The document discusses steam turbine control and instrumentation. It describes various types of steam turbines including conventional cycle, combined cycle, and nuclear turbines ranging from 210MW to 800MW. It then discusses the aims of automation in steam turbines, including improved control quality, increased plant availability and efficiency. The document outlines the main subsystems of steam turbine control including control systems, monitoring and measurement systems, and protection systems. It provides details on an Automatic Turbine Run-Up System (ATRS) which automatically controls the start-up process. The ATRS utilizes functional group control philosophy and consists of sub-group controls, sub-loop controls, and drive interface controls. It also describes the turbine protection system and various tripping criteria to

1. STEAM TURBINE
CONTROL
&
INSTRUMENTATION

2. STEAM TURBINE TYPE
Conventional Cycle
• 210MW
• 250MW
• 300/350MW
• 500/600MW
Combined Cycle
• MN Series (Dual Pressure)
• HMN Series (Triple Pressure)
Nuclear Turbine
• 500MW
High Pressure Turbine
• 250/270MW
• 660/800 MW (Super Critical)

3. AIMS OF AUTOMATION
• Improvement in quality of control
• Increase in plant availability
• Increase in plant safety
• Increase in Plant efficiency
• Faster start-up and load change
• Easy handling of the plant
• Avoidance of maloperation

4. MEASUREMENT
CLOSE-LOOP
CONTROL
OPEN-LOOP
CONTROL
PROTECTION
MONITORING
INSTRUMENTATION
AND
CONTROL

5. Thermal Cycle in a Power Plant

6. ST SUBSYSTEMS
A. CONTROL SYSTEM:
ANALOG (CLOSED LOOP)
- ELECTROHYDRAULIC CONTROLLER (EHC)
- LOW PRESSURE BYPASS CONTROLLER (LPBPC)
- GLAND STEAM PRESSURE CONTROLLER (GSPC)
- LUBE OIL/ WARM-UP TEMPERATURE
CONTROLLERS
BINARY (OPEN LOOP)
- AUTOMATIC TURBINE RUN UP SYSTEM (ATRS)
- AUTOMATIC TURBINE TESTER (ATT)

7. ST - SUBSYSTEMS
B. MONITORING & MEASUREMENT SYSTEM
- TURBINE SUPERVISORY INSTRUMENTATION (TSI)
- TURBINE STRESS EVALUATOR/CONTROLLER (TSE/TSC)
- MEASURMENT OF PARAMETERS LIKE, TEMPERATURE,
PRESSURE , LEVEL etc.
C. PROTECTION SYSTEM
- TURBINE PROTECTION SYSTEM
- BYPASS PROTECTION SYSTEM

8. A T R S
AUTOMATIC TURBINE RUNUP SYSTEM

9. AUTOMATIC TURBINE RUN-UP SYSTEM
INTRODUCTION:
• The task of the automatic startup control "SGC Turbine” is to
implement transition of the steam turbine-generator from turning
gear operation to power operation.
• A successful start-up of the TG-set normally requires acquisition,
analysis and collation of a wide variety of information pertaining
to various parameters like Press, Temp., Vacuum., Speed etc.
• Difficult task for the operator to handle and collate so many bits
of information swiftly & correctly along with status of auxiliary
equipments
• A Microprocessor based ATRS performs this task accurately and
at an appropriate time

10. AUTOMATIC TURBINE RUN-UP SYSTEM
CONCEPT:
• A programmable Automatic Turbine Run-up
System (ATRS) is based on the “Functional
Group Control” philosophy
• The control area is divided into clearly defined
functional areas called “Functional Groups”
• Each Functional Group is organised & arranged
in SGC, SLC and Drive Interface Function

11. CONCEPT OF C&I IN THERMAL POWER STATION
UNIT CONTROL
CLOSED
LOOP
CONTROL
FUNCTIONAL
GROUP
CONTROL
PROT-
IVE
LOGICS
DATA PROCESS-
ING, ALARM
ANNUNCIATION
SIGNAL
CONDITIONING
ALALOG, BINARY
CONTROL INTERFACE
MOTOR CONTROL CENTRE
SWITCH GEAR
M M DRIVES
SIGNAL TRANSMITTER
ANALOG AND
BINARY
SIGNALS
DISPLAY UNIT
LOGS
CONTROL
ROOM
PLANT (FIELD)
OPERATOR

12. AUTOMATIC TURBINE RUN-UP SYSTEM
TASKS PERFORMED:
• SWIFT,ACCURATE AND OPTIMUM STARTUP ( INCLUDING
SYNCHRONISATION AND LOADINING) OF TURBINE
• MAINTAINING OIL SUPPLY
• BUILDING UP AND MAINTENANCE OF VACUUM
FEATURES :
• BASED ON FUNCTIONAL GROUP CONTROL PHILOSOPHY,
EACH FUNCTIONAL ‘SUB-GROUP CONTROL’, ‘SUB-LOOP
CONTROL’, AND ‘CONTROL INTERFACE’ OPERATION
ALONG WITH STATUS DISPLAYS IN OWS
• OPERATING MODES AVAILABLE:
- MANUAL MODE ( OPERATOR GUIDE)
- AUTOMATIC MODE
- STEP BY STEP MODE

13. HIERARCHY OF CONTROL
UNIT
CONTROL
GROUP CONTROL
(WHEN, HOW MANY,WHICH)
SUB-GROUP CONTRL-1 SUB-GROUP CONTRL-2
CONTROL INTERFACE
SWITCH GEAR (MCC)
SLC ( SUB LOOP CONTROL)

14. ADVANTAGES OF ATRS
• ELIMINATES HUMAN ERROR
• PROVIDES MAXIMUM PROTECTION AGAINST
MALFUNCTIONS
• LESS DIFFICULT OPERATOR TASK
• ENABLES SAFE, SMOOTH, STRESS CONSISTANT AND
OPTIMUM WARM-UP, ROLLING AND SYNCHRONISATION
OF TURBINE IN LEAST POSSIBLE TIME
• INCREASES PLANT AVAILABILITY
• REDUCES STARTING TIME WITHOUT IMPAIRING LIFE
• MEETS EMERGENCIES AUTOMATICALLY
• ALL PLANT OPERATING CONDITIONS CATERED TO BY
CRITERIA DEPENDANT PROGRAMMING
• INCREASED OPERATING FLEXIBILITY, SAFETY AND
RELIABILITY

15. AUTOMATIC TURBINE RUN-UP SYSTEM
SUB GROUP CONTROL ( SGC):
• SGC executes commands to bring the equipment upto a particular
defined status.
• The commands are executed in a predefined sequence in the form of
steps.
• Desired number of criteria act as preconditions before the SGC can
take off or execute its defined sequence.
• The functional group continues to function automatically all the time
demanding enabling criteria based on the process requirements and
from other FGs, if required.
• In case the desired criteria is not available, the system would
automatically act in such a manner as to ensure the safety of the main
equipment.
• The sequence is programmed in the processor. The process signals
are acquired through the input modules and are available on the bus.

16. AUTOMATIC TURBINE RUN-UP SYSTEM
WAITING AND MONITORING TIME FOR STEPS:
Waiting Time :
It implies that the subsequent step will not be executed
unless the specified time elapses. If no waiting time is
specified, the next step gets executed as soon as the
enabling criteria are fulfilled.
Monitoring Time :
It is the time required for executing the command of any
step as well as the time required for appearance of
criteria for the next step. Under healthy conditions it
should happen within the specified time, otherwise an
alarm is initiated. Whenever there is uncertainty
regarding the time required for completing a particular
task, such as warming-up, pulling vacuum etc., the
monitoring time is blocked.

17. AUTOMATIC TURBINE RUN-UP SYSTEM
• ATRS can be switched on at any stage after completing
certain tasks manually, if so desired.
• In such cases, the SGC program quickly scans through
the steps and starts executing from the stage upto which
the tasks have been completed manually.
• This is achieved by incorporating suitable overflow /
bypass conditions in the logic.

18. PROGRAM STEP OF A SUBGROUP CONTROL
02
FROM STEP 1
STEP CRITERIA FOR STEP -2
BYPASS CRITERION
PROGRAM LOOP
WAIT
50s
MO TIME
20s
COMMAND
1
2
&
&
1
&
• STEP 2 ( START UP PROGRAM) WITH 2 STEP CRITERIA, 2 COMMAND
OUTPUTS AND A MONITORING & WAITING TIME .
• WITH ADDITIONAL PROGRAM LOOP CONTROL AND A BYPASS
CRITERIA FOR STEP 1
• WAITING OR MO TIME CAN BE PROGRAMMED FOR 0.1 SEC TO 999
MIN.
• NOS. 1-49 USED FOR START-UP, 51 TO 99 FOR SHUTDOWN PROGRAM.
EXAMPLE

19. EXPLANATION OF KWU IDENTIFICATION SYSTEM (KKS)
0 1 2 3
A NAAANN AANNN AANN
A 1MAV22 AP001 XB01
ORDINAL SECTION
GENERAL
EXAMPLE
SIGNAL IDENTIFICATION
CONSECUTIVE NO. OF EQUIPMENT
TYPE OF EQUIPMENT
NO. OF SUBGROUP
PLANT GROUP (FUNCTIONAL GROUP)
NO. OF UNIT

20. AUTOMATIC TURBINE RUN-UP SYSTEM
• ATRS CONTROLS:
1. ATRS is organized in the following three Sub-Groups :
• Oil supply system
• Evacuation system
• Turbine system
2. SGC issues commands either to the SLC or directly to
the drive through the Control Interface.
3. Each of these SGCs has its subordinate SLCs and
Drive Control Macros. These SGCs in conjunction with
the turbine governing system , TSE and the auto-
synchronizer accomplish the function of start-up of the
TG set.

21. AUTOMATIC TURBINE RUN-UP SYSTEM
SUB-LOOP CONTROL (SLC) :
• A SLC, when switched on, actuates the equipment and brings
it to the desired status as demanded by the process and there
is no sequence logic involved in it.
• SLC is like a watch-dog performing an assigned duty.
• All mechanical equipment which need to be switched on/off
based on process consideration are hooked-up in various
SLCs. Standby equipment is also interlocked in SLCs.
• SLC can be switched on either manually or through SGC and
issues commands to the drive control level.
• SLC logic is also realised in the processor module.

22. AUTOMATIC TURBINE RUN-UP SYSTEM
( DRIVE CONTROL INTERFACE )
DRIVE CONTROL MACROs : ( Software realization)
Basically three types of Drive Control Macros:-
1 a) LTUDPB (for Unidirectional LT drives with Pushbutton
Interface)
b) LTUD (for Unidirectional LT drives without Pushbutton
Interface)
2 a) BDPB (for Bidirectional drives with Pushbutton Interface)
b) BD (for Bidirectional drives without Pushbutton Interface)
3 a) SOVPB (for solenoid drives with Pushbutton Interface)
b) SOV (for solenoid drives without Pushbutton Interface

23. AUTOMATIC TURBINE RUN-UP SYSTEM
( DRIVE CONTROL INTERFACE )
DRIVE CONTROL MACROs : (Software realization)
The drive control macro functions (‘custom blocks’ in maxDNA terminology)
LTUDPB & LTUD are used to control unidirectional drives such as pumps,
fans, motors etc., Bi-directional drives (BDPB/BD) such as Valves, Dampers
etc& Solenoid valves.
The Pushbutton commands & LED indications exclusively for LTUDPB /
BDPB/SOVPB are for interfacing with control desk and not available in
respective functional blocks without PBs.
Drive commands can be issued from:
- Pushbutton panel in the control desk
(only for LTUDPB/BDPB/SOVPB)
- HMI operator station
- Automatic higher level system
- Protection signals.

24. AUTOMATIC TURBINE RUN-UP SYSTEM
( DRIVE CONTROL INTERFACE )
DRIVE CONTROL MACROs : (Software realization)
• Pushbutton commands ON/OFF (OPEN/CLOSE) are effective
only when pressed alongwith “Pushbutton” release.
• “Pushbutton” commands and auto commands are processed
alongwith the respective release logic input signals.
• Protection command inputs do not need any release input.
• No separate manual release required for HMI commands.

25. AUTOMATIC TURBINE RUN-UP SYSTEM
( DRIVE CONTROL INTERFACE )
DRIVE CONTROL MACROs : (Software realization)
( For SOV / unidirectional / bi-directional drives)

26. AUTOMATIC TURBINE RUN-UP SYSTEM
DRIVE ICON :
( For Bi-directional drives)
DRIVE ICON :
( For Uni-directional drives)
INDICATION ON HMI
DRIVE ICON :
( For Solenoid Valves)

27. AUTOMATIC TURBINE RUN-UP SYSTEM
ATRS STRUCTURAL SYSTEM:
1. SGC-TURBINE SYSTEM :
SGC Turbine acts directly on the following systems :
• Sub-loop Control (SLC) Drains.
• Warm up Controller.
• Turbine controller.
• Turbine startup & lift limiter

28. AUTOMATIC TURBINE RUN-UP SYSTEM
2. SGC-OIL SUPPLY SYSTEM :
SGC oil supply directly acts on the following system :
• Sub-loop control (SLC) turning gear.
• SLC auxiliary oil pump 1.
• SLC auxiliary oil pump 2.
• SLC emergency oil pump.
• SLC jacking oil pumps.
• SLC exhausters.

29. AUTOMATIC TURBINE RUN-UP SYSTEM
3. SGC EVACUATION SYSTEM :
SGC Evacuation directly acts on the following systems :
• SLC Vacuum pumps
• Drive of Vacuum pumps

30. SGC-DISPLAY
4 6 8 7 5
1
3
2
1. CONTROL BUTTON “SHUTDOWN”
2. CONTROL BUTTON “STARTUP” OR “OPERATION”
3. CONTROL BUTTON “AUTOMATIC ON/OFF”
4. LAMP “SHUTDOWN PROGRAM”
5. LAMP “STARTUP” OR “OPERATION” PROGRAM
6. LAMP “AUTOMATIC OFF”
7. LAMP “ AUTOMATIC ON”
8. LAMP “FAULT”

31. SLC-DISPLAY
2 3 4
1. CONTROL BUTTON “MANUAL ON/OFF”
2 .LAMP “SLC OFF”
3. LAMP “ FAULT”
4. LAMP “SLC ON”
1

32. DRIVE INTERFACE-DISPLAY
3 4 5
1. CONTROL BUTTON “OFF” (CLOSE)
2. CONTROL BUTTON “ON” (OPEN)
3. LAMP “ OFF” (CLOSE)
4. LAMP “FAULT”
5. LAMP “ON” (OPEN)
1 2

33. PROTECTION SYSTEM
FOR
STEAM TURBINE

34. TURBINE PROTECTION SYSTEM
TASK PERFORMED :
PROTECTS TURBOSET FROM INADMISSIBLE
OPERATING CONDITIONS
PREVENTS DAMAGE IN CASE OF PLANT FAILURE
FAILURE OCCURRENCE REDUCED TO MINIMUM

35. TURBINE PROTECTION SYSTEM
ADVANTAGES :
DETECTION OF UNIT IRREGULARITIES
PREVENTION OF UNIT OVERSTRESSING DUE TO
TRIPS
RELIEF OF OPERATING PERSONNEL FROM QUICK
AND CORRECT DECISION TAKING

36. TURBINE PROTECTION SYSTEM
GENERAL :
• The electrical trip system comprises of two identical and
independent relay based trip channels viz. electrical trip
channels 1 & 2.
• Both channels are connected to different (two) trip solenoid
valves.
• All command signals for turbine trip are hooked up with both the
channels.
• Actuation of any of the channels energises the respective trip
solenoid which in turn trips the turbine.
• Each channel is realized in a local bus. Both the local buses are
completely independent of each other and input modules,
processor module and output modules reside on each.

37. TURBINE PROTECTION SYSTEM
• Trip signals from the sensors / field instruments are conditioned
and distributed to both the channels (local buses) via hardwired
modules.
• Realisation of 2 out of 3 trip logic is carried out in the local bus.
On detection of a fault in any one of the input signals to a
channel, the configuration for that channel changes from 2 out of
3 to 1 out of 2 and is annunciated. Further failure in a channel
changes the configuration to 1 out of 1.
• Trip signal from each of the local buses acts on 3 relays in 2 out
of 3 combination.

38. TURBINE PROTECTION SYSTEM
TRIPPING CRITERIA :
1. CONDENSER VACUUM VERY LOW :
• This is a back up protection to the hydraulic low vacuum trip
device.
• The protection acts if absolute pressure in the condenser rises
above 0.3 Kg/cm2 (abs).
2. LUBE OIL PRESSURE LOW :
• The protection acts if the lube oil pressure before thrust bearing
decreases to 1.2Kg/cm2 .
• The trip signal is initiated by three pressure switches in 2-out-of-3-
logic.

39. TURBINE PROTECTION SYSTEM
3. FIRE PROTECTION :
• The protection acts in the event of any of the following
conditions :
i) Fire protection switch, either in unit control room or in
machine hall, operated.
ii) Level in main oil tank falls to a very low value, indicating
substantial leakage of oil from the system.
The command signal under condition (ii) is initiated from
three level transmitters in 2-out-of-3 logic.

40. TURBINE PROTECTION SYSTEM
4. HP EXHAUST STEAM TEMPERATURE HIGH :
• The HP exhaust steam temperature protection circuit causes the
exhaust sections of the turbine, the blading and the extraction points
against overheating.
• Under extreme operating conditions the HP turbine can be run at low
flow rate and simultaneous relatively high back pressure. This prevents
the steam from expanding, which causes the exhaust steam
temperature to rise ( >5000C).
• The temperature is measured by means of three thermocouples and
protection criteria is derived in 2 out of 3 logic.

41. TURBINE PROTECTION SYSTEM
5. TURBINE TRIP SWITCH OPERATED :
• The protection acts when the turbine trip switch in unit control
room is operated manually.
6. TRIP COMMAND INITIATED FROM ATRS :
• The protection acts when the trip command signal is initiated
from the Automatic Turbine Run-up System .

42. TURBINE PROTECTION SYSTEM
7. GEN. PROTECTION OR MFT- RELAY ENERGISED :
• In the event of generator faults under Class-B trip both the turbine
trip channels are actuated to trip the turbine. In such a case the
generator protection acts through Reverse Power Relays.
• In the event of generator faults under Class-A trip or in the event of
boiler "Master fuel trip relay" energised, command signal for
turbine trip shall act simultaneously and independent of other
equipment trip out sequence.
8. OPERATION OF REVERSE POWER RELAY :
• The command signal is initiated with a time delay of 10 seconds after
any of the two reverse power relays have operated.