turbine governor frequency coordination
TRANSCRIPT
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Turbine Governor Frequency Coordination
Frequency coordination keeps the unit load demand to the boiler in line with any actions takenby the turbine speed governor. During a frequency upset on the power grid, the turbine speed
governor provides direct and prompt proportional control action on the turbine to correct the
frequency upset. Frequency coordination indexes the unit load demand to match the loadconditions being required by turbine speed governor to prevent incorrect interactions between the
boiler control system and the turbine speed governor while a frequency error exists.
The frequency correction logic is proportional only control with a deadband which must have the
same proportional gain and deadband settings (droop) as the turbine speed governor. A typical
curve is shown in Figure ULD-2. When either the boiler or turbine is on manual control or a unit
runback is in progress, unit load demand frequency coordination must be disabled.
Governor Droop - the decrease in frequency to which a governor responds by causing a
generator to go from no load to full load. This definition of governor response is more precisely
defined as "speed regulation," which is expressed as a percentage of normal system frequency.For instance, if frequency decays from 60 to 57 hertz, a 5% change, a hydro generator at zero
load with a governor set at a 5% droop would respond by going to full load. For smaller changes
in frequency, changes in generator output are proportional. The more technically correctdefinition of governor droop is the change in frequency to which a governor responds by causing
the turbine gate position to move through its full range of travel, which is generally non-linear
and a function of load.
Governor Dead Band - A range of control signal input to the governor in which there is neitheran increase nor decrease in the governor output.
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NERC Operating Manual
1. Governor installation. Generating units with nameplate ratings of 10 MW or greater should beequipped with governors operational for frequency response unless restricted by regulatory
mandates
2. Governors free to respond. Turbine governors and HVDC controls, where applicable, should be
allowed to respond to system frequency deviation, unless there is a temporary operating problem.
3. Governor droop. All turbine generators equipped with governors should be capable of providing
immediate and sustained response to abnormal frequency excursions. Governors should provide a
5% droop characteristic. Governors should, as a minimum, be fully responsive to frequency deviations
exceeding 0.036 Hz ( 36 mHZ).
4. Governor limits. Turbine control systems that provide adjustable limits to governor valve movement
(valve position limit or equivalent) should not restrict travel more than necessary to coordinate boiler and
turbine response characteristics
Graph showing relation between generator output and Interconnection frequency at 0, 50%, and 100%LOAD for a 5% governor droop characteristic.
5% Governor Droop
57
58
59
60
61
62
63
0 20 40 60 80 100
Percent Outpu
Freque
ncy
-Hz
Full Load
50% Load
No Load