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GEH-6810 OpFlex Enhanced Transient Stability (ETS) for GE Gas Turbines

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GE Energy
OpFlex* Enhanced Transient Stability (ETS)
for GE Gas Turbines
User Guide
GEH-6810
These instructions do not purport to cover all details or variations in equipment, nor to provide for every possible contingency
to be met during installation, operation, and maintenance. The information is supplied for informational purposes only, and
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Issued: 2011-05-06
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GEH-6810
User Guide
5
To prevent personal injury or damage to equipment, follow all
GE safety procedures, LOTO, and site safety procedures as
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OpFlex Enhanced Transient Stability (ETS) for GE Gas Turbines
Contents
Overview ....................................................................................................................................................... 9
Model-based Control (MBC) – Direct Boundary Control .................................................................................. 9
Adaptive Real-time Engine Simulation (ARES) .............................................................................................. 10
Control Mode ........................................................................................................................................... 10
Parameter Boundaries ................................................................................................................................ 11
Enhanced Transient Stability (ETS) .............................................................................................................. 11
Improved Transient (Grid) Response ................................................................................................................... 12
Model-based Coordinated Air-fuel (MBCAF) ................................................................................................. 12
Grid Frequency Filter (GFF) ....................................................................................................................... 12
Flame Anchoring Stability (Transient Split Bias) ............................................................................................. 14
Input Signal Processing (ISP) ............................................................................................................................. 15
Protective Actions ..................................................................................................................................... 16
Sensor Models .......................................................................................................................................... 17
Human-machine Interface (HMI) Screens ............................................................................................................. 18
MBC Sensor Data ..................................................................................................................................... 18
MBC Sensor Data Specific Details................................................................................................................ 19
MBC Sensor Training ................................................................................................................................ 22
MBC Sensor Tuning .................................................................................................................................. 24
Combustor Hardware Selection.................................................................................................................... 25
Cycle Reference Parameters............................................................................................................................... 26
Combustion Reference (CRT) ...................................................................................................................... 26
Turbine Reference (TRT) ............................................................................................................................ 26
Alarms and Unit Response................................................................................................................................. 27
Glossary of Terms ............................................................................................................................................ 36
GEH-6810
User Guide
7
Notes
8
OpFlex Enhanced Transient Stability (ETS) for GE Gas Turbines
Overview
The 2000s witnessed a boom in combined cycle gas turbine power plants. This trend
has been large enough to significantly impact the generating mix in many countries and
fundamentally shift the dynamics of grid operation and dispatch. One outcome of this
is that a combined cycle gas turbine plant is now one of the easiest generation assets to
manipulate. The modern combined cycle power plant is often expected to start and stop
multiple times a week, as well as respond to changing load demands multiple times an
hour.
The goal of Enhanced Transient Stability (ETS) is to increase the robustness of the Dry
Low NOx (DLN)-based gas turbine. GE Energy has re-written the core control software
of the gas turbine using a Model-based Control (MBC) - Direct Boundary Control
approach, referred to as MBC technology. This technology improves our control accuracy
and capability.
Model-based Control (MBC) – Direct Boundary Control
The intent of MBC - Direct Boundary Control is to identify operational parameters (such
as exhaust temperature, firing temperature, and emissions) of the physical system and
create a control loop specific to each parameter to regulate. This ensures that the turbine
as a whole, as well as the individual components, is always operating within the intended
design space. The Direct Boundary Control concept removes the inherent coupling that
comes from legacy control methods, such as exhaust temperature control. Instead, gas
turbine actuators or effectors such as fuel, air (inlet guide vanes [IGV]), inlet bleed heat
(IBH), and fuel splits may be operated independently to provide a more flexible control
solution with greater ability for optimization.
Effector Coupling
The ARES model is based on
the engineering cycle deck.
GEH-6810
In practice, many gas turbine boundaries are often parameters that are not directly
measured or even measurable (such as firing temperature). To overcome this limitation
various boundary models are used. The goal of the models is to estimate the behavior of
the system, based on known physics, to the level of fidelity required for the application.
User Guide
9
Adaptive Real-time Engine Simulation (ARES)
ARES is a high fidelity model of the gas turbine, continuously tuned in real-time to
match the performance of the actual gas turbine. This model is derived from the Gas
Turbine Performance (GTP) Model application and coded to run real-time in the gas
turbine controller. In order to make the steady state cycle model function transiently in
the controller, both a heat soak model and filter were added to supplement the basic cycle
calculations. Together they use the existing gas turbine sensors to tune the ARES model to
match the actual operating conditions of a unit at any given moment.
Refer to GEH-6740,
Model-based Control for
GE Gas Turbines, for further
information on the AutoTune
system.
The ARES model is a key enabler in order to execute the Direct Boundary Control
philosophy. As previously stated, many parameters that make up a component’s design
space are not readily measurable. The ARES model estimates many un-measurable cycle
parameters with a high degree of accuracy that can be used directly in control loops
or as inputs to additional downstream sub-system models. The fidelity of the ARES
model and any additional sub-system models are determined by the precision required
in order to maintain the component in question within its design space. An example of
sub-system models that are enabled by ARES are the DLN transfer functions used for
the OpFlex*AutoTune* product. These DLN models would not be feasible without first
having the ARES model in place.
Control Mode
In the case of a gas turbine, many key parameters are affected by moving a single actuator
or effector. This requires the creation of a priority scheme, or control mode, for each
parameter that an actuator will affect. The typical GE Energy gas turbine continuously
controls approximately 20 parameters within the flange-to-flange turbine. The control of
these parameters must be achieved with only four actuators: total fuel, IGV, IBH, and
DLN fuel splits. The way this problem is overcome is by prioritizing certain control
parameters over others. The control mode is a hierarchy of control loops, with increasing
priority to the right.
Note The following figure is for reference only and does not represent an actual design.
Example Control Mode for the IGV Actuator
Each input to the control mode is an independent control loop that is controlling one
parameter. Whichever loop actively makes it though the control mode gate to determine
the command to the actuator is said to be the loop in control (LIC).
In some cases, multiple actuators can control the same parameter. For example, either
IGVs or total fuel flow could be changed to impact the exhaust temperature. This allows
the parameter to continue to be controlled even when one or more of the actuators are
saturated (unable to respond further).
10
OpFlex Enhanced Transient Stability (ETS) for GE Gas Turbines
Parameter Boundaries
Each loop in the control mode must have a boundary to use as the control loop reference.
These parameter boundaries can be a constant, such as the rotor torque limit, or complex
multi-variable schedules, such as the compressor operating limit line. Typical gas turbine
cycle boundaries include (but are not limited to):
•
Hot gas path durability (firing temperature)
•
Exhaust frame durability (exhaust temperature)
•
Compressor surge
•
Compressor icing
•
Compressor aero-mechanical limits
•
Compressor clearances
•
Compressor discharge temperature
•
Valve pressure ratio
•
DLN boundaries
Enhanced Transient Stability (ETS)
With the fundamental philosophy of Direct Boundary Control and the ARES model in
place, the decision was made to structure the software into two separate areas:
•
Control of the gas turbine cycle – bulk fuel/air control
•
Control of the DLN system – DLN split control
The control structure for the gas turbine cycle is ETS and the control structure for the DLN
system is AutoTune. This document primarily explains ETS.
The startup control scheme uses
the same logic as the legacy
part-speed control logic.
ARES is currently designed for use only when connected to the grid at operating points
above full speed no load (FSNL). ETS requires ARES to operate; therefore a separate
control scheme, referred to as startup control, is used during turbine startup or shutdown.
Startup control consists of all part-speed operation (generator breaker open), and includes
all control loops and commands that do not use the ARES model.
Startup/Cycle Control Mode Selection
GEH-6810
User Guide
11
Improved Transient (Grid) Response
The ETS product was designed to improve the transient response of GE Energy gas
turbines. It accomplishes this objective by using three main methods:
•
Maintenance of global fuel/air ratio through coordinated air-fuel control
•
Regulation of fuel response (fuel stroke reference [FSR]) by filtering the speed input
to the load governor and controlling fuel response to rapid transients
•
Increase of transient lean blowout (LBO) margin, which is accomplished through
transient DLN fuel split biasing.
Model-based Coordinated Air-fuel (MBCAF)
The global fuel-air ratio is
the total fuel entering the
combustor divided by the total
airflow entering the combustor.
The modern DLN combustor only remains operable over a small window of stoichiometric
ratios. If the ratio is too high, the combustor will experience high combustion dynamics
and NOx emissions. If the ratio is too low, the combustor will flame out or produce
excessive CO. The goal of the Coordinated Air-Fuel (CAF) control is to maintain
the global fuel-air mixture (or stoichiometric ratio) delivered to the combustor in an
operable range. The CAF control typically uses IGVs as its actuator. Therefore, the
CAF regulates airflow into the compressor in response to sensed or demanded fuel flow
into the combustor.
The MBCAF control improves
the transient capability of the
gas turbine by adjusting air and
fuel flow rates simultaneously.
The basic idea behind the MBCAF control is to create a model of an ideal IGV-to-FSR
relationship (also known as the CAF Map), and to then use that modeled relationship to
control IGVs in response to a fast FSR motion instead of the nominal exhaust temperature
feedback loop. The MBCAF intends to impact IGV control only when FSR is moving
faster than the normal IGV control loop can follow. The target of the MBCAF is
significant grid events, when FSR can load/unload the unit at a rate that can exceed 10 to
15 times the nominal loading rate.
Grid Frequency Filter (GFF)
Gas turbine robustness to LBO during abrupt frequency disturbances can be a concern,
particularly in the emission compliant modes of a DLN combustor. Any change in grid
frequency causes a speed error, and invokes a response in which the speed-based fuel
command is modified. Rapid changes in commanded fuel flow are not necessarily paired
with well-coordinated changes in airflow, potentially leading the combustor to a condition
in which it is operating either too rich or too lean. In addition, grid requirements do not
currently require the kind of rapid fuel flow changes that can occur during grid events
when no filtering is applied to sensed speed.
To address this condition, a speed/frequency filter called the Grid Frequency Filter (GFF)
is used to shelter the gas turbine from the full effects of extreme frequency disturbances.
As grid speed changes dramatically, only a tolerable rate of the change is passed through
to the load governor to set the new fuel command. In effect, this limits the response of
the engine during grid events to maneuvers which are more aligned with actual machine
capability, as well as only that response required by the relevant grid code(s).
12
OpFlex Enhanced Transient Stability (ETS) for GE Gas Turbines
The GFF design is based upon a self-imposed transient power response requirement
aligned with the most stringent European grid codes. The assumed transient power
response requirement is defined as follows. If measured, the turbine output response
to a 1% (60 Hz) change in grid frequency ramped in over a 10 second period and then
sustained for another 20 seconds is such that the power at the end of the 10 seconds has
changed by at least the power response (P) and is sustained for 20 seconds.
Transient Power Response Requirement (as measured)
The magnitude of the power response (P) is expressed as a percent (%) of rated output
and is scheduled as a function of the current gas turbine load (refer to the following
figure). Holding each gas turbine to such a requirement is a more appropriate balance
between responsiveness (supporting the grid) and precaution as to not call upon units to
respond in a way that is beyond their transient operating capability where they may be
more vulnerable to LBO.
Power Response Requirement as a Function of Gas Turbine Load
GEH-6810
User Guide
13
The requirement is stated so that the turbine is expected to be most responsive while in the
emission compliant mode of operation that is consistent with being at a dispatchable load
level. The requirement assumes that a unit operating below the minimum turndown point
(outside of emission compliance) has no transient power response expectation tied to it.
This is consistent with the fact that these units are most likely loading or unloading to or
from the emission compliant modes as part of a startup or shutdown, and not being relied
upon to support the grid. If a unit operating just above the turndown point is faced with a
positive change in grid frequency, it will be called upon to shed load, but the rate will be
less than the maximum and adjusted as load changes as to discourage an actual transfer
out of the combustion mode. Similarly, a unit operating at base load that is faced with a
negative change in grid frequency will not respond as it cannot pick up any more load
from the base loaded point without incurring a higher maintenance factor.
Flame Anchoring Stability (Transient Split Bias)
The transient DLN split bias function temporarily adjusts pre-determined fuel circuits by
pre-determined amounts to ensure sufficient LBO margin during fast transients. The
amount of split bias given to a fuel circuit is calculated differently depending upon
whether the unit is running in AutoTune or not. If the unit is not running in AutoTune, the
fuel splits are biased by a constant percentage during every application of split biasing.
If the unit is running in AutoTune, the split biases are calculated in real time to ensure
sufficient LBO margin while limiting total split levels in an effort to minimize the impact
on combustion system dynamics and emissions.
14
OpFlex Enhanced Transient Stability (ETS) for GE Gas Turbines
Input Signal Processing (ISP)
The accuracy of the ARES model relative to the actual operating turbine is extremely
important. If ARES believes a parameter to be one value when in reality it is something
else, the control system will have no knowledge that it is in error. The result can be broken
hardware or reduced component life. The accuracy of the ARES model is dependent
on the accuracy of the gas turbine input sensors. It is therefore more important that the
sensors are kept operational and in good calibration for MBC than for a non-MBC based
control scheme.
Recognizing this potential weakness, a new input signal processing (ISP) function
was developed for MBC. The ISP function provides fault detection, isolation, and
accommodation (FDIA) for each analog sensor input that is critical to maintaining the
accuracy of ARES across the load envelope. It also initiates appropriate control system
actions based on input sensor status. The sensor measurements monitored by the ISP
function are those inputs which have the greatest impact on gas turbine operational
parameters across the load and ambient envelope, both those estimated by ARES as well
as standard parameters such as exhaust temperature. A representative list of sensor
measurements in the scope of the ISP function is as follows:
GEH-6810
•
Ambient pressure
•
Inlet dew point temperature
•
Inlet bleed heat upstream pressure
•
Inlet bleed heat downstream or differential pressure
•
Compressor discharge pressure
•
Compressor discharge temperature
•
Compressor inlet temperature
•
Generator power
•
Gas fuel pressure
•
Gas fuel system differential pressures for PM1, PM2, PM3
•
Gas fuel flow
•
Gas fuel temperature
•
Liquid fuel water injection flow
•
9th stage compressor extraction pressure
•
13th stage compressor extraction pressure
User Guide
15
The ISP function uses statistical techniques to provide a complete solution to input
signal processing diagnostics – out-of-range and in-range fault detection, faulted channel
isolation and measured parameter accommodation for single, dual, and triple-redundant
sensors. The algorithm is able to distinguish between the following fault types:
•
No fault
•
Availability fault
•
Spike fault
•
Shift fault
•
Stuck fault (low noise)
•
Noise fault (high noise)
•
Disagreement fault (able to be isolated to a specific channel)
•
Drift fault
•
Redundant channel differential (not able to be isolated to a specific channel)
Fault detection is based on specific fault mode confidence calculations. Specific
confidences are combined to determine overall channel confidences and classification of
faults, if they exist. The instantaneous channel confidences are combined with recent
historical health information to derive a final confidence value for each sensor. Lastly, the
accommodation takes into account all system information to decide how to combine each
of the sensor readings to obtain a final output value for the measured parameter, which is
used by all downstream control functions.
Protective Actions
The sensor failures are aggregated from all monitored sensors. Based upon a
pre-determined protective matrix, the ISP takes the appropriate actions to protect the gas
turbine. The following is a representative list of the protective actions that can be taken by
the ISP logic:
16
•
Start inhibit (a start permissive)
•
Use a model/surrogate in place of a failed sensor set
•
Slew out of ETS (step to spinning reserve)
•
Slew out of AutoTune
•
Disable liquid fuel water injection
•
Fail the inlet bleed heat (IBH) system open
•
Disable the IBH DLN turndown schedule (raise the minimum IGV angle)
•
Load reject to full speed no load (FSNL)
•
Fired shutdown
•
Trip
•
Fail degraded operation
OpFlex Enhanced Transient Stability (ETS) for GE Gas Turbines
The application of the ISP strategy brings with it the benefit of more flexibility in the
automated protective actions of the gas turbine when station instrumentation fails. This
means that when certain sensors fail, the unit may still operate at a reduced output level
rather than causing the unit to trip. Fail degraded is an operational mode used for situations
when the impact of sensor failures on key gas turbine operational boundaries has been
quantified, and thus can be conservatively accommodated in the parameter boundaries.
The new operating state depends on the specific sensor failure or set of failures. The
fail degraded concept was introduced to maintain power generation, while potentially
avoiding more severe consequences of failures, such as an automatic shutdown or trip.
The magnitude of potential gas turbine derate is indicated by the fail degraded level, on a
scale of 1-10, with higher numbers being more severe. The scale is relative and does not
indicate a specific impact to the gas turbine, as this can vary with operating condition.
Sensor Models
An integral piece of the ISP is a generic tool set of sensor-specific models that may be
used to provide additional virtual sensor readings to assist in unit operation and control.
As previously stated, sensor models are used to increase the range of protective actions
available to ISP, and to assist in fault isolation. The sensor models are all physics-based
models, and many are tuned on a machine-to-machine basis, either automatically in
real-time, or at unit commissioning. A representative list of sensor models included with
the ISP function is as follows:
•
Ambient pressure
•
Inlet dew point temperature
•
Inlet bleed heat flow
•
Compressor discharge pressure
•
Compressor discharge temperature
•
Compressor inlet temperature
•
Generator power
•
Gas fuel flow
•
Liquid fuel flow
•
Liquid fuel water injection flow
Each sensor model provides an indication of its validity, as well as an alarm for faulted
conditions. The validity logical indicates when the model should and should not be used.
Some sensor models are expected to not be valid at certain times, for example, there are
ARES-based models that cannot be valid when the main ARES model is not valid. In
these cases the alarm is masked, but the model output is not used by the ISP.
GEH-6810
User Guide
17
Human-machine Interface (HMI) Screens
Three screens have been added to the HMI to facilitate sensor training and tuning as
well as communicate the enhanced level of sensor information provided by this update
to the operator. Details on these screens are provided in the figures in this section (use
the notes for guidance).
Note The screens in this section are illustrations for reference only; actual screens
may vary slightly.
MBC Sensor Data
Feedbacks from the LVDTs
(gas valves, SRV, IGV, and IBH
positions) are also displayed,
but enhanced information is not
available for these sensors.
This screen displays an overview of the entire gas turbine, including all applicable fuel
streams and inlet, with analog sensor readings displayed in their approximate physical
location. All of the analog sensor sets with enhanced protection provided by this package
have a faceplate that turns red if any problems are detected with that sensor set. For
example, the following figure displays the compressor inlet temperature (CTIM) has
detected a failure.
MBC Sensor Data HMI Screen
18
OpFlex Enhanced Transient Stability (ETS) for GE Gas Turbines
If at any time the user moves the cursor over a faceplate, the application code signal name
displays on the faceplate as shown in the following figure.
Faceplate Application Code Signal Name Display
If the unit is operating in a fail-degraded mode, the MBC Sensor Data screen also displays
the fail-degraded level at which the unit is operating. The figure, MBC Sensor Data HMI
Screen, displays an example of the unit operating in fail-degraded mode Level 9. This
element disappears when the unit is not operating in fail-degraded mode.
MBC Sensor Data Specific Details
By clicking on any of the faceplates, the sensor data HMI screen displays sensor specific
details. There are three possible popup screens that may be displayed depending on the
redundancy of the sensor set: simplex (single sensor), duplex (dual-redundant), or triplex
(triple-redundant).
Simplex Sensor Faceplate
GEH-6810
User Guide
19
Duplex Sensor Faceplate
Triplex Sensor Faceplate
Raw Sensor Values – On an individual channel basis, the faceplate displays each sensor’s
current reading in analog and bar chart form. The bar chart range limits are determined
by each parameter’s engineering range limits, which are set by control constants in
application code.
Output Selection – For the input parameter being examined (such as CPD and CTD), the
displayed output value is the result of the input selection processing function. The output
selection is the value of the parameter used by the control system.
20
OpFlex Enhanced Transient Stability (ETS) for GE Gas Turbines
Selection Status – For the input parameter being examined, the method of output selection
is displayed on the faceplate. For example, a triplex sensor with all good input channels
calculates a median output. The selection status options are as follows:
•
Median
•
Weighted average of A & B
•
Weighted average of A & C
•
Weighted average of B & C
•
Channel A
•
Channel B
•
Channel C
•
Model
•
Default Value
Confidence – On an individual channel basis, confidence displays on a scale of 0-1 how
confident the input signal processing is of that sensor’s reading. A confidence of zero
indicates a failure has been detected, while a confidence of one indicates a completely
healthy sensor. This box turns red if a failure has occurred.
Long-term (LT) Confidence – On an individual channel basis, LT confidence displays on
a scale of 0-1 how confident the input signal processing has been in that sensor’s reading
over a period of approximately the past 24 hours, with greater emphasis on more recent
sensor behavior. This box turns red if long-term confidence is very low.
Refer to the section Input Signal
Processing (ISP) for a list of
faults
Fault Status – If a failure has been detected, fault status provides a best guess as to the
failure mode of that sensor. Also identifies when sensors have high spread. This box turns
red if a fault has been detected, and yellow if high spread is detected.
Fail Degraded Box – The fail degraded box displays if the unit is utilizing a sensor model
input. As displayed in the previous figure, the unit is in Fail Degraded Mode Level 9 due
to a CTIM hardware set failure.
GEH-6810
User Guide
21
MBC Sensor Training
As described previously, one of the fault detection checks looks for abnormally high
or low noise relative to a normal baseline. The baseline is established once during the
commissioning of the software, during which adjustments to the default sensor noise
levels are made. The constants are then stored in non-volatile random access memory
(NOVRAM) within the gas turbine controller such that they are recalled even if the
controller is powered down and returned to service. If failed sensors are not replaced in
kind, training should be manually initiated to avoid unnecessary protective actions. This
screen is used to facilitate this tuning process.
Note Sensor training must be completed before loading the unit beyond spinning
reserve for the first time.
Noise Training Initiation Button (On) – This is located in the center of the screen toward
the top in the Sensor Training box. Clicking this button performs training on all sensor
sets that have been enabled and meet the necessary permissives. This button changes to
blue in color for the duration of the training process.
Individual Sensor Set Training Status Boxes – These comprise the majority of the
screen. The training procedure can be enabled or disabled for an individual sensor set by
selecting the Enable or Disable button for that sensor. Successful training automatically
sets the Disable button (displays in blue), but the user can enable noise training at a later
time by manually selecting the Enable button again. All sensor sets are set to enable
(Enable button displays in blue) initially for convenience. Upon successful completion
of sensor training the sensor displays Trained in green. Otherwise, Not Trained displays
in red.
Example: In the figure MBC Sensor Tuning HMI Screen only the CTIM sensor set has
been successfully trained. With the exception of TS2P and WQ, all sensor sets in the
right column have met the necessary requirements for training (they display Permitted
in green and Enable displays in blue). Clicking the On button would train all of them
simultaneously. In contrast, the sensor sets in the left column have all met the permissive
(Permitted displays in green) but are disabled. The sensor sets associated with water
injection and the Cooling Optimization Package (COP) have not met the permissives (Not
Permitted displays in red) because the unit is consuming gas rather than liquid fuel and at
a load below where COP may be initiated.
22
OpFlex Enhanced Transient Stability (ETS) for GE Gas Turbines
MBC Sensor Training HMI Screen
GEH-6810
User Guide
23
MBC Sensor Tuning
In the event a sensor set measuring a critical input has failed, sensor models are used to
support the unit in fail degraded operation. For simplicity, sensor models are referred
to with an M suffix added to the signal name. As an example, the sensor model for
compressor inlet temperature which has signal name CTIM is CTIMM.
A subset of the sensor sets with model counterparts include automated tuning features
for their respective model. This is done to maximize its accuracy. The indications and
pushbuttons required to utilize this functionality reside in their respective sensor tuning
boxes located in the Sensor Model Tuning field in the upper right hand corner of the screen
as displayed in the following figure. In general, the automated tuning process makes
permanent adjustments to the sensor model calculations based on the hardware outputs
at the time tuning is initiated. Sensor models should be tuned during commissioning as
well as after any hardware changes within the subsystem they reside as they do make
assumptions about subsystem components.
MBC Sensor Tuning HMI Screen
Outputs – The output of the sensor model is displayed in the field with the white
background, below its hardware counterpart displayed in the field with the grey
background. If the control logic detects a problem with a given sensor model, the white
field containing its output displays Invalid. (Refer to the previous figure; inlet bleed heat
flow [CQBH] displays Invalid.) Similarly, when a fault is detected within a sensor set, the
text in the grey field containing the hardware output changes from black to white. (Refer
to compressor discharge pressure [CPD] in the previous figure.) This designates that the
hardware is not performing optimally but is still being used by the controller.
24
OpFlex Enhanced Transient Stability (ETS) for GE Gas Turbines
Faceplates – If the controller is using the information provided by the hardware, the
faceplate associated with a given signal remains grey. In the event all available hardware
intended to provide that signal has failed, the unit operates in a fail-degraded state using
output from the sensor model. This is indicated by the faceplate of the sensor model
changing to red. (Refer to the compressor inlet temperature (CTIM) in the previous
figure.) The popup screen associated with each faceplate is available on this screen by
clicking the faceplate on the Sensor Data screen.
Fail Degraded Box – Similar to the functionality on the Sensor Data screen, the fail
degraded box displays if the unit is utilizing a sensor model input. As displayed in the
previous figure, the unit is in Fail Degraded Mode Level 9 due to a CTIM hardware
set failure.
Individual Sensor Set Training Status Boxes – If a sensor model has never been tuned,
Not Tuned displays in red. In the previous figure both the water injection flow sensor
model (WQM) and the gas fuel flow sensor model (FQGM) have not been tuned. The first
step to tune is to verify the Permitted indication is green. This means all of the required
permissives specific to that particular sensor model have been met. This is the case for the
inlet bleed heat flow sensor model (CQBH) in the previous figure. Tuning can then be
initiated by clicking the Enable button. This button remains blue in color for the duration
of the tuning process which is different for each sensor model. Once the tuning process
has been completed, Commissioned displays in green on the respective sensor model. For
example, in the previous figure, the compressor inlet temperature sensor model (CTIMM)
and the inlet bleed heat flow sensor model (CQBHM) are commissioned.
Note Tuning can be repeated after commissioning if system hardware has been
changed and/or a sensor model indicates it is invalid, and all of its input parameters
have been verified to be in working order.
Combustor Hardware Selection
The Combustor Hardware Selection screen allows the user to account for different
combustor hardware configurations. This enables proper GT operation based on actual
combustion hardware installed.
GEH-6810
User Guide
25
Cycle Reference Parameters
Combustion Reference (CRT)
The control variable Combustion Reference (CRT) is used to define combustion mode
transfer points (including staying in emissions compliance) and fuel split schedules for the
DLN system, replacing the functionality of the traditional TTRF1 signal. The CRT can
also be used as a boundary for control of specific gas turbine cycle effectors as required
by given engine configuration. Depending on the plant requirements, the signal CRT
can also be used for scheduling the operation of additional plant equipment through the
distributed control system (DCS).
Encoded parameters are
proprietary to GE Energy.
Many cycle parameters, including the CRT, are encoded; the value is not given in
engineering units but rather in non-dimensional units. The encoded values still allow for
full evaluation and manipulation of gas turbine operation.
Turbine Reference (TRT)
The control variable TRT is used to define proper or nominal turbine operation,
predominantly at base load. It is an encoded value that allows for verification of predefined
turbine operation by the operators of the power plant to ensure that gas turbine operation
is as expected. This encoded value is synonymous with previous usage of TTRF1 by gas
turbine operators to verify that the unit is operating correctly on the exhaust temperature
control curves, which are no longer in use with ETS. A correlation between a gas turbine
input parameter such as ambient temperature or compressor inlet temperature and turbine
reference is provided to the customer at commissioning of the unit to be used to assess
proper gas turbine operation.
26
OpFlex Enhanced Transient Stability (ETS) for GE Gas Turbines
Alarms and Unit Response
As part of the high-level protection strategy associated with MBC, alarms indicate various
faults that have an impact on the system. It is important that these guidelines be followed
to maintain the integrity and operability of MBC.
It is imperative that only trained personnel perform any of the
following actions, and that all site-wide safety procedures are
followed.
Attention
Alarm List and Gas Turbine Response
Alarm Signal
L83CA_F_A
Fault Condition
•
ARES Model Fails
Controller Display / Action
Recommended Operator
Actions
ARES DIAGNOSTIC FAULT MBC DISABLED
Allow at least five minutes for
the alarm to clear. This fault
requires a master reset to clear.
If the alarm becomes active
again (or if the original alarm
never clears), contact the PAC
center for assistance.
Step the unit to spinning reserve.
L30SUC_LLO
GEH-6810
•
In startup control at too
high of a load, CRT, or not
on minimum IGV angle.
•
Unable to enter cycle
control.
Start Up Control Load Lock Out
Alarm
•
ARES model has failed
(see L83CA_F_A)
•
Ensure compressor bleed
valves are closed.
•
Sensor failures have
disabled the ARES model.
See LCA_CSENS_A
for details on specific
combinations of sensor
failures).
•
All CPD sensors
unavailable AND CPD
sensor model not valid
•
All CTD sensors
unavailable AND CTD
sensor model not valid
•
All DWATT sensors
unavailable AND DWATT
sensor model not valid
•
Refer to the table Sensor
Fault Root Causes and
Recommended Actions for
recommended actions to
fix sensor failures.
User Guide
27
Alarm Signal
Fault Condition
Controller Display / Action
Recommended Operator
Actions
L30TS2PSENS_A
•
Ejector system not
operational
SENSOR FAULTS - DISABLE
EJECTOR SYSTEM
Inspect Ejector sensors. Refer
to the table Sensor Fault Root
Causes and Recommended
Actions for troubleshooting
tips.
L30TSQPSENS_A
•
Ejector system not
operational
SENSOR FAULTS - DISABLE
EJECTOR ISOLATION
VALVE
Inspect Ejector sensors. Refer
to the table Sensor Fault Root
Causes and Recommended
Actions for troubleshooting
tips.
LCA_SENSTRN_A
•
Sensor training has not
been performed or was not
successful
MBC RUNBACK DUE TO
INADEQUATE SENSOR
TRAINING
Perform sensor training as
described in GEH-6810.
LTS2P_TRNP_A
•
Sensor training for TS2P
has not been performed or
was not successful
TS2P SENSOR HAS NOT
BEEN TRAINED - PERFORM
SENSOR TRAINING
PROCEDURE
Perform sensor training as
described in GEH-6810.
LTS2QP13_TRNP_A •
Sensor training for
TS2QP13 has not been
performed or was not
successful
TS2QP13 SENSOR HAS
NOT BEEN TRAINED
- PERFORM SENSOR
TRAINING PROCEDURE
Perform sensor training as
described in GEH-6810.
LTS3QP9_TRNP_A
•
Sensor training for
TS2QP9 has not been
performed or was not
successful
TS3QP9 SENSOR HAS
NOT BEEN TRAINED
- PERFORM SENSOR
TRAINING PROCEDURE
Perform sensor training as
described in GEH-6810.
LWQ_TRNP_A
•
Sensor training for WQ
has not been performed or
was not successful
WQ SENSOR HAS NOT
BEEN TRAINED - PERFORM
SENSOR TRAINING
PROCEDURE
Perform sensor training as
described in GEH-6810.
L3SENS_A
•
One or less CPD sensors
available OR
SENSOR FAULTS - INHIBIT
START
•
One or less FPG2 sensors
available OR
Start Inhibited
•
One or less CTIM sensors
available OR
•
Two or more of the
following are true:
Examine sensor faults and
sensor model validity changes
(with associated alarms) that
caused protective action. Refer
to the table Sensor Fault Root
Causes and Recommended
Actions for recommended
actions to fix sensor failures.
−
−
−
−
−
28
One or less AFPAP
sensors available
One or less CPD
sensors available
One or less CTD
sensors available
Zero ITDP sensors
available
Zero CPBH1 sensors
available
OpFlex Enhanced Transient Stability (ETS) for GE Gas Turbines
Alarm Signal
Fault Condition
Controller Display / Action
Recommended Operator
Actions
Generator breaker closed
AND all DWATT sensors
unavailable AND DWATT
sensor model not valid
SENSOR FAULTS – LOAD
REJECT TO FSNL
Examine sensor faults and
sensor model validity changes
(with associated alarms) that
caused protective action. Refer
to the table Sensor Fault Root
Causes and Recommended
Actions for recommended
actions to fix sensor failures.
•
All FPG2 sensors
unavailable AND on
total gas fuel OR
SENSOR FAULTS – TRIP
UNIT
•
All CPD sensors
unavailable AND CPD
sensor model not valid
AND at minimum
operating speed AND
generator breaker closed
•
All FTG sensors
unavailable AND on
total gas fuel OR
•
Start permissive conditions
not met AND breaker not
closed AND not tripped
AND not already shutting
down
•
All CTIM sensors
unavailable AND CTIM
sensor model not valid OR
•
All AFPAP sensors
unavailable
−
−
−
−
−
L30LRSENS_A
L86SENS_A
L94SENS_A
L3BHSENS_A
GEH-6810
•
Zero CPBH2 sensors
available
One or less FPG2
sensors available
AND not on total
liquid fuel
One or less FTG
sensors available
AND not on total
liquid fuel
Zero FQG sensors
available AND not on
total liquid fuel
Zero FQLM1 sensors
available AND on
total liquid fuel
Load Reject to FSNL
Trip
SENSOR FAULTS –
SHUTDOWN UNIT
Fired Shutdown Initiated
SENSOR FAULTS - FAIL
BLEED HEAT OPEN
IBH System Failed Open (by
solenoid)
Examine sensor faults and
sensor model validity changes
(with associated alarms) that
caused protective action. Refer
to the table Sensor Fault Root
Causes and Recommended
Actions for recommended
actions to fix sensor failures.
Examine sensor faults and
sensor model validity changes
(with associated alarms) that
caused protective action. Refer
to the table Sensor Fault Root
Causes and Recommended
Actions for recommended
actions to fix sensor failures.
Examine sensor faults and
sensor model validity changes
(with associated alarms) that
caused protective action. Refer
to the table Sensor Fault Root
Causes and Recommended
Actions for recommended
actions to fix sensor failures.
User Guide
29
Alarm Signal
L3BHTSENS_A
•
Fault Condition
Controller Display / Action
Recommended Operator
Actions
CPBH2 sensor not
available AND CQBH
sensor model not valid
SENSOR FAULTS –DISABLE
IBH DLN TURNDOWN
Examine sensor faults and
sensor model validity changes
(with associated alarms) that
caused protective action. Refer
to the table Sensor Fault Root
Causes and Recommended
Actions for recommended
actions to fix sensor failures.
IBH DLN Turndown Schedule
Disabled,Minimum IGV Angle
Increased
L3WQSENS_A
•
WQ sensor failure of any
type detected
SENSOR FAULTS - DISABLE
WATER INJECTION
Liquid Fuel Water Injection
System Disabled
L30LRSENS_A
LCA_SENS_FD
L30AFPAP_0
L30AFPAP_1
L30AFPAP_2
L30AFPAP_DIF
L30CPBH1_0
L30CPBH2_0
L30CPD_0
L30CPD_1
L30CPD_2
L30CPD_DIF
L30CTD_0
L30CTD_1
L30CTD_2
L30CTD_DIF
L30CTIM_0
L30CTIM_1
L30CTIM_2
L30CTIM_DIF
L30DWATT_0
L30DWATT_1
L30DWATT_DIF
L30FPG2_0
L30FPG2_1
L30FPG2_2
L30FPG2_DIF
L30FPGN1_0
30
•
•
Generator breaker closed
AND all DWATT sensors
unavailable AND DWATT
sensor model not valid
SENSOR FAULTS - LOAD
REJECT TO FSNL
A sensor fault in one of
the monitored parameters
(AFPAP, CPD, CTD,
CTIM, DWATT, FPG2,
FPGN1, FPGN2, FPGN3,
FQG, FQLM1, FTG,
ITDP, WQ, TS2P,
TS2QP13, or TS3QP9) has
occurred.
Fail degraded biases applied to
machine boundary targets as
appropriate to accommodate
these sensor failures.
Load Reject to FSNL
Examine sensor faults and
sensor model validity changes
(with associated alarms) that
caused protective action. Refer
to the table Sensor Fault Root
Causes and Recommended
Actions for recommended
actions to fix sensor failures.
Examine sensor faults and
sensor model validity changes
(with associated alarms) that
caused protective action. Refer
to the table Sensor Fault Root
Causes and Recommended
Actions for recommended
actions to fix sensor failures.
Refer to the table Sensor
Fault Root Causes and
Recommended Actions for
recommended Operator
Actions.
OpFlex Enhanced Transient Stability (ETS) for GE Gas Turbines
Alarm Signal
Fault Condition
Controller Display / Action
Recommended Operator
Actions
L30FPGN1_1
L30FPGN1_2
L30FPGN1_DIF
L30FPGN2_0
L30FPGN2_1
L30FPGN2_2
L30FPGN2_DIF
L30FPGN3_0
L30FPGN3_1
L30FPGN3_2
L30FPGN3_DIF
L30FPGN4_0
L30FPGN4_1
L30FPGN4_2
L30FPGN4_DIF
L30FQG_0
L30FTG_0
L30FTG_1
L30FTG_2
L30FTG_DIF
L30ITDP_0
L30ITDP_1
L30ITDP_2
L30ITDP_DIF
L30WQ_0
L30WQ_1
L30WQ_DIF
L30TS2P_0
L30TS2P_1
L30TS2P_2
L30TS2P_DIF
L30TS2QP13_0
L30TS2QP13_1
L30TS2QP13_2
L30TS2QP13_DIF
L30TS3QP9_0
L30TS3QP9_1
L30TS3QP9_2
L30TS3QP9_DIF
LCA_ATSENS_A
GEH-6810
•
All FPGN1 sensors
unavailable OR
•
All FPGN2 sensors
unavailable OR
•
All FPGN3 sensors
unavailable
SENSOR FAULTS –
AUTOTUNE DISABLED
Slew Out of Autotune
MBC,FSR-VPR Loop Disabled
Examine sensor faults and
sensor model validity changes
(with associated alarms) that
caused protective action. Refer
to the table Sensor Fault Root
Causes and Recommended
Actions for recommended
actions to fix sensor failures.
User Guide
31
Alarm Signal
LCA_CSENS_A
Fault Condition
•
All CTD sensors
unavailable AND CTD
sensor model not valid OR
•
All CTIM sensors
unavailable AND CTIM
sensor model not valid OR
•
FQLM1 sensor unavailable
AND on total liquid fuel
OR
•
2 or more of the following
are true:
−
−
−
−
−
−
−
−
−
−
−
−
32
Controller Display / Action
SENSOR FAULTS – ARES
DISABLED
Slew Out of ALCC (Step to
Spinning Reserve)
Recommended Operator
Actions
Examine sensor faults and
sensor model validity changes
(with associated alarms) that
caused protective action. Refer
to the table Sensor Fault Root
Causes and Recommended
Actions for recommended
actions to fix sensor failures.
One or less AFPAP
sensors available
One or less CPD
sensors available
One or less CTD
sensors available
One or less DWATT
sensors available
Zero ITDP sensors
available
Zero CPBH1 sensors
available
Zero CPBH2 sensors
available
One or less FPG2
sensors available
AND not on total
liquid fuel
One or less FTG
sensors available
AND not on total
liquid fuel
Zero FQG sensors
available AND not on
total liquid fuel
Zero FQLM1 sensors
available AND on
total liquid fuel
One or less WQ
sensors available
AND water injection
is on
OpFlex Enhanced Transient Stability (ETS) for GE Gas Turbines
Alarm Signal
L30CPDM
Fault Condition
•
CPD sensor model is not
valid
Controller Display / Action
CPD SENSOR MODEL
INVALID
CPD sensor model output is
ignored in downstream logic,
ex. input signal processing
(ISP).
L30CTDM
•
CTD sensor model is not
valid
CTD SENSOR MODEL
INVALID
CTD sensor model output is
ignored in downstream logic,
ex. input signal processing
(ISP).
L30DWATTM
•
DWATT sensor model is
not valid
DWATT SENSOR MODEL
INVALID
DWATT sensor model output is
ignored in downstream logic,
ex. input signal processing
(ISP).
L30CTIMM
•
CTIM sensor model is not
valid
CTIM SENSOR MODEL
INVALID
CTIM sensor model output is
ignored in downstream logic,
ex. input signal processing
(ISP).
L30FQGM
•
FQG sensor model is not
valid
FQG SENSOR MODEL
INVALID
FQG sensor model output is
ignored in downstream logic,
ex. input signal processing
(ISP).
L30CQBHM
•
CQBH sensor model is not
valid
CQBH SENSOR MODEL
INVALID
CQBH sensor model output is
ignored in downstream logic,
ex. input signal processing
(ISP).
GEH-6810
Recommended Operator
Actions
Check health of input sensors
to model first (CPD, DWATT).
Verify wiring, calibration,
device integrity, and so forth.
Replace if necessary.Repeat for
all other ARES analog sensor
inputs.
Check health of input sensors
to model first (CTD, DWATT).
Verify wiring, calibration,
device integrity, and so forth.
Replace if necessary.Repeat for
all other ARES analog sensor
inputs.
Check health of input sensors
to model first (CPD, CTD).
Verify wiring, calibration,
device integrity, and so forth.
Replace if necessary.Repeat for
all other ARES analog sensor
inputs.
Check health of input sensors
to model (CTD, CPBH1,
CPBH2). Verify wiring,
calibration, device integrity,
and so forth. Replace if
necessary.Turn off evaporative
cooling.
Check health of input sensors
to model (CPD, FPG2, FTG,
FPGN1, FPGN2, FPGN3).
Verify wiring, calibration,
device integrity, and so forth.
Replace if necessary.
Check health of input sensors to
model (CTD, CPBH1). Verify
wiring, calibration, device
integrity, and so forth. Replace
if necessary.
User Guide
33
Alarm Signal
L30ITDPM
Fault Condition
•
ITDP sensor model is not
valid
Controller Display / Action
ITDP SENSOR MODEL
INVALID
ITDP sensor model output is
ignored in downstream logic,
ex. input signal processing
(ISP).
L30WQM
•
WQ sensor model is not
valid
WQ SENSOR MODEL
INVALID
WQ sensor model output is
ignored in downstream logic,
ex. input signal processing
(ISP).
34
Recommended Operator
Actions
Check health of input sensors
to model (AFPAP, CTIM).
Verify wiring, calibration,
device integrity, and so forth.
Replace if necessary.
Check health of input sensors
to model (WQDP). Verify
wiring, calibration, device
integrity, and so forth. Replace
if necessary.
OpFlex Enhanced Transient Stability (ETS) for GE Gas Turbines
Sensor Fault Root Causes and Recommended Actions
Possible Causes of Sensor Fault
Detection
Recommended Operator Actions
Control hardware failure
•
Examine I/O board/pack diagnostics log
•
Check proper I/O layout/fanning to ensure single panel loss does not result
in sensor signal loss
•
Ensure all controllers in controlling state (not inputs enabled, and such)
•
Find source of contamination and seal
•
Clean or replace sensing lines
•
Check if new equipment recently installed near sensing lines/wiring
•
Install additional electromagnetic shielding
•
Ensure proper signal path separation from power wiring
•
Re-route sensing lines/wiring
•
Physically inspect transmitter for damage, wear, and leakage
•
Replace transmitter
•
Perform signal injection tests to confirm proper operation
•
Double-check device settings including I/O settings in application software
•
Check I/O configuration in application software is consistent with panel layout
•
Ensure tight terminations in control cabinets and connections at the device
•
Perform loop checks
Sensor not properly calibrated
•
Recalibrate the sensor
Sensors isolated or valved out
•
Remove isolation block (if present)
•
Confirm sensors not in calibration mode
•
Disengage isolation valve (if present)
•
Thermocouples: check proper well installation and insertion depth
•
Differential pressures: ensure lines piped to correct sides of transmitters
•
Pressure transmitters: look for leakages
•
Check sensor placed in proper physical location/tap
Dirty pneumatic or sensing lines
External interference
Faulty or broken transmitter
Incorrect I/O settings
Loose, broken, and/or incorrect wiring
Wrong installation
GEH-6810
User Guide
35
Glossary of Terms
Adaptive Real-time Engine Simulation (ARES) is a high-fidelity model of the
gas turbine that is continuously tuned in real-time to match the performance of the actual
machine.
All Load Cycle Control (ALCC) is a technology that implements MBC direct
boundary control from breaker closure for the bulk fuel/air boundaries.
AutoTune is a software product that adds closed loop DLN split control to ETS,
enabling greater allowable MWI variation and elimination of seasonal retunes.
Boundary is a limit, such as an operational limit or a design limit. An example would
be the typical 9 ppm NOx limitation for a 7FA+e gas turbine.
Boundary Models are physics-based models that capture the fundamental behavior
of the operational boundaries.
Coordinated Air-Fuel (CAF) is a control strategy used to maintain an operable
global fuel-air mixture in the combustor during gas turbine transient events.
Combustion Reference (CRT) is a control system parameter used to schedule
combustion mode transfer points and split schedules.
Effectors are the control elements that alter machine operation; IGV, inlet bleed heat,
total fuel flow, fuel temperature, and DLN fuel splits.
Enhanced Transient Stability (ETS) is a product that utilizes the technology
platform of ALCC and provides improved transient response of GE gas turbines using
MBCAF, the GFF, and transient fuel split biasing.
Grid Frequency Filter (GFF) is a speed filter specifically designed for the ETS
product utilized to shelter the gas turbine from the full effects of extreme frequency
disturbances.
GE Control System Solutions (CSS toolbox) is a Windows®-based application
used to configure Mark* VI control hardware and software.
Health is a term that defines whether a variable is functioning as expected.
Input Signal Processing (ISP) is a signal-processing-based fault detection,
isolation, and accommodation strategy applied to all sensor inputs critical to the accurate
operation of ARES.
Loop in Control (LIC) is a status indication that displays which control loop is
generating the output reference for an effector.
Model-based Control (MBC) is a control strategy designed to improve the
performance and operational flexibility of a GE gas turbine.
Model-based Coordinated Air-Fuel (MBCAF) is a coordinated air-fuel strategy
specific to the ETS product that creates a model of an ideal IGV-to-FSR relationship then
uses that modeled relationship to control IGVs in response to a fast FSR motion.
ToolboxST* application is a Windows-based application used to configure Mark Ve
and Mark VIe control hardware and software.
Turbine Reference (TRT) is a control system parameter used to define proper or
nominal turbine operation, predominantly at base load.
36
OpFlex Enhanced Transient Stability (ETS) for GE Gas Turbines
Notes
37
OpFlex Enhanced Transient Stability (ETS) for GE Gas Turbines
GE Energy
1501 Roanoke Blvd.
Salem, VA 24153–6492 USA
1 540 387 7000
www.geenergy.com
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