enclosure, some factory fabricated skids

will be mounted on the local instrument stanchion or supporting plate.

・The temperature gauge or pressure gauge will be installed on the process

directly.

(3) Impulse Piping (Tubing) Work

・Material

Stainless steel tube (1/2” OD x 0.065” wall thickness, SUS304) is applied in

general.

(4) Instrument Air Supply and Control Piping (Tubing) Work

・Material

Stainless tube, stainless pipe and flexible hose are applied in general.

7 INSTRUMENTATION AND CONTROL SYSTEMS 7.11 DCS INTERFACE



7 - 11 - 1


7.11 DCS INTERFACE

The duplicated OPC servers (OPC A&E1.0/DA1.0 or 2.0) with routers are prepared

in the turbine control system. The communication interface to the Buyer’s DCS is

designed according to the following categories and philosophies. Refer to the

attached drawing U-F2010 also.

7.11.1 Hardwired Signal

The signals which require a fast response shall be hardwired. One category is the

signals for analyzing the cause of trouble (for example, each trip events within the

Steam turbine protection system). Dry contact signal of each trip event are

reserved for Buyer’s use, which are shown on the attached drawing U-F2010. The

signals will be inputs to SOE (Sequence of events recorder, which may be a part of

DCS) with other events from other equipment (for example, HRSG, BOP,

Substation and Generator).

7.11.2 Data Link Signal

Signals other than the above are assigned as data link signals. Assigned signals

depend on the philosophy of automation, control and reporting for operations and

maintenance.

7 INSTRUMENTATION AND CONTROL SYSTEMS 7.12 CENTRAL CONTROL ROOM SPACE INFORMATION



7 - 12 - 1


7.12 MAIN CONTROL ROOM SPACE INFORMATION

Buyer will be required to prepare cabinets, desks and installation space for the

following equipment installed in Main Control Room. Required power feeders will

be prepared by Buyer also. Please refer to the following table for more detail

information.

MHI will provide the dedicated control equipment installed at MCR such as OPS,

ACS, EMS, Printer, and CPFA (Client PC).

The arrangement designing and erection work of these equipments will be done by

Buyer accordingly.

Table 7-8 Detail information of Turbine Control equipments in MainControl Room

DESCRIPTION Qty DIMENSION (mm) REMARKS

W D H

OPS desk 1/GT 800 800 700 Heat dissipation; 1.0kVA

ACS desk 1/Plant 1600 1200 700 Heat dissipation; 1.5kVA

EMS desk 1/Plant 1600 1200 700 Heat dissipation; 1.0kVA

Printer desk 1/Plant 1600 800 700 Heat dissipation; 1.0kVA

CPFA desk 1/GT 1000 1200 700 Heat dissipation; 1.0kVA

SMCT desk 1/GT 1000 1200 700 Heat dissipation; 1.0kVA

Data Management PC desk 1/Plant 1000 1200 700 Heat dissipation; 1.0kVA

OPC Server desk 1/Plant 1600 1200 700 Heat dissipation; 1.5kVA

Space for note PCs 1/GT 1200 800 700 Located on Temporary table

7 INSTRUMENTATION AND CONTROL SYSTEMS 7.13 ATTACHED DRAWING



7 - 13 - 1


7.13 ATTACHED DRAWING

The following drawings are attached hereinafter.

Drawing No. Drawing Title U-F2010 TURBINE CONTROL SYSTEM CONFIGURATION E-20420 TURBINE GOVERNOR CONTROL DIAGRAM(GT PORTION) (1/2), (2/2) E-20460 TURBINE GENERAL LOGIC DIAGRAM (1/2), (2/2) E-10420 TURBINE GOVERNOR CONTROL DIAGRAM(ST PORTION) E-20400 TURBINE UNIT INTERLOCK DIAGRAM

－ DIVISION OF SCOPE OF SUPPLY FOR INSTRUMENTATION & CONTROL

M134352

長方形

M134352

長方形

M134352

長方形

M134352

長方形

M134352

長方形

M134352

長方形

M134352

長方形

DIVISION OF SCOPE OF SUPLY FOR INSTRUMENTATION & CONTROL

CONTENTS

I General

II Configuration of control system

III Scope of Cables & Piping

IV Supplemental Explanation

ATTACHMENTS

Attachment-1: List of I&C Engineering works

Attachment-2: Specific interface figures (Fig.1 - Fig.18)

－1－

I General

This document shows the scope of I&C engineering work and equipment applicable for contract execution.

Division of scope for I&C Engineering works are shown in Attachment-1.

The definition of the marks which are used in the relevant lists will be as below.

The marks and meaning

P : SK E&C

M : MHI

◎ : Prepare drawings and diagrams covering whole system

○ : Supply of necessary data/drawing

△ : Review and/or advice

II Configuration of control system

1. The configuration of control system is attached as “Fig-II-1: SCOPE OF SUPPLY FOR I&C and the

scope of equipment will be marked within the figure.

－2－

1

23

45

E P

Sensors such as transmitter, switch, gauge, thermocouple, speed pickup etc.

Sensors such as transmitter, switch, gauge, thermocouple etc.

E P

Sensors such as transmitter, switch, gauge, thermocouple, speed pickup etc.

M’s Portion Piping & Equipment (Internal of Steam Turbine Lagging)

E P

PLANT CONTROL SYSTEM- Plant Control System - HRSG Control System - Power Distribution Operation System - PI/O for Data Acquisition and Logging - Engineering Station - Gateway for auxiliary plant system

DRAWN

ISSUED

IH G FED CB A A3

MAIN CONTROL ROOM

FIELD

ELECTRICAL ROOM

Operator Console- VDU with keyboards

Printers - Report printers - Hard copiers

Local Control System for Auxiliary Plant System

Hardwired or Communication link

HARDWIRED EQUIPMENT ・ Operation switches ・ Emergency Trip PBs ・ Indicators, Recorders for BOP

etc.

DISTRIBUTED CONTROL SYSTEM (DCS)

M’s Portion Piping & Equipment (Internal of Gas Turbine Enclosure, Fuel Gas Unit, Purge Air Unit, Fuel Oil Unit, Flow Divider Unit, Lube Oil Reservoir Unit and Control Oil Unit)

TB

M’s HRSG Portion Piping & Equipment

TB

P’s Portion Piping & Equipment

Sensors such as transmitter, switch, gauge, thermocouple etc.

Turbine Interlock Panel

Note

P’s scope

M’s scope

Operator Station - LCD with keyboard - Printer


DIVISION OF SUPPLY & DESIGN FOR I&C

Turbine Supervisory Instrument Panel

Accessory Station - LCD with keyboard - Data Storage

OPC Server- OPC

A&E1.0/DA1.0 or2.0

OPC Client Engineering Maintenance Station - LCD with keyboard

DRAWING NO. Fig.II-1

Ethernet communication link

OPC communication link

(*1) (*1) Desks for equipment

supplied by M in Main Control Room shall be supplied by P

Generator Control System

E P

－3－

III Scope of Cables & Piping

(Note)

1) This chapter shows the division of design, supply & erection for cables and piping.

2) The designer & supplier of cables shall also design & supply installation materials, such as cable tray,

duct, fitting, cable gland and support, etc.

3) All of the site erection work shall be supplied by P.

4) The erection works of non-fabricated cables for M’s scope, that is, internal of GT enclosure, ST

lagging, etc. shall also be P’s scope.

In this case M will provide the drawing for the erection work as wiring connection at the terminal

boxes, location of instruments/terminal boxes etc.

1. Division of instrument cables design, supply & erection

(1) M’s scope

a. Design & supply for instrument cables internal of GT enclosure, Fuel gas unit, Purge air unit,

Fuel oil unit, Flow divider unit, Lube oil reservoir unit and Control oil unit.

Terminal points are terminal box mounted on base plate.

b. Design & supply for instrument cables internal of ST lagging.

Terminal points are terminal box mounted on base plate.

c. Erection of cables internal of GT Fuel gas unit, Purge air unit, Fuel oil unit, Flow divider unit

and Control oil unit.

(2) P’s scope

a. All of the other cables design, supply and erection, such as follows.

(a) Between equipment supplied by P

(b) Between equipment supplied by M

(c) Between equipment supplied by P and M

b. Erection of cables in M’s scope except internal of GT Fuel gas unit, Purge air unit, Fuel oil unit,

Flow divider unit and Control oil unit.

Table III-1 Division of instrument cables

Design Supply Erection

Internal of GT Enclosure M M P

Internal of GT Fuel gas unit M M M/P*

Internal of GT Purge air unit M M M/P*

Internal of GT Fuel oil unit M M M

Internal of GT Flow divider unit M M M

Internal of GT Lube oil reservoir unit M M P

Internal of GT Control oil unit M M M

Internal of ST Lagging M M P

Others except above P P P

*: Some equipment installation and cabling work for CO2 fire fighting system shall be done at site.

About more details, please refer to Attachment-2.

－4－

2. Division of impulse piping and instrument air tubing

(1) M’s scope

(a) Design & supply of impulse piping and instrument air tubing for instruments internal of GT

enclosure, Fuel gas unit, Purge air unit, Fuel oil unit, Flow divider unit, Lube oil reservoir unit

and Control oil unit.

(b) Design & supply of impulse piping and instrument air tubing for instruments internal of ST

lagging.

(c) Erection of impulse piping and instrument air tubing for instruments internal of GT Fuel gas unit,

Purge air unit, Fuel oil unit, Flow divider unit and Control oil unit.

(2) P’s scope

(a) All the other impulse piping and instrument air tubing design, supply and erection, such as

follows.

a. Impulse piping and instrument air tubing for instruments supplied by P

b. Impulse piping and instrument air tubing for instruments supplied by M except that in M’s

scope.

(b) Erection of impulse piping and instrument air tubing for M’s scope except internal of GT Fuel

gas unit, Purge air unit, Fuel oil unit, Flow divider unit and Control oil unit.

Table III-2 Division of impulse piping and instrument air tubing

Design Supply Erection

Internal of GT Enclosure M M P

Internal of GT Fuel gas unit M M M

Internal of GT Purge air unit M M M

Internal of GT Fuel oil unit M M M

Internal of GT Flow divider unit M M M

Internal of GT Lube oil reservoir unit M M P

Internal of GT Control oil unit M M M

Internal of ST Lagging M M P

Others except above P P P

About more details, please refer to Attachment-2.

(Note)

The definition of the marks which are used in Attachment-2 is as below.

The marks and meaning

‘P’ : SK E&C

‘M’ : MHI

◎ : Prepare drawings and diagrams covering whole system

○ : Supply of necessary data/drawing

△ : Review and/or advice

－5－

IV Supplemental Explanation

(1) APS (Automatic Plant Start-up & Shutdown) Controller and APR (Automatic Power Regulation) Controller

coordinate the slave controllers (Turbine Control System) as shown in the following.

Division of total software and hardware architecture shall be considered in the following.

APS and APR Controller is a part of DCS. The DCS shall prepare OPC (A&E1.0/DA1.0or2.0)

communication link to connect M’s Turbine Control System, so that the data can be transmitted between M’s

Turbine Control System and DCS and perform the above-mentioned control function.

(2) HRSG Control System shall be supplied by SK E&C as a part of DCS. M will provide necessary description

of HRSG control philosophy for Purchaser to prepare the control logic diagram for the HRSG Control

System.

(3) The reporting function (daily, monthly) to help future maintenance and plant management shall be the

function of Data Logger system in the part of DCS. The required data will be obtained from Turbine Control

System and others.

APS / APR Controller

OPC Client HRSG Control System

Plant ControlSystem

Data Logger

･Feedwater Pumps ･Drum level ･etc.

･ST Gland Seal System ･ST Oil System ･Turbine Drain System ･Condensate System ･Cooling Water System ･Deaerator level/press. ･Process Water System ･etc.


OPC (A&E1.0/DA1.0or2.0) communication link

DCS

OPC Server

Supplied by SK E&C

Supplied by MHI

－6－

Attachment-1 List of I&C Engineering works

Responsibility

Item M P

1. Layout Designing of Control Room, Relay Room and Electrical Room

○ ◎ M will supply outline drawings of M’s equipment such as OPS.

2. Drawing, Documents and Manuals ◎ ◎ Each for own equipment

3. Distributed Control System (DCS)

3.1 Basic design

Basic system configuration － ◎

Basic function specification △ ◎

Basic control logic diagram for APS (Automatic Plant Start-up and shutdown), APR (Automatic Power Regulator)

○ ◎ M will supply interface signal to GT & ST.

Control logic diagram for HRSG ○ ◎

Control logic diagram for BOP △ ◎

Control logic for other equipment － ◎

Input/output signal list ○ ◎ Each for own equipment

Set point list ○ ◎ Ditto

Graphic display plan (General form) ○ ◎ Ditto

VDU operation plan (General form) ○ ◎ Ditto

Logging items ○ ◎ Ditto

3.2 Detail engineering

System configuration & hardware specification

△ ◎

Function specification including display design

△ ◎ Each for own equipment

Control logic diagram △ ◎ Ditto

Interface specification for M’s control system

○ ◎

Schematic wiring diagram － ◎

3.3 System setup and programming － ◎

3.4 Shop inspection & test △* ◎ *Communication interface test

3.5 Training for each control function － ◎

3.6 Commissioning & test

Connection signal & Actual operation test △* ◎ *Support for field/control equipment in M’s scope

4. Turbine Control system for GT & ST

－7－

Responsibility

Item M P

Control logic diagram ◎ －

Interface specification to other systems ◎ －

5. Protection interlock system for GT and ST

Logic diagram (Interlock Diagram) ◎ －

Hardware Annunciation (if any) － ◎

6. Turbine supervisory instrument panel (GT & ST)

◎ －

Vibration Diagnostic/Analyzing System △ ◎ If required

7. Communication network (Data highway) (Including interface to TCS)

○ ◎ OPC communication link

8. Field Instruments

Instrument list ◎ ◎ Each for own equipment

Hook up drawing ◎ ◎ Ditto

Location plan ◎ ◎ Ditto

Bill of material ◎ ◎ Ditto

9. Internal cable of GT enclosure, Fuel gas unit, Purge air unit, Fuel oil unit, Flow divider unit, Lube oil reservoir unit, Control oil unit & ST lagging

◎ －

10. Cable & accessories except item 9

Cable including the followings; - Cable except GT/ST internal cable - Cable between GT enclosure T/B etc.

and TCS - Cable between ST lagging T/B and TCS

○ ◎ M will supply terminal information of M’s equipment.

Cable schedule ○ ◎

Tray/conduit route design ○ ◎

Control wiring diagram ○ ◎

11. Continuous Emission Monitoring System － ◎

12. Unit interlock system ○ ◎

13. Commissioning & test ○* ◎ *Technical Adviser

－8－

Attachment-2 Specific interface figures

Typical Terminal Points (interface of boundary limits) are shown in the attached drawings;

Fig - 1 TURBINE CONTROL

Fig - 2 TURBINE PROTECTION

Fig - 3 TURBINE SUPERVISORY INSTRUMENT

Fig - 4 GLAND STEAM PRESS CONTROL

Fig - 5 GLAND STEAM TEMPERATURE CONTROL

Fig - 6 TURBINE EXHAUST SPRAY CONTROL

Fig - 7 IMPULSE PIPING (1)

Fig - 8 IMPULSE PIPING (2)

Fig - 9 TEMPERATURE DETECTOR (1)



Fig - 12 INSTRUMENT AIR TUBING (1)

Fig - 13 INSTRUMENT AIR TUBING (2)

Fig - 14 MOTOR CONTROL for TURBINE

Fig - 15 MOTOR CONTROL for HRSG

Fig - 16 FUEL GAS CALORIE METER

Fig - 17 SIGNAL EXCHANGE (1)

Fig - 18 SIGNAL EXCHANGE (2)

－9－

ITEM TURBINE CONTROL Fig - 1

Power Supply Turbine

Control System

LEGEND

Scope of M Scope of P

Remark M provides only instruments. P mounts the instruments on instrument racks supplied by P. Piping and cabling are P’s portions.

GT Enclosure GT Fuel gas unit GT Purge air unit GT Fuel oil unit GT Flow divider unit GT Lube oil reservoir unit GT Control oil unit ST Lagging

Speed Pick upControl Valve

Transmitter Switch

T B

Mounted on outsideof GT Enclosure and ST Lagging

E/H

DCS

Hardwired interface

Transmitter Switch

EP

Control Valve Thermocouple,

RTD

OPC Server



All of the site erection (including equipment in M’s scope (except internal of GT Fuel gas unit, Purge air unit, Fuel oil unit, Flow divider unit and Control oil unit)) is P’s portion.

Turbine Control Package

Turbine-OPS EMS

－10－

ITEM TURBINE PROTECTION Fig - 2

LEGEND


Limit Switch

Press Switch

Trip Solenoid

TB

SV

Power Supply

Turbine Interlock Panel

Turbine Supervisory Instrument

Panel

TRIP P.B.

(OPS Desk in CCR)

DCS

Power Supply

Hardwired interface




－11－

ITEM TURBINE SUPERVISORY INSTRUMENT Fig - 3

LEGEND


Power Supply

Turbine Supervisory Instrument

Panel

GT Enclosure / ST Lagging

TB TB TB

GENGT

TB

～

・Shaft Vibration ・Shaft Position ・Shell Expansion ・Differential Expansion ・Eccentricity ・Zero Speed ・One Pulse ・SSS clutch shrinkage ・SSS clutch disengage ・SSS pinion clutch engage ・SSS pinion clutch disengage


All of the site erection (including equipment in M’s scope) is P’s portion.


DCS

OPC Server


TB TB

ST


－12－

ITEM GLAND STEAM PRESS CONTROL Fig - 4

LEGEND


NOTE) ※1 P’s scope includes control logic designing in accordance with P’s supply valves or etc, installation and testing.

※1 DCS

EP

Gland Steam Press. Control

Valve (From Aux. steam)

Gland Steam Spill Over

Valve

Gland Steam Press.

PXE

P Air Supply


Air Supply

－13－

ITEM GLAND STEAM TEMPERATURE CONTROL Fig - 5


LEGEND


TB

※1 DCS

Gland Steam Temp. Control

Valve

ST Lagging

LP Turbine Gland Steam

Temp.

E P Air Supply


－14－

ITEM TURBINE EXHAUST SPRAY CONTROL Fig - 6

LEGEND



Turbine Exhaust Spray Valve LP Turbine

Exhaust Steam Temp.

T B

Air Supply

DCS※1

ST Lagging SV


－15－

I T E M IMPULSE PIPING (1) Fig - 7

<TYPE-1> Case that instruments installed inside GT Enclosure or ST Lagging

LEGEND


Cable

Cable

Transmitter or Switch

Local Rack or Stanchion

Equipment supplied by M

TB



<TYPE-2> Case that instruments installed on skid supplied by M


Cable

GT Fuel gas flow meter skid GT Fuel gas inlet filter skid GT MFOP unit GT Water injection pump skid

<TYPE-3> Case that instruments installed on HRSG

Cable


DCS Turbine Control System




－16－

I T E M IMPULSE PIPING (2) Fig - 8


LEGEND


<TYPE-6> Case that instruments (supplied by P)installed on equipment supplied by P

<TYPE-5> Case that instruments installed on equipment supplied by P

Remark M provides only instrument. P mounts this instrument on the instrument rack supplied by P. Piping and cabling are P’s portion.

Equipment supplied by P

Cable

Equipment supplied by P

Cable

Turbine Control System or DCS

<TYPE-4> Case that instruments installed on HRSG

Cable


DCS

<TYPE-3> Case that instruments installed on equipment supplied by M except above TYPE-1 & 2

Cable





－17－

ITEM TEMPERATURE DETECTOR (1) Fig - 9

LEGEND


<TYPE-1> Case that temperature detectors installed inside GT Enclosure

TB

Compensation Wire

GT


GT Enclosure GT Fuel gas unit GT Purge air unit GT Fuel oil unit GT Flow divider unit GT Lube oil reservoir unit GT Control oil unit

<TYPE-3> Case that temperature detectors installed on HRSG

Compensation Wire

HRSG

HRSG area

DCS

<TYPE-2> Case that temperature detectors installed inside skid

GT Fuel gas flow meter skid GT Fuel gas inlet filter skid GT MFOP unit GT Water injection pump skid

Compensation Wire




<TYPE-3> Case that temperature detectors installed on HRSG

Compensation Wire

HRSG

HRSG area

DCS

－18－


LEGEND


Equipment supplied by M (outside of GT Enclosure, ST Lagging or HRSG)

Compensation Wire

<TYPE-5> Case that temperature detectors installed on equipment supplied by M (outside of GT enclosure, ST lagging or HRSG)

DCS


Compensation Wire


<TYPE-4> Case that temperature detectors installed inside ST Lagging

TB

Compensation Wire

ST ST Lagging


DCS

－19－


LEGEND


<TYPE-6> Case that temperature detectors (supplied by P) installed on equipment supplied by P

Equipment supplied by P Compensation

Wire

<TYPE-5> Case that temperature detectors installed on equipment supplied by P

Equipment supplied by P Compensation

Wire




－20－

ITEM INSTRUMENT AIR TUBING(1) Fig - 12

LEGEND


<TYPE-1> Case that control valves installed inside GT Enclosure

E P

GT Enclosure, GT Fuel gas unit, GT Purge air unit, GT Fuel oil unit, GT Flow divider unit


TB

Air Supply

Header

SV

<TYPE-2> Case that solenoid valves installed inside ST Lagging

ST Lagging

Air supply SV Turbine Control

System TB

<TYPE-3> Case that control valves installed inside HRSG

E P

HRSG area

DCS

SV

Air supply

Air supply


<TYPE-3> Case that control valves installed inside HRSG

E P

HRSG area

DCS

SV

Air supply

Air supply

－21－

ITEM INSTRUMENT AIR TUBING(2) Fig - 13

LEGEND



<TYPE-3> Case that control valves installed on piping supplied by M in GT portion (outside of GT enclosure or ST lagging)

E P Air Supply

SV

Air Supply

<TYPE-5> Case that control valve supplied by P installed on equipment supplied by P

E P Air Supply

SV

Air Supply



<TYPE-4> Case that control valves installed on piping supplied by P in GT portion (outside of GT enclosure)

E P Air Supply

SV

Air Supply


－22－

ITEM MOTOR CONTROL for TURBINE Fig - 14


MCC

MOTORMOTOR

MM

LEGEND



Power Cable

DC Starter


－23－

ITEM MOTOR CONTROL for HRSG Fig - 15

LEGEND



SWGR, MCC

MOTORMOTOR

MM

DCS

Power Cable

－24－

ITEM FUEL GAS CALORIE METER Fig - 16

Fuel gas pipeline

LEGEND



Fuel Gas

Calorie Meter


To drain pit

Sample gas vent

Gas Cylinders

Remark The fuel gas calorie meter will be supplied loose by M The gas cylinders together with the calibration gas shall be supplied by P.

Power Supply (UPS)

Instrument Air

Calorie Meter House

Remark The calorie meter will be installed inside of the house supplied by P.

－25－

ITEM SIGNAL EXCHANGE (1) Fig - 17

LEGEND


Interfacing signal specification AI: 4-20mA, Input resistance 250ohm AO: 4-20mA, Load impedance less than 550ohm/750ohm DI: Contact rating 24VDC/5mA DO: Dry Contact, Contact rating 120VDC/0.5A, 120VAC/0.5A


Panels supplied by P

Panels supplied by M

Dry Contact

Dry Contact

24VDC4-20mADC

4-20mADC

Isolator

Isolator

24VDC

120VDC

120VAC

－26－

ITEM SIGNAL EXCHANGE (2) Fig - 18

LEGEND



Instruments supplied by P

Panels supplied by M

4-20mADC

RTD (Pt100ohm, 3-wired)

Thermocouple (Type E) 24VDC powered

by TCS

2-wired type

Transmitter

RTD, T/C

Compensation Wire for T/C

E P

Control Valve

4-20mADC

SV

Solenoid Valve

120VDC

Interfacing signal specification AI: 4-20mA, Input resistance 250ohm AO: 4-20mA, Load impedance less than 550ohm/750ohm

9. TECHNICAL INFORMATION



9 - 0 - 1


9.1 （Not Used）

9.2 PAINTING SPECIFICATION

9.3 INSULATION SPECIFICATION

9.4 DESIGNN PHILOSOPHY OF VALVE NAME PLATE

9.5 SPECIAL TOOL LIST

9.6 （Not Used）

9.7 （Not Used）

9.8 UTILITY LIST

9.9 ELECTRICAL LOAD LIST

9.10 DESIGN DATA FOR LIFTING DEVICE

9.11 HEAT LOAD LIST

9.12 EQUIPMENT LOADING INFORMATION

9. TECHNICAL INFORMATION 9.2 PAINTING SPECIFICATION



9 - 2 - 1


Title Drawing No.

1. PAINTING SPECIFICATION (MHI PORTION) -

2. PAINTING PROCEDURE (MELCO PORTION) 6126-W163


PAINTING SPECIFICATION (MHI PORTION)


1. GENERAL 1.1 This Painting Specification will be applied mechanical equipment supplied by MHI

for the Turbine and the Auxiliary equipment. 1.2 The painting procedure/specification including surface preparation, coating method,

paint materials etc. for equipment/items procured as package, mass product items or standard equipment will be in accordance with the manufacturer’s standard specification. (M.S.)

1.3 Painting specification for instrumentation such as local instrument rack, stanchion,

terminal box, instruments etc. shall be in accordance with the manufacturer’s standard specifications. (M.S)

1.4 Wherever, “general name” or “specific product names” are indicated in the list, the

equivalent products will also be applicable. 1.5 Dry film thickness of painting indicated in the list means averaged thickness. 1.6 The Painting shall not be applied to the following surface of equipments and

materials. (a) Stainless steel, Aluminum, insulation lagging, Brass, Copper, Bronze, Chrome

plate, Plastic, Plastic coated material and non-ferrous material. (b) Equipment parts such as coupling, shaft, surface, of sliding etc. (c) Metal surface to be embedded in concrete. (d) Internal surface of pipes, tubes, headers, fittings, valves, pressure vessel and

others. (e) Galvanized surface except damaged area.

(f) Machined surfaces

(g) Lighting Poles

(h) Cable tray and supports

(i) Bus duct enclosure

(j) Concrete floors, curbs, side wall, paving

(k) Electrical conduit, wireways and JBs (except specified)

(l) Electrical Conductors

(m) Floor plates

(n) Gauges


(o) Glazing

(p) Hardwire

(q) Lighting fixtures except supports

(r) Porcelain embedded surface

(s) Porcelain Bushing

(t) Rubber Belt, Skirting gasket and idle disc

(u) Others which are not necessary to apply painting or will hinder on performance

1.7 Rust Preventive Means Other than Painting

(a) Inside of pre-fabricated pipes at shop will be cleaned mechanically or by air blowing depending on sizes and VCI/VPI will be enclosed for rust prevention during transportation.

VCI･･･Vapour Corrosion Inhibitor

VPI･･･Vapour Phase Inhibitor

(b) Machined surface of weld end preparation and surfaces within 75 mm of field welds shall be coated with consumable rust preventive coating.

(c) 50A and smaller pipes will be capped at shop and Wash Primer will be applied to pipes at mill shop to prevent the rust during transportation.

1.8 Lead, Chrome and Cadmium are not included in all paint products.

1.9 Blasting media shall be shot, slag or girt. The use of sand or silica bearing material is prohibited.


Detailed Painting Schedule

System No.

Application

Place of operation

Surface preparation

General name ( Product name )

Number of coat

Dry Film Thickness

(μ)

Remarks

2 Pack Epoxy Zinc Rich Paint (ZETTAR EP-2HB or equivalent)

1* 75** Shop Blast Cleaning SSPC SP 10

2 Pack Epoxy MIO Paint (EPONICS MIO or equivalent)

1* 75**


( 1* ) ( 75** )


( 1* ) ( 75** )

Spot cleaning and touch up for damaged area only

1A Structural steel : For indoor & Outdoor : Not for stainless steel

Site Power Tool Cleaning SSPC SP 3

Acryl Polyurethane Enamel (V TOP-HB or equivalent)

1 50

Mark* :If the paint method is brush, the number of coat is 2. Mark** shows total D.F.T. The paint does not include Pb, Cr and Cd.



System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks


1* 75** Shop Blast cleaning SSPC SP 10


1* 75**


( 1* ) ( 75** )


( 1* ) ( 75** )


1B Structural steel : For indoor only : Not for stainless steel

Site Power tool cleaning SSPC SP 3

2 Pack Epoxy Top Coat (EPONICS #20 TOP COAT or equivalent)

1 50




System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks


1* 75**

2 Pack Epoxy Coating (EPONICS #20 TOP COAT or equivalent)

1* 75**

Shop Blast cleaning SSPC SP 10


1 50


( 1* ) ( 75** )


( 1* ) ( 75** )

2A Structural steel : For Indoor & Outdoor : Not for stainless steel



( 1 ) ( 50 )





System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks


1* 75**


1* 75**



1 50


( 1* ) ( 75** )


( 1* ) ( 75** )

2B Structural steel : For Indoor only : Not for stainless steel



( 1 ) ( 50 )





System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks




1* 75**


( 1* ) ( 75** )


( 1* ) ( 75** )


3A External surface of equipment & pipe : For Indoor & Outdoor : Below 100°C : Not for stainless steel



1 50




System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks




1* 75**


( 1* ) ( 75** )


( 1* ) ( 75** )


3B External surface of equipment & pipe : For Indoor only : Below 100°C : Not for stainless steel



1 50




System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks


1* 75**


1* 75**



1 50


( 1* ) ( 75** )


( 1* ) ( 75** )

4A External surface of equipment & Pipe : For Indoor & Outdoor : Below 100°C : Not for stainless steel



( 1 ) ( 50 )





System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks


1* 75**


1* 75**



1 50


( 1* ) ( 75** )


( 1* ) ( 75** )

4B External surface of equipment & Pipe : For Indoor only : Below 100°C : Not for stainless steel



( 1 ) ( 50 )





System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks

Ethyl Silicate Zinc Rich Paint / High Build Type

(ZETTAR OL-HB or equivalent)

1 50 Shop Blast cleaning SSPC SP 10

Silicone Aluminum Heat Resistant Paint (PYROSIN B #1000 SILVER

or equivalent)

1 10



1 ( 50 )


or equivalent)

1 ( 10 )


5 External surface of equipment & pipe : High temperature service/Below 400°C : Not to be insulated : Not for stainless steel



or equivalent)

1 10




System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks





or equivalent)

2 10 / Coat



1 ( 50 )



Silicone Aluminum Heat Resistant Paint (PYROSIN B #1000 SILVER or equivalent)

2 (10 / Coat )





System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks

Silicone Aluminum Heat Resistant Paint (PYROSIN B #1000 SILVER HB

or equivalent)



or equivalent)

( 1 ) ( 25 )


or equivalent)

1

25







System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks


or equivalent)

2 25/Coat Shop Blast cleaning SSPC SP 10


or equivalent)

( 2 ) ( 25/Coat )

8 External surface of equipment & pipe : High temperature service/Below 600°C : Not to be insulated : Not for Stainless Steel






System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks

Epoxy Zinc Phosphate Primer (EONICS ZP or equivalent)

2*

60** / Coat

Epoxy MIO Paint (EPONICS MIO or equivalent)

1* 50**

9A External surface site fabricated pipe : For Indoor & Outdoor : Below 100°C : For water, air, steam and gas piping : Not for stainless steel



1 50**




System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks


1* 75**

2 Pack Epoxy Under Coat (EPONICS #20 UNDER COAT

or equivalent)

1* 75**

9B External surface site fabricated pipe : For Indoor only : Below 100°C : For water, air, steam and gas piping : Not for stainless steel

Site Blast cleaning SSPC SP 10


1 50




System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks



1* 75**


( 1* ) ( 75** ) Spot cleaning and touch up for damaged area only


1* 75**

10A External surface site fabricated pipe : For Indoor & Outdoor : Below 100°C : For oil piping : Not for stainless steel



1 50




System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks



1* 75**


( 1* ) ( 75** ) Spot cleaning and touch up for damaged area only

2 Pack Epoxy Under Coat (EPONICS #20 UNDER COAT

or equivalent)

1* 75**

10B External surface site fabricated pipe : For Indoor only : Below 100°C : For oil piping : Not for stainless steel



1 50




System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks


Zinc Phosphate / Alkyd Primer (ZP PRIMER NON-LEAD or equivalent)

1* 70** 11 External surface of equipment and pipe : High Temperature : To be insulated Site Power tool

cleaning SSPC SP 3

Zinc Phosphate / Alkyd Primer (ZP PRIMER NON-LEAD or equivalent)

1 ( 70 ) Spot cleaning and touch up for damaged area only




System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks

Shop Galvanizing 12 Galvanized surface (Touch-up) : Below 150°C Site Power tool

cleaning SSPC SP 3

Epoxy Zinc Rich Paint / High Build Type (ZETTAR EP-2 HB or equivalent)

1* ( 70** ) Spot cleaning and touch up for damaged area only




System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks

Special Epoxy Primer (ETON #2100E PRIMER

EXPORT GRAY)

2 30/Coat Shop Blast cleaning SSPC SP 10

Special Epoxy Silver Paint (ETON #2100E SILVER)

2 25/Coat

Special Epoxy Primer (ETON #2100E PRIMER

EXPORT GRAY)

( 2 ) ( 30/Coat )

13-1 Internal surface for lube oil tank and surface immersed into oil for pump

Site Sanding treatment with abrasive paper and Solvent cleaning SSPC SP 1

Special Epoxy Silver Paint (ETON #2100E SILVER)

( 2 ) ( 25/Coat )





System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks

15-1 Internal surface for exhaust duct (EB01) Internal surface for GT exhaust expansion joint

Shop Commercial blastcleaning SSPC SP 6

Quick Drying Temporary Anti-Corrosive Clear

(BOGO CLEAR #100 QD or equivalent)

2 15/Coat




System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks




1 50 15-2 Internal surface for exhaust duct (EB02) : Below 400°C : Not for Stainless Steel Site Power tool

cleaning SSPC SP 3



( 1 ) ( 50 ) Spot cleaning and touch up for damaged area only




System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks

16-1 External surface for exhaust duct (EB01)

Shop Commercial blastcleaning SSPC SP 6

Quick Drying Temporary Anti-Corrosive Clear

(BOGO CLEAR #100 QD or equivalent)

2 15/Coat




System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks



or equivalent)

2 40** 16-5 External surface for up-stream side of G/T exhaust expansion joint (EE-01) : High temperature service/Below 600°C : Not to be insulated



or equivalent)

( 2 ) ( 40** ) Spot cleaning and touch up for damaged area only




System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks


1* 75**


1* 75**



1 50


( 1* ) (75** )


( 1* ) ( 75** )

17 Internal surface for G/T inlet air duct

Site Power tool Cleaning SSPC SP 3


( 1 ) ( 50 )





System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks




1* 75**


( 1 ) ( 75** )


( 1 *) ( 75** )



1 50

18-1 External surface for G/T inlet air duct (Not insulated)





System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks




1* 75**


( 1* ) ( 75** )

18-2 External surface for G/T inlet air duct (Insulated surface)



( 1* ) ( 75** )





System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks

Epoxy Melamine Primer (DELICONE #260 NPS or equivalent)

2 20/Coat Shop Pickling SSPC SP 8 and phosphatizing

Melamine Alkyd Enamel (DELICCONE #700 or equivalent)

2 20/Coat

19 Instrument and Panel

Site Sanding treatment by abrasive paper

Acryl Polyurethane Enamel (V TOP-H TOP COAT or equivalent)

( 2～3 ) ( 80**) Spot cleaning and touch up for damaged area only




System No.

Application

Place of operation

Surface preparation


Number of coat

Dry Film Thickness

(μ)

Remarks

Shop M.S. M.S. M.S. M.S. 23 Equipment/Items procured as package, mass product items or standard equipment Such as crane, valve, DG set, fire detection system and others which are finish painted in shop to manufacture’s standards.

Site Sand Treat. or power tool according to manufacture’s standard

( M.S.) ( M.S.) ( M.S.) Spot cleaning and touch up for damaged area only
