Document Code: S1M____-BDB2501d-1

Issuing date: 6 May, 2003

Status: d

Project:

WEST OFFALY POWER

Author: Approved: Language:

H. Murakami H. Murakami English
Document title:

System Description of Turbine, Generator and Condenser

Submitted for: Customer reference: Other information:

Revision remarks
Revision: Revision date: Modified information: Initials:
(a) 6 June 2003 According to MOM#8 H.M.
(b) 1 July 2003 PID KKS code changed H.M.
(c) 19 Sept. 2003 Correct typograghical error H.M.
(d) 22 Oct. 2003 Revised according to FW comment H.M.

For Information

Prepared by:
 S1M____-BDB2501d-2

CONTENTS
1.0 TURBINE SYSTEM

2.0 LUBE OIL SYSTEM

3.0 CONTROL FLUID SYSTEM

4.0 GENERATOR SYSTEM

5.0 CONDENSER SYSTEM

6.0 LP FEED WATER HEATER SYSTEM

7.0 VACUUM PUMP SYSTEM

8.0 TURBINE CONTROL SYSTEM

9.0 TURBINE PROTECTION SYSTEM

10.0 GENERATOR PROTECTION SYSTEM

Attachment:
Cross Reference List for System Description and
Pre-Commissioning/Commissioning Item
 S1M____-BDB2501d-3

1.0 TURBINE SYSTEM

Reference P&I Diagram ;

Extraction Steam S1LBD__-MFB2501 (PL219201)

Gland Steam S1MAW__-MFB2501 (ST219119)
Drain S1LB___-MFB2503 (PL219200)

1.1 System Description

The 150 MW steam turbine is reheat, condensing and two casings type
and operates at 3000rpm.
Design steam condition at the main steam inlet flange is 165 bar
absolute at 560oC with exhaust pressure of 0.028 bar absolute.
Two main stop valves equipped with hydraulic actuators are fully
opened to supply steam to the turbine or fully closed to stop to supply
steam to the turbine. Two governor controlled main control valves are
fitted downstream of the stop valves, which modulate under governor
action to control the steam flow and subsequent turbo generator
output.

1.1.1 Turbine

The each turbine casing is split with a horizontal joint flange.

There is a condenser connection at the bottom of LP turbine casing,
which is directly connected to the condenser that is solidly mounted on
the floor.
Two rupture disk type pressure relief fittings are mounted on the top of
upper section of LP turbine casing to ensure the turbine and condenser
not being pressurized.

Pressure of a gland steam is controlled by a supply steam control valve

and/or an exhaust steam control valve as 1.079 bar absolute to seal
turbine glands. Source of supply steam is either auxiliary steam boiler,
cold reheat steam or No.3 extraction steam.
The leak off steam is led to gland steam condenser where steam is
condensed and recovered to condenser while air is released to
atmosphere by an exhaust fan.

1.1.1 Turbine Drain system

Drain lines are provided on main steam control valves, HIP turbine
casing and reheat steam stop valves to remove drain. Drain is led to
condenser through flash chamber by opening motor operated valve
automatically at start up and shut down.
 S1M____-BDB2501d-4

1.1.2 Reheat and Extraction Check Valves

The check valves are provided on cold reheat steam line and extraction
steam line to prevent the turbine from over speed at turbine load
rejection and to prevent the turbine from damage due to reverse flow of
drain and/or cold steam at feed water heater tube leakage.
These check valves have a pneumatic actuator and are forced to close
when turbine trip, water level in feed water heater emergency high.

1.1.3 Turning Device

The steam turbine is equipped with the electrical turning device which
prevents any bending of the rotor and casing during start up, shut down
and standstill. The turning device can be operated both automatically
and manually.
The turning device is installed on the No.1 bearing pedestal.

1.1.4 Seal Water System for Valve Gland

In order to prevent air from getting into a line that is a vacuum condition
during normal operation, seal water is injected to the gland for valves
being more than 65mm and equal diameter.
Valves having bellows seal at the gland are applied for smaller valves
because such seal water boss can not be provided.

1.1.5 LP Turbine Spray Water system

LP turbine casing temperature will raise at turbine no load operation

due to less exhaust steam. LP turbine spray system is provided for
lowering the temperature. When the temperature is higher than the
setting value, the spray water stop valve is automatically opened.

1.2 Equipment Data

1.2.1 Steam turbine

Type Two casing (HIP combined and LP),
Reheat, Condensing.
Rated output 150,000 kW
Rated steam pressure 165 bar absolute
Rated steam temperature 560oC
Exhaust pressure 0.028 bar absolute
Direction of rotation Counterclockwise viewed from the front

1.2.2 Rupture disk

Quantity Two
Material Stainless steel
 S1M____-BDB2501d-5

1.2.3 Cold reheat check valve

Type Swing check valve with pneumatic cylinder
Size (nominal bore) 600 mm
Class (nominal press.) ANSI 600 LB
Connection Butt weld

1.2.4 Extraction steam check valve

1) No.5 extraction steam
Type Swing check valve with pneumatic cylinder
Size (nominal bore) 200 mm
Class (nominal press.) ANSI 300 LB
Connection Butt weld

2) No.4 extraction steam

Type Swing check valve with pneumatic cylinder
and swing check valve without pneumatic
cylinder
Size (nominal bore) 350 mm
Class (nominal press.) ANSI 150 LB
Connection Butt weld

3) No.3 extraction steam

Type Swing check valve with pneumatic cylinder
Size (nominal bore) 600 mm
Class (nominal press.) ANSI 150 LB
Connection Butt weld
 S1M____-BDB2501d-6

2.0 LUBE OIL SYSTEM

Reference P&I Diagram ;

Lube Oil S1MAV__-MFB2501 (ST113069)

Cooling Water S1MAJ__-MFB2501 (PL321895)

2.1 System Description

The turbine lube oil system provides oil to the turbine and generator for
lubrication and cooling of the bearings and jacking up of turbine and
generator rotor at start up and shut down.

2.1.1 Main Oil Tank

The main oil tank is a reservoir.

Return lubricating oil enters the tank to remove solid debris. The oil
tank has internal baffles to ensure the oil to be held in the tank for a
time period to allow release of any entrained air and suspended
particles.
The main and emergency oil pumps are mounted on top of the tank.
The jacking oil pump is installed on the skid. The oil tank is fitted with a
vapor extraction fan that maintains a slight vacuum in the tank and
bearing oil return lines.
The main oil tank is fitted with electric heater that maintains the tank
temperature between 35oC and 40oC when the turbine has been off
load and the lube oil has cooled.

2.1.2 Main Oil Pump

The main oil pump is a vertical mounted single suction centrifugal type.
The pump is fitted to supply lubricating oil to the each bearing.
A check valve in the main oil pump outlet prevents a back flow through
the pump when the pump is not running.
The standby oil pump is started automatically when discharge pressure
of operating pump is detected as low.

2.1.3 Emergency Oil Pump

An emergency DC powered lubricating oil pump is fitted. This pump is

vertical mounted single entry centrifugal type. The pump supplies oil
directly to the turbine bearings, bypassing the filters and coolers.
The emergency oil pump starts automatically on detection of low
bearing oil pressure.
 S1M____-BDB2501d-7

2.1.4 Jacking Oil Pump

An axial piston type high-pressure oil pump supplies oil to the turbine
and generator bearings. The high-pressure oil lifts (jacks) the turbine
and generator rotor off the bearings and allows the turning gear to
move the rotor.
This pump is used at all times when the turbine is turning. Operation of
the pump is automatic with starting and stopping being initiated by the
turning gear start and stop.
The jacking oil pump can be supplied from the main oil tank or the
bearing lubricating oil supply line after the filters.

2.1.5 Oil Coolers and Filters

There are two 100% duty plate type oil coolers to cool the lube oil by
water supplied from the auxiliary cooling water system. The oil
temperature is regulated by the action of the oil flow control valves.
There are two transfer valves for changing over the duty cooler.
The duplicate type oil filter is fitted with a transfer valve for changing
over the duty filter. The transfer valve ensures that the correct valve
operation occurs during filter change over. The oil filters should be
changed over and the fouled filter change over when the differential
pressure exceeds an allowable limit.
The lubricating oil flow to each bearing can be regulated by action of
the throttle valve fitted in each bearing oil supply pipe.

2.2 Equipment Data

2.2.1 Main oil tank

Quantity One
Type Box type
Capacity 8 m3 normal
Lube oil Turbine oil ISO VG-32

2.2.2 Vapor extractor

Quantity One
Capacity 5.5 m3/min

2.2.3 Main oil pump

Quantity Two (one for operation, one for standby)
Type Vertically centrifugal
Capacity 80 m3/hour at 5.5 bar gauge

2.2.4 Emergency oil pump

Quantity One
Type Vertically centrifugal
Capacity 48 m3/ hour at 2.2 bar gauge
 S1M____-BDB2501d-8

2.2.5 Jacking oil pump

Quantity One
Type Horizontally centrifugal
Capacity 9 m3/ hour at 168 bar gauge

2.2.6 Lube Oil cooler

Quantity Two (one for operation, one for standby)
Type Water cooled, plate type
Quantity of cooling water 0.02223 m3/sec

2.2.7 Oil filter

Quantity One
Type Duplex bucket type
Mesh 37 micron m (400 mesh)
 S1M____-BDB2501d-9

3.0 CONTROL FLUID SYSTEM

Reference P&I Diagram ;

Control Fluid S1MAX__-MFB2501 (ST113070)

3.1 System Description

The turbine control fluid system provide fluid to the servo motor control
of the position main stop valves, main control valves, reheat stop
valves and reheat control valves and some protective devices of the
turbine.
.
Control fluid is of fire-resistant type.

3.1.1 Control Fluid Tank

The control fluid tank is a reservoir.

3.1.2 Control Fluid Pump

The Control fluid pump is an axial piston pump. The pump is fitted to
supply control fluid to the actuators for main stop valves, main control
valves, reheat stop valves and reheat control valves.
The standby pump is started automatically when discharge pressure of
operating pump is detected as low.

3.1.3 Heating Pump

There is a heating pump that raises the control fluid temperature in the
tank up to 40oC by re-circulation of the control fluid.

3.1.4 Coolers and Filters

There are two 100% duty finned type coolers to cool the control fluid by
air.
The both suction and discharge filters are fitted to each control fluid
pump. The control fluid pump should be changed over and the fouled
filter cleaned when the differential pressure exceeds an allowable limit.

3.2 Equipment Data

3.2.1 Control Fluid Tank

Quantity One
Type Box type
Capacity 500 litter normal
Control fluid Fire-resistant Type
 S1M____-BDB2501d-10

3.2.2 Control fluid pump

Quantity Two (one for operation and one for standby)
Type Horizontal gear pump
Capacity 56 litter/min at 160 bar gauge

3.2.3 Heating pump

Quantity One
Type Horizontally centrifugal
Capacity 53 litter/min at 50 bar gauge

3.2.4 Control fluid cooler

Quantity Two (one for operation and one for standby)
Type Air cooled, finned tube type

3.2.5 Suction filter

Quantity Two
Type Bucket type
Mesh 100 mesh

3.2.6 Discharge filter

Quantity Two
Type Bucket type
Mesh 15 micron m (c)
 S1M____-BDB2501d-11

4.0 GENERATOR SYSTEM

Reference P&I Diagram ;

Cooling Water S1MAJ__-MFB2501 (PL321895)

4.1 System Description

The generator is two-pole, totally-enclosed water to air cooled type.

The stator winding insulation is F class and temperature rise is B class.

4.1.1 Generator cooling

The cooling air is circulated in the generator interior in a closed circuit

by two axial fans fitted on each side of the rotor shaft, and re-cooled in
air coolers mounted on the side of generator. The water leakage
detector is set under the air coolers. In event of a cooler tube leak an
alarm will be raised to alert the operator.

4.1.2 Excitation and Automatic Voltage Regulation

The generator uses a brushless excitation system. The 3 phase AC

exciter output is generated on the rotor, and connected to the rotating
rectifier also mounted on the generator rotor. The DC output of the
rotating rectifier is supplied to the rotor windings.
The output voltage of the generator and generated power factor is
controlled by the turbine governor panel (TGR), which regulates the
field current of the exciter.

4.1.3 Space Heater

When the generator stops operation, inside temperature comes down.

If the internal temperature comes down lower than dew point, moisture
so far contained in the machine interior becomes dew that will attach
on the surface of the machine. It brings about not only deterioration of
insulation but also cause of rust production. In sequence, space
heaters are installed under the generator and at the same time as the
machine stop the heater switch is turned on to protect temperature
coming down.
 S1M____-BDB2501d-12

4.2 Equipment Data

4.2.1 Generator
Type Totally enclosed air to water cooled,
3 phase AC synchronous generator
Rating Continuous
Output 181,700 kVA
Voltage 11,500 V
Current 9,122 A
Number of phase 3 phase
Power factor 0.85 (lagging)
Frequency 50 Hz
Rotating speed 3,000 rpm
Excitation method Brushless
Insulation class F
Temperature rise B

4.2.2 Brushless exciter

Type Brushless
Rating Continuous
Output 560 kW
Voltage DC 470 V
Current DC 1191 A
Frequency 300 Hz
Poles 12
Insulation class F

4.2.3 Permanent magnet generator

Type Permanent magnet generator
Rating Continuous
Output 5 kVA
Voltage 220 V
Current 13.1 A
Frequency 300 Hz
Poles 12
Insulation class F
 S1M____-BDB2501d-13

5.0 CONDENSER SYSTEM

Reference P&I Diagram ;

Condenser S1MAG__-MFB2501 (PL219202)

Cooling Water S1MAJ__-MFB2501 (PL321895)
Drain S1LB___-MFB2503 (PL219200)

5.1 System Description

The main condenser serves primarily to condense the steam as it

leaves the turbine. In addition, the main condenser serves a secondary
function as the collection point for the flowing condensate streams:

1) Gland steam drain.

2) Turbine steam system drain.

5.1.1 Condenser

The surface condenser is tube and shell type. The cooling water flows
through the cooling tubes where indirect contact of the exhaust steam
and cooling water occurs. As the steam is condensed, the condensate
is collected in the main condenser hotwell and delivered to the
deaerator through LP heaters by the condensate pump.
Non-condensable gases not absorbed into the condensate are
extracted from the condenser by the vacuum pump system to maintain
0.028 bara. of vacuum pressure at the design conditions.
The condenser has two separate cooling water chambers allowing tube
blocking during operation if tube leakage is occurred.
LP bypass nozzle with necessary erosion protection is located at the
condenser neck.

5.1.2 Air Evacuation System

The purpose of the liquid ring type vacuum pump system is to remove
air accumulated in the top of condenser cooling water chamber.
The mixture of air with water is extracted by the vacuum pump through
vacuum tank to prevent the pump from water induction. Water is led to
drain funnel through a barometric tank while air is released to
atmosphere through a separator.
 S1M____-BDB2501d-14

5.2 Equipment Data

5.2.1 Condenser
Type Surface type
Internal Pressure 0.028 bara
Cooling water Inlet temperature 12 oC
Cooling water outlet temperature 19.96 oC
Cooling Water Flow Rate 17,511 m3/hr
Size of cooling tube 23mm (outer dia.), 0.7mm (thick)
Number of Cooling Tube 12,764
Total cooling surface 10,744 m2
Number of Pass 2
Material of Cooling Tube Stainless steel type 304

5.2.2 Air Evacuation System

Vacuum Pumps
Quantity One
Type Liquid ring vacuum pump
Speed 1500 rpm
Seal Water 19 l/min
Separator
Quantity One
Type Vertically cylindrical
 S1M____-BDB2501d-15

6.0 LP FEED WATER HEATER SYSTEM

Reference P&I Diagram ;

Extraction Steam S1LBD__-MFB2501 (PL219201)

Drain S1LB___-MFB2503 (PL219200)

6.1 System Description

The LP feed water heater No.1 is tube and shell type. The condensate
from condensate pump outlet flows through the cooling tubes where
indirect contact of the extraction steam and cooling water occurs. As
the steam is condensed, the condensate is collected to the condenser.
The heater is installed in the condenser neck. The extraction steam
piping from LP turbine casing to the heater is installed in the condenser.
Heater drain is led to the condenser through U-seal piping to
compensate differential pressure between heater internal pressure and
condenser internal pressure.

6.2 Equipment Data

Type Indirect contact tube and shell type

Design Condition
Extraction steam inlet 0.09 bara / 43.6 deg.C
Heater drain outlet 0.09 bara / 43.6 deg.C
Condensate inlet 15 bara / 18.3 deg.C
Condensate outlet 15 bara / 38.2 deg.C
Number of Tube 204
Total cooling surface 189 m2
Number of Pass 2
Material of Tube Stainless steel DIN 1.4301
 S1M____-BDB2501d-16

7.0 VACUUM PUMP SYSTEM

Reference P&I Diagram ;

Condenser S1MAG__-MFB2501 (PL219202)

Cooling Water S1MAJ__-MFB2501 (PL321895)

7.1 System Description

The purpose of the liquid ring type vacuum pump system is to remove
non-condensable gases from the main condenser that accumulates as
the incoming steam condenses.

The non-condensable gases are taken separately off the gas cooling
zones of the main condenser. The non-condensable gas from the main
condenser gas cooling zones flows first through vacuum pump.

The non-condensable gas is extracted through the vacuum pump and

separated at the separators. The non condensable gas is then
released to atmosphere. While the condensate is used as seal water of
vacuum pump through the booster pump and seal water cooler.

7.2 Equipment Data

7.2.1 Vacuum Pumps

Quantity Two (one for operation, one for standby)

Type Liquid ring vacuum pump
Speed 490 rpm
Seal Water 13.8 m3/h

7.2.2 Separator
Quantity Two (one for operation, one for standby)
Type Vertically cylindrical
 S1M____-BDB2501d-17

8.0 TURBINE CONTROL SYSTEM

Reference Document ;

Description of TGR system S1MAY__-BFB2501 (WA56566)

STG EHG & AVR (TGR) Logic Diagram S1MAY__-BFF2502 (WA46330)
Schematic Diagram for TGR System S1MAY__-BFB2502 (W431187)

8.1 System Description

The EHG function consists of mainly following control loops;

(1) Speed control loop
(2) Power control loop
(3) Turbine inlet steam pressure (MSP) control loop
(4) Steam pressure Limiter control loop
(5) Condenser Vacuum Limiter control loop
(6) Control valve (CV) position control loop

8.1.1 Speed Control Loop

2 speed inputs are processed by high selector gate, higher value is

used for speed control.
The speed control loop only determines control valve position to adjust
turbine speed at setting value before the generator is paralleled to the
power system. Such the task is transferred to the power control loop
or the MSP control loop after synchronization with the system, however,
it is put on the position for back-up protection at the same time to
prevent from over-speed during parallel operation.

8.1.2 Power Control Loop

The steam turbine shall be controlled on this MW-control mode

normally. In the event of a drop of grid frequency, the governor valves
shall open instantaneously to provide frequency support in the form of
additional MW.
When the main steam pressure (MSP) control mode is operation, this
MW-controller is tracking to the main steam pressure (MSP) controller.

8.1.3 Turbine Inlet Steam Pressure (MSP) Control Loop

2 main steam pressure inputs are processed by high selector gate,

higher value is used for MSP control.
MSP mode (Turbine Follow mode) of operation results in the governing
system modulating the steam flow to regulate the steam pressure at a
fixed value. The control system shall switch automatically to this mode
when faults occur which prevent normal control of the boiler. MSP
mode will take over following a drop in steam pressure of 10% or an
 S1M____-BDB2501d-18

increase in pressure of 3%. It shall be possible to manually switch to

this mode.
When the power control mode is operation, this steam pressure
controller is tracking to power controller.

8.1.4 Steam Pressure Limiter Control Loop

The pressure limiter shall override the governor and progressively

reduce the steam flow to the turbine as the steam pressure before the
HP steam turbine governing valves drops below a predetermined value
in order to limit serve drops in steam temperature.

8.1.5 Condenser Vacuum Limiter Control Loop

This limiting controller shall override the governor and progressively

reduce the steam flow to the turbine as the condenser vacuum falls
over a predetermined range in an effort to maintain the condenser
vacuum at this value. The setting shall be adjustable. It shall be
possible to override the device during vacuum raising and it shall not
come into operation below 1000 rpm.

8.1.6 Control Valve (CV) Position Control Loop

An output from the above loops is given to the CV position control loop
as its setting. Consequently, it adjusts CV position in accordance with
its characteristic curves respectively.
This portion outputs opening command to the Electro-hydraulic (E/H)
converter mounted on each CV separately. Due to each E/H
converter having two magnet coils, two separate signal (±10V) lines
are connected to them.

8.2 Operation scheme

This system supports following operation stage;

8.2.1 Start-up Operation

(1) Before synchronizing

Speed control loop functions during turbine acceleration up to
rated speed after steam admission. Around rated speed the
setting can be adjusted for synchronizing by manual or
automatically from automatic synchronizing system (ASY).

(2) After synchronizing

Just after synchronization, an initial load is instantaneously
taken by it to avoid the generator reverse power. At the same
time, speed setting is fixed at rated speed by interlock action
and the speed control loop will function as back-up protection
 S1M____-BDB2501d-19

against over speed.

8.2.2 Normal Operation

During normal operation, Power control loop functions under constant

pressure
The steam turbine should be capable of operation with a fixed boiler
pressure by controlling the governor valves. While operating in this
mode the steam turbine should be capable of providing primary
operating reserve in the form of addition megawatts by immediately
opening of the governor valves in the event of system frequency dips.

8.2.3 Shutdown Operation

Unloading up to the minimum load is conducted by the power control

loop.
 S1M____-BDB2501d-20

9.0 TURBINE PROTECTION SYSTEM

Reference Document ;

Description of Over Speed Protection System S1MAY__-BEC2504

Turbine Protection Logic Diagram S1MAY__-BFF2503 (WA46326)

9.1 System Description

Turbine protection device are arrange to actuate trip solenoid valve for
main steam stop valve /reheat stop valve, and operate to close these
emergency valves.
In case the following faults is occurred in turbine and the around,
turbine would be stopped automatically.

The Function of Turbine Protection

(1) Over speed
(2) Thrust failure
(3) Shaft vibration high
(4) Main steam inlet temp. Low
(5) HP exhaust steam temp. high
(6) LP exhaust steam temp. high
(7) Exhaust steam press. high
(8) Lube oil supply press. Low
(9) Boiler trip (MFT)
(10) Generator trip
(11) EHG heavy fault
(12) Manual trip (TURBINE TRIP PB ON)
(13) Power system frequency low
(14) Reverse power

9.2 Function

9.2.1 Over Speed

(1) Overall
The turbine shall be provided with duplicated independent over
speed protection channels.
Over speed protection system is mainly composed of Bentry
Nevada 3500/53 over speed system, speed sensor, proximittor.
The speed signal (pulse signal) detected by 6 pieces of speed
sensors is transmitted to 3500/53 system.
In case of over speed, 3500/53 system output-relay operates,
and the trip signal is processed by duplex 2 out of 3 voting
hardwired circuit.
These devices shall be entirely separate from the regulating
governor and shall be capable of effecting immediate closure of
 S1M____-BDB2501d-21

both emergency stop and governor valves.

The turbine Protection System has both 110% and 105% setting
for over speed protections.
When the unit is synchronized, the trip setting value shall be set
at 110% (3300rpm).
And when the unit is un-synchronized, the trip setting value shall
be set at 105% (3150rpm).
The above descriptions are presented in attached “Turbine
protection system overview”

(2) TUeV approval

Bentry Nevada 3500/53 over speed detection system is
available with TUeV certification, as the system of detection
monitor, Proximittor(amplifier), probe(speed pick up).

(3) Testing procedures of over speed protection

The 3500 over speed protection module has an on board
frequency generator that can generate a test signal for testing
the over speed protection function of the monitor.

Test mode is performed by BN Maintenance tool that are connected to

rack interface module.

1) Run the Rack Configuration Software on the test

computer (Maintenance tool).
2) Enter a Start RPM (400rpm minimum) and an End RPM
(limited to the upper full scale range) for the test
frequency to sweep through.
3) Choose Verification from the Utilities menu and choose
the slot of the Over speed Protection Module to be tested
then click the Verify button.
4) Verify that the OK LED is on, that the Channel OK State
status on the Over speed Protection Verification screen
reads OK, the bar graph indicator for Speed is green, and
that the Current Value Field has no alarm indication.
5) Click on the Invoke Test Mode button on the Verification
screen. This will initiate the Over speed Test function.
The rpm displayed on the bar graph indicator for Speed
will begin to ramp from the configured Test Mode Start
rpm.
6) As the rpm level exceeds the Over Alert/Alarm1 set point
level, verify that the bar graph indicator for Speed
changes color from green to yellow and that the Current
Value Field indicates an alarm.
7) As the rpm level exceeds the Over Danger/Alarm2 (Over
speed) set point level verify that the bar graph indicator
for Speed changes color from yellow to red and that the
 S1M____-BDB2501d-22

Current Value Field indicates an alarm. If Enable Relays

While in Test Mode is enabled, verify that the Over speed
relay contacts change state.
8) Click on the Invoke Test Mode button on the Verification
screen again to remove the module from Test Mode. The
Over speed Protection Module will perform a full self-test
before resuming monitoring functions.

Verify that the monitor passed the self-test.

9.2.2 Thrust Failure (Shaft position protection)

Electrical thrust protect device includes 3 non-contact displacement

detectors that are installed in standstill side, the opposite of the disk on
turbine shaft.
The shaft position signals detected by 3 pieces of displacement sensor
are transmitted to 3500/45 system.
The alarm will be issued when mean value of 3 shaft position signals
over alarm value due to the fault such as wear of thrust bearing,
In case of thrust failure, 3500/45-system output-relay operates, and the
trip signal is made by 2 out of 3 logic circuit in turbine protection
system.

Alarm : ± 0.5 mm
Trip : ± 1.0 mm

9.2.3 Shaft Vibration High

The shaft vibration monitoring 3500/32-systems measure X-Y

directions per bearing #1 to #5 of turbine generator.
The alarm will be issued when high-selected value of X-Y direction
signals over alarm value.
Turbine trip will be occurred only when more than one probe measures
over trip value and the other probe installed at next bearing measures
over alarm value.

Alarm : 125micron-meter (peak to peak)

Trip : 250micron-meter (peak to peak)

9.2.4 Main Steam Inlet Temperature Low

Turbine shall be tripped in order to prevent the damage by low

temperature steam getting into high-pressure turbine.
The alarm will be issued when mean value of 3 temperature signals
over alarm value.
The trip signal is made by 2 out of 3 logic circuit in turbine protection
system.
 S1M____-BDB2501d-23

Alarm : ANN setting curve

Trip : TRIP setting curve

9.2.5 HP Exhaust Steam Temperature High

Turbine shall be tripped in order to prevent the overheating of blade by

ventilation.
The alarm will be issued when mean value of triple sensor over alarm
value.
The trip signal is made by 2 out of 3 logic circuit in turbine protection
system.

Alarm : 500 deg.C

Trip : 550 deg.C

9.2.6 LP Exhaust Steam Temperature High

Turbine shall be tripped in order to prevent the deformation of

low-pressure turbine casing.
The alarm will be issued when mean value of triple sensor over alarm
value.
The trip signal is made by 2 out of 3 logic circuit in turbine protection
system.

Alarm : 90 deg.C
Trip : 110 deg.C

9.2.7 Exhaust Steam Pressure High

Turbine shall be tripped automatically when a predetermined low

condenser vacuum is reached.
The alarm will be issued when mean value of triple sensor over alarm
value.
The trip signal is made by 2 out of 3 logic circuit in turbine protection
system.

Alarm : 0.2 bara

Trip : 0.3 bara

9.2.8 Lube Oil Supply Pressure Low

The alarm will be issued when monitoring signal of lube oil pressure fall
less than alarm value.
The trip signal is made by 2 out of 3 logic circuit in turbine protection
system.
 S1M____-BDB2501d-24

Alarm : 1.5 barg

Trip : 1.4 barg

9.2.9 Boiler Trip (MFT)

In the event of boiler trip, turbine shall be tripped in order to prevent the
damage of turbine body by wet steam getting into the turbine.

9.2.10 Generator Trip

In the event of internal fault of generator, generator will be

automatically cut-off from power system (generator trip), and turbine
will be tripped in order to prevent the expansion of fault.

9.2.11 EHG Heavy Fault

In the event of EHG controller heavy fault such as cut of control power,
controller fault and loss of turbine speed signal, the speed control is
impossible and then safe operation is impossible, so turbine shall be
tripped.

9.2.12 Manual Trip (Turbine trip PB ON)

Turbine shall be tripped by manual operation of turbine emergency

stop button installed in the control desk in main control room and
machine side of turbine (local).

9.2.13 Power System Frequency Low

In the event of system frequency decrease, turbine shall be tripped in

order to prevent the resonance of low-pressure long large blade.
There is no limitation to operate steam turbine within frequency range
of 47.5 Hz to 51.5Hz.
Trip signal is made by generator protection relay.
Setting value is as follows

110kV CB OPEN : 48.0Hz

Turbine trip, GCB OPEN : 47.5 Hz

9.2.14 Reverse Power

In the event of reverse power of generator because of turbine trip,

generator will be automatically cut-off from power system (generator
trip) in order to prevent the rotation of turbine because of motoring.
This trip circuit is constructed in generator protection relay.
 S1M____-BDB2501d-25

10.0 GENERATOR PROTECTION SYSTEM

Reference Document ;

Generator Protection Logic Diagram S1MAY__-BFF2505 (WA46340)

10.1 System Description

The main areas of application of the REG216 system are the protection
of generator.
The REG216 belongs to the generation of fully digital generator
protection devices, i.e. analogue to digital conversion of the input
variables takes place immediately after the input transformers and all
further processing of the digital signals is performed by
microprocessors and controlled by programs. Provision is thus made
for the exchange of data such as reaction less reporting of binary
states, events, measurements and protection parameters or the
activation of a different set of settings by higher level control systems.
The availability of a device, i.e. the ratio between its mean operating
time without failure and its total life, is most certainly its most important
characteristic. As a consequence of the continuous supervision of its
functions, this quotient in the case of REG216 is typically always close
to 1.
The menu-based HMI (human machine inter-face) makes the tasks of
connection, configuration and setting simplicity itself. A maximum of
flexibility, i.e. the ability to adapt the protection for application in a
particular power system or to coordinate with, or replace units in an
existing protection scheme, is provided in REG216 by ancillary
software functions and the assignment of input and output signals via
the HMI.
REG216’s reliability, selectivity and stability are backed by decades of
experience in the protection of transmission and distribution systems.
Digital processing ensures consistent accuracy and sensibility
throughout its operational life.

The function of Generator Protection

(1) Protection function
(2) Measuring
(3) Ancillary functions
(4) Plausibility check
(5) Sequence of event recorder
(6) Disturbance recorder
(7) Self-diagnosis and supervision

These functions can be activated within the scope of the CPU capacity.
One or the other function may be applied in accordance with the PT
connections (e.g. three phase for minimum impedance or single phase
 S1M____-BDB2501d-26

for rotor and stator earth fault protection).

10.2 Function

10.2.1 Protection function

Voltage-controlled over current protection (51V)

Pole slip (78)
Over voltage (59)
Under voltage (27)
Over Frequency (81H)
Under Frequency (81L-1,81L-2)
Generator differential (87G)
Reverse power (32)
Gen. Impedance (21)
Loss of excitation (40)
Busbar earth fault (64B)
Over excitation (Volt/Hz Saturation) (24)
Load Unbalance (46)
Gen. Stator earth fault (64S)
Gen. CB breaker failure (50BF)
Gen. Overload (49)
Rotor ground fault (64R)
Voltage balance (60FL)

10.2.2 Measuring

The measuring function measures the single-phase rms values of

voltage, current, frequency, real power and apparent power for display
on the local HMI.
The measurement of the three-phase real and apparent powers is
performed by the power function.

10.2.3 Ancillary functions

Ancillary functions such as logic and a delay/integrator enable the user

to create logical combinations of signals and pick-up and reset delays.

10.2.4 Plausibility check

The current and voltage plausibility functions facilitate the detection of

system asymmetries, e.g. in the secondary circuits of c.t’s and v.t ’s.

10.2.5 Sequence of events recorder

The event recorder function provides capacity for up to 256 binary

signals including time marker with a resolution in the order of
milli-seconds.
 S1M____-BDB2501d-27

10.2.6 Disturbance recorder

The disturbance recorder monitors up to 12 analogue inputs

(CT’s/VT’s), up to 16 binary inputs and up to 12 analogue channels of
internal measurement values. 12 samples per period (sampling
frequency 600 or 720 Hz at rated frequency of 50/60 Hz.
Available recording time for 9 CT/VT and 8 binary signals
approximately 5 s. Recording initiated by any binary signal, e.g. the
general trip signal.

10.2.7 Self-diagnosis and supervision

REG216 self-diagnosis and supervision functions ensure maximum

availability not only of the protection device itself, but also of the power
system it is protecting. Hardware failures are immediately signaled by
an alarm contact. In particular, the external and internal auxiliary
supplies are continuously supervised. The correct function and
tolerance of the A/D converter are tested by cyclically converting two
reference voltages.
Special algorithms regularly check the processor’s memories
(background functions). A watchdog supervises the execution of the
programs.
An important advantage of the extensive self-diagnosis and supervision
functions is that periodic routine maintenance and testing are no longer
necessary.
 LOUGH REE POWER & WEST OFFALY POWER PEAT FIRED PLANTS

CROSS REFERENCE LIST

for
System Description and Pre-
Pre-Commissioning/Commissioning Item

Lough Ree Power West Offaly Power

System Description L1M___BDB2501 S1M___BDB2501
Site Test Procedure - Mechanical L1M___BEC2501 S1M___BEC2501
Site Test Procedure - Electrical L1MAY___BEC2501 S1MAY___BEC2501
Site Test Procedure - Instrument L1CQ___BEC2501 S1CQ___BEC2501

Fuji Electric Systems Co. Ltd.

MUH-031022 (1/6)
System Description Commissioning Item
1.0 Mechanical :
Turbine System M-14 : Gland steam condenser exhauster operation test
M-21 : HP stop valve & reheat stop valve operation test
M-22 : Adjustment of HP steam control valve and reheat
intercept valve
M-23 : Reheat check valve & Extraction check valve
operation test
M-26 : Turning gear operation test
M-51 : No-load operation test of turbine and generator
M-54 : Partial and rated load operation test
M-57 : Heat run test
Electrical :
See common
Control & Instrument :
10 : Interlock test
11 : Vibration monitoring loop test
12 : Eccentricity monitoring loop test
13 : Zero speed monitoring loop test
14 : Shaft position monitoring loop test
15 : Expansion monitoring loop test
2.0 Mechanical :
Lube Oil System M-1 : Adjustment of oil level of main oil tank
M-3 : Setting of pressure switches
M-4 : Gas charge for Accumulator
M-5 : Main Oil tank vapor extractor operation test
M-6 : Main oil pump operation test
M-7 : Emergency oil pump operation test
M-8 : Jacking oil pump operation test
M-9 : Oil purifier operation test
M-17 : Main oil pump automatic starting test
M-18 : Emergency oil pump automatic starting test
M-20 : Adjustment of bearing oil pressure
M-24 : Change over test of oil line equipment and oil
pump
M-25 : Jack up test

MUH-031022 (2/6)
 Electrical :
See common
Control & Instrument :
See common
3.0 Mechanical :
Control Fluid System M-2 : Adjustment of oil level of control fluid tank
M-3 : Setting of pressure switches
M-4 : Gas charge for Accumulator
M-10 : Control fluid pump operation test
M-11 : Control fluid heating pump operation test
M-12 : Control fluid cooler fan operation test
M-13 : Control fluid circulation pump operation test
M-19 : Control oil pump automatic starting test
M-24 : Change over test of oil line equipment and oil
pump
Electrical :
See common
Control & Instrument :
See common
4.0 Mechanical :
Generator System M-51 : No-load operation test of turbine and generator
M-54 : Partial and rated load operation test
M-57 : Heat run test
Electrical :
6 : Main circuit test
8 : Synchronizing circuit adjustment and test
11 : Measurement of generator insulation
12 : Shaft Voltage measurement
13 : Zero speed monitoring loop test
14 : Shaft position monitoring loop test
15 : Expansion monitoring loop test
Control & Instrument :
11 : Vibration monitoring loop test
5.0 Mechanical :
Condenser System M-16 : Cooling water air evacuation pump operation test
M-61 : Condensate oxygen content test

MUH-031022 (3/6)
 Electrical :
See common
Control & Instrument :
See common
6.0 Mechanical :
LP Feed Water Heater System See common
Electrical :
See common
Control & Instrument :
See common
7.0 Mechanical :
Vacuum Pump System M-15 : Vacuum pump operation test
M-29 : Vacuum up test
M-30 : Vacuum pump automatic starting test
M-60 : Vacuum tightness test
Electrical :
See common
Control & Instrument :
See common
8.0 Mechanical :
Turbine Control system M-27 : ATS simulation test
M-51 : No-load operation test of turbine and generator
M-55 : Load rejection test
M-56 : Valve test during load operation
M-58 : House load operation test
M-59 : Load change test
M-62 : Main steam pressure control test
M-63 : Main steam limit pressure control test
M-64 : Vacuum unloading test
M-65 : Turbine start up test by ATS at cold, warm, hot
mode condition
Electrical :
15 : Turbine & Generator regulating system (TGR)
Control & Instrument :
16 : Control valve operation check
17 : DCS interface test

MUH-031022 (4/6)
9.0 Mechanical :
Turbine Protection System M-28 : Turbine Trip interlock test
M-31 : Low Vacuum trip test
M-52 : Master trip test
M-53 : Over speed trip test
M-56 : Valve test during load operation
Electrical :
10 : Interlock test
Control & Instrument :
10 : Speed monitoring loop test
11 : Vibration monitoring loop test
12 : Eccentricity monitoring loop test
14 : Shaft position monitoring loop test
15 : Expansion monitoring loop test
10.0 Mechanical :
Generator Protection System See common
Electrical :
2 : PT & CT secondary circuit test
4 : Protection relay setting & test
13 : Generator open circuit test
14 : Generator short circuit test
16 : Neutral grounding transformer cubicle test
Control & Instrument :
8 : Temperature monitoring loop test
11 : vibration monitoring loop test
Common Mechanical :
None
Electrical :
1 : Panel installation and cable connection inspection
3 : Calibration of measuring instruments
5 : Measurement of insulation resistance
7 : Motor load operation test
9 : Sequence test
10 : Interlock test

MUH-031022 (5/6)
Control & Instrument :
2 : Visual structure inspection
3 : Power supply check and setup
4 : Calibration of pressure switch
5 : Calibration of level switch
6 : Instrument & instrument circuit test
7 : Pressure monitoring loop test
8 : Temperature monitoring loop test
9 : Level monitoring loop test

MUH-031022 (6/6)