p12 - control, switchgear & grid
TRANSCRIPT
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Electricity
1. Control2. Switchgear3. Grid and off-grid
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1. Control
Controls for a 3 machine 2400kW plant – Sri Lanka
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Introduction
C t l ll th f d di t bl t tControl allows the safe and predictable start, run-up, synchronising and loading, unloading, disconnection and shut-down of turbine-generator installations.
Instrumentation monitors and displays the electrical, hydraulic and mechanical conditions, also raising alarms in the event of abnormal operation
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in the event of abnormal operation.
Protection monitors the electrical conditions to trip and shut down the plant in the event of a fault – either in the plant or the network.
Mechanical control
Mechanical control systems act on the water supplyMechanical control systems act on the water supply• initially and finally on the Main Inlet Valve Fully Open/Fully closed
to synchronise and unload at start/stop:• Jet deflectors on Pelton and Turgo-impulse turbines• Guide vanes on Francis turbinesOpen/Close – all continuously adjustable
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to control flow or load in operation • Spear valves on Peltons and Turgos• Guide vanes on Francis turbinesOpen/Close – all continuously adjustable
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Mechanical control
Runner
Main Inlet Valve Spear Valve(s)
Mechanical control
Governor
Main Inlet Valve
Runner
Jet Deflector(s)
Spear Valve(s)
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Mechanical control
M i I l t V lMain Inlet Valve
Guide Vanes
Mechanical control
Main Inlet Valve
Guide Vanes
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Mechanical control
Moveable Runner Blades
Guide Vanes
Electrical control:
Electrical control systems act on the electricity supply, • to synchronise and disconnect at the Main Circuit
Breaker Open/Close
• Continuously on flow control
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• Continuously on flow control –Spear valves on Pelton and TurgoGuide vanes on Francis turbinesIncrease/Decrease – continuously adjustable
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Governing
For speed / load control of the water turbine in isolated (island) mode
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Governing
Used for synchronising and Operating isolated from a t k ( id)network (grid)
If load (kW) is added to generator, shaft speed falls, and governing system opens guide vanes or spear valves to increase speed.
This increases power output to balance mechanical load on
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This increases power output to balance mechanical load on turbine and speed is restored.
A control loop dampens the response.
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Governor Operation
Water admission controlled by guide vanes or jet deflector
Speed is measured by shaft encoder
Speed sensor
Nmeas
NrefΣ Amp
Nref-Nmeas
Governor or ECS
Governor opens and lSpeed is measured by shaft encoder
and compared with an (adustable) reference speed setting in the governor or
electronic control system.Used for synchronising and
Operating isolated from a network (grid)
Rotor coupling to generator shaf
Water inlet Power in
Main Inlet Valve TurbinePower out
closes guide vanes
(grid)
Note: For small schemes, a head level controller and plc controls are now more commonly used
AVR Operation
Rotor excitation controlled by output of solid state AVR amplified and fed as dc to main rotor winding
Operating isolated from the network
fed as dc to main rotor winding
Generator stator voltage is measured by a VT and compared with an (adustable) reference
voltage setting in the AVR.
For synchronising p gIf electrical load is added to
generator, terminal voltage falls, and AVR increases excitation to increase voltage and minimise error in control loop.
y g
If measured speed V1 is lower than reference voltage Vref error signal (Vref – V1) is amplified and used to increase main excitation a little, but quite precisely
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Mechanical and electrical aspects of startup
Design is generally site specific, but general principles for start logic are:• Test all trips are reset, no alarms are raised, all control voltages are available• Test for full head behind MIV• Open MIV fully and prove• Part-open spear valve or guide vanes and prove• Turbine accelerates and passes half speed driving governor• Governing system takes control of speed (on guide vanes or jet deflector)
towards unloaded setting• Generator excitation builds up and generator excites• AVR takes control of speed towards no load voltage• Autosynchroniser takes control of reference speed and senses generated
frequency and voltage• Speed of rotation and generated frequency are controlled by the admission of
water to the runner – under speed governor action in closed loop towards a preset speed.
• Open circuit voltage is controlled by the excitation of the generator rotor under Automatic Voltage Regulator (AVR) action in closed loop, towards a preset voltage.
• All operations are checked within time-outs, and aborted to shut-down if they fail
SynchronisingCircuit breaker open.
Network ‘running’ at Vgrid and fgrid
Generator speed and voltage is
Vgrid f grid
Generator speed and voltage is
increased until Vgen = Vgrid
and fgen = fgrid.
Synchroscope
compares phase
of Vgen and Vgrid.
Synchroscope look for stationary at 12.00
f genVgen
Turbine
Circuit Breaker
Stator
Sh f
Generator
gen grid
CB is closed when scope is Vary speed set point until fgen = fgrid
Rotor
Shaft
AVR
Governing System
Power control
Vary voltage set point until Vgen = Vgrid
Nref
Vref
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Autosynchronising
Manual synchronising is normally only for backup,
Usual for start, run-up, and synchronising to be automated.
• Turbine controlled and protected by PLC or relay logic
• Set points on governing system and AVR are motorised
• Auto-synchroniser responds to freq, phase and voltage difference to match ‘running’ and generator supplies.
When conditions are correctWhen conditions are correct
• Check-synchroniser verifies this and allows through a ‘CLOSE’ instruction to main Circuit Breaker, and breaker closes.
• Any neutral earthing contactor on generator is opened at this point
• Once closed increase reference speed setting to pick up active power and load and initiate any other control such as head level or load-share.
Electrical aspects of operation
After connection to the network
Speed of rotation and generated frequency are dictated (precisely) by the synchronous connection and governing system is set to maximum power (or load limit) by increasing the reference speed Nref above synchronous.
Generator voltage is dictated (precisely) by the synchronousGenerator voltage is dictated (precisely) by the synchronous connection and the Automatic Voltage Regulator (AVR) can only control generated power factor.
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Head level control
Where storage is small relative to design flow, and can runoff into storage can vary quickly head level control can adjust discharge to keep free surface level nearly constant in headpond.
Radio transmitter
Ultrasonic level detector
DC supply
Reducing water level closes spear, increasing water level opens spear
Radio receiver
PID controller
Motorised spear valve
increasing water level opens spear.Needs aux supplies at intake
Means that turbine output follows inflow
Instrumentation (typical)
Electrical Mechanical Alarms
Bus voltage Inlet pressure DC failure
Bus frequency Shaft speed Overspeed
Gen voltage Bearing temp Overtemp
Gen frequency Stator temp Overtemp
Phase current Hours run Vibration
Power Head level Start fail
Power factor Valve status Stop fail
EnergyEnergy
Main CB status
NE breaker st.
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Mech & elec aspects of shutdownDesign is again generally site specific, but general principles for planned
stop logic are:
• Initiate stop, this drives down the reference speed setting on the governing systemgoverning system
• As this passes synchronous speed, governor senses speed high
• Error signal acts to correct this by inserting jet deflector, or closing guide vanes
• Water supply to turbine runner is reduced slowly to zero
• Depending on turbine type either generator starts to motor and Reverse Power protection trips main circuit breaker, or
• When spear valve/guide vanes are closed logic trips main circuit breaker
• Generator runs down, excitation collapses and generator de-excites
• Spear valve (turgo and Pelton) and main valve are closed in sequence
• All operations are checked within time-outs, and aborted to shut-down if they fail.
Emergency ShutdownDesign is again generally site specific, but general principles for
emergency stop logic following a protection trip are:• Protection trips main circuit breaker• Load has been removed and water supply is still on, so speed takes offpp y , p• As this passes reference speed setting, governing system senses speed
high• Error signal acts to correct this by inserting jet deflector quickly or closing
guide vanes slowly • Generator runs down, excitation collapses and generator de-excites• Spear valve (impulse turbines) and main valve are closed slowly in
sequence• Guide vanes (Reaction turbines) and main valve are closed slowly in
sequence• Water supply from pipeline is reduced slowly to zero to avoid pressure
rise – could take several minutes.• With Francis turbine this inevitably means a period of time when there is
no mechanical power take off, and the runner is still being driven. Flywheels are necessary to limit speed rise while avoiding pressure rise.
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2. Switchgear
They accommodate all current and voltage
Network circuit breakers are 3 phase switches, with mechanically operated contacts that open and close. The breakers can be fixed or withdrawable.
current and voltage transformers and protection relays
Operators and auto sync may open or close them locally or from remote positions.
Local or remoteLocal or remote protection equipment may open them.
They must open and close very quickly under normal and abnormal conditions.
Requirements and Obligations
It is a legal and professional requirement that all distributed generators are designed, manufactured and installed to operate in an inherently safeand installed to operate in an inherently safe manner, under normal, abnormal & fault conditions.
Statutory obligations– Health & Safety at Work Act 1974– Electricity Act 1989y– Electricity Supply Regulations 1988
Under these Regulations no person may operate generating plant in parallel with a Distribution Network Operator’s (DNO's) system without their written agreement and the plant must meet minimum standards of operation, protection and disconnection in the event of a distribution network or plant failure.
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Requirements and Obligations
Written agreement of DNO will require demonstrableWritten agreement of DNO will require demonstrable compliance with
• Local or International standards for equipment and installation practice
• Connection and operating standards, such as
Engineering Recommendation G59/1, G75 & ETR113• Prevents connection to faulty network
• Prevents displacement of V or frequency outside statutory limitsPrevents displacement of V or frequency outside statutory limits
• Prevents back-energising of network
• Neutral earthing compliance
• Electrical and mechanical protection
General Protection Considerations
Switchgear of new DG must have a prescribed minimumsystem of protection relays that will disconnect they p ygenerator from network if
a fault develops on either side of the generator circuit breaker;
the system voltage or frequency goes out of agreed limits within thestatutory maxima and minima;
the network becomes disconnected at a remote point.
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System voltage and frequency limits
General Protection Considerations
y g q y
• V: 10% of 400/230V (253-207) 6% of 11kV
• Frequencies: +1%/-6% of 50Hz (50.5-47)
• Time for operation: 0.5secs (> by agreement)transient network disturbances such as auto reclosure of– transient network disturbances such as auto-reclosure of network circuit breakers and motor starting
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11kV lines:3-phase & single phasesingle phase
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11kV lines:3-phase & single phase
- dropping to LV
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Switchrooms and Metering Pointsg
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Connection layouts
• Generator connected directly to heat load. Off-grid
B ttR tifi D C l d
a.c.
Batteryd.c.
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Rectifier
a.c.
D.C. loadd.c.
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Connection layouts
Batteryd.c.
Rectifier Inverterd.c.
A.C. load
a.c.a.c.
• Current rectified then reinverted
• Still off-grid
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Connection layouts
d.c.Rectifier Inverter
a.c.
HouseProtection
a.c. Generation meter
• Current rectified then reinverted
• Relays in case of fault
• Export or use onsite
• Rectified, inverter & protectionmay be supplied as one unit
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Grid
Import meter