GE Position Sensors on Power Gen Turbines
How they work and how to use them with a third-party LVDT signal conditioner designed specifically for Power Gen Applications
LVDTs (Linear Variable Differential Transformers) are very commonly used as position sensors in power plants throughout the world. Working from AC voltages and frequencies not available from power lines, LVDTs require a signal conditioner to provide the necessary operating power. Alliance Sensors Group's model S1A module, designed specifically to be used in power gen applications, is considered by many power gen users be the most advanced and easy to use single channel LVDT signal conditioner on the market today. It can operate practically any inductive or LVDT-type position sensor currently in use.
However, users and systems integrators can be confused by unusual LVDT configurations, particularly in regard to the General Electric 185A1328 and 311A5178 series of LVDTs typically used with their gas turbines. Furthermore, for many years, GE has been using a contactless position sensor known as an inductive half-bridge for measuring the position of the operating shafts of steam turbine control valves. These sensors, often called VRTs or LVRTs, are used to provide position feedback from modulating throttle and governor valves, as well as to give open or closed condition feedback from bypass, stop, and interceptor valves. They are also used to monitor valve position on some turbine feedwater pumps. Some typical GE half-bridge part numbers include the 119C9638, 119C9639, and 196C8768 series. Again, there is some confusion among many systems integrators about how to connect these GE half-bridge sensors to an LVDT signal conditioner and how to calibrate them. This application note should dispel much of the confusion around the operation of both GE LVDTs and inductive half-bridge sensors.
Operating GE Gas Turbine LVDTs with an ASG S1A LVDT Signal Conditioner
This application note shows how these GE LVDTs differ from conventional LVDTs and how to operate them with an S1A LVDT signal conditioner module. To understand the differences between GE Gas Turbine LVDTs and conventional LVDTs, it is important to review the characteristics of an ordinary LVDT. Regardless of the method of construction actually used to make a conventional LVDT, it has a primary winding and two identical secondary windings that are usually connected in series opposition as shown in Figure 1 below.
The electrical output of a typical LVDT as a function of its core's position is shown in Figure 2 below. Note that the plot of its AC output amplitude versus position shows the classical "V" shape usually associated with an LVDT, with a minimum value called null at the center of its range of motion, and an increased output amplitude for core positions on either side of null. More important is the fact that the phase relationship of the differential AC output to the primary input voltage shifts abruptly by 180 ° as the core moves through null. It is this 180 ° phase shift that permits a user to know on which side of null the core is positioned. The voltages and frequency shown are typical of those found in the operation of a conventional LVDT. It is important to note that the actual excitation voltage utilized makes very little difference to an LVDT's performance. Only the excitation frequency is important for proper operation.
The configuration of the LVDTs used by GE for various position sensing functions on their gas turbines is shown in Figure 3 below. While the most obvious difference is the tap on the primary, it does not otherwise seem to be much different from a conventional LVDT, but its electrical operation is extremely different. Although it is tempting to view it as a center tap, it is not a center tap at all. Most often it is a 30% tap, but, depending on the model, it can sometimes be a 25% tap. The voltages shown are typical of those used by GE, but, as noted above, the device is a transformer and will function with whatever AC voltage is used to operate it. For the sake of clarity, typical GE values are used for the explanation of how this variety of LVDT works.
This LVDT hookup is generally known as a "Buck-Boost" configuration. As can be seen in Figure 3, the voltage appearing at the tap is 30% of the excitation voltage being applied to the LVDTs primary, and is in phase with the primary voltage. The way the windings are connected, this 30% voltage, e tap, is being added to the differential secondary voltage, which consists of e1, which is in phase with the primary voltage, to which has been added e2, which is 180 ° out of phase with the primary voltage. The turns ratio of these GE LVDTs is usually about 5:1, so, with a 7.07 V ACrms input, the full scale output of the secondaries, without the effect of the 30% tap, would be about 1.4 V ACrms, either in phase with the primary excitation or 180 ° out of phase with it. However, the 30% tap inserts an additional 2.1 V ACrms that is in phase with the primary excitation to be added to the voltages already in the secondaries. The result is plotted in Figure 4, which shows that the total AC output from the series connection of the two secondaries and the 30% tap is a voltage between 0.7 to 3.5 V ACrms, with no 180 ° phase shift as the LVDT's core moves from one end of its range of motion through null to the other end of its range.
The electronics used by GE in their controllers requires this unusual AC output, but almost all these "Buck-Boost" LVDTs can be successfully operated with an ASG S1A signal conditioner module by using the proper connection configuration. The first thing to do is to ignore any connection to the primary tap. Instead, connect the LVDT in a 3-wire configuration as shown in the S1A instruction manual. In this configuration, the high end of the primary is connected to J1-1, the common connection of the primary and the series-connected secondaries is connected to J1-3, and secondaries' high output is connected to J1-4. A 3-wire configuration of an S1A only applies 1/2 of the usual input voltage to the primary, so it is good practice to shift jumper J7 over to increase the excitation output to the LVDT's primary by 50%. After this 3-wire connection for a "Buck-Boost" LVDT has been completed, the S1A can be operated and the LVDT calibrated in the normal manner shown in the module's manual.
Operating GE Inductive Half-bridge Position Sensors with an S1A Signal Conditioner
First, it is necessary to understand how GE half-bridge sensors function. Figure 5 shows the schematic of a typical GE half-bridge sensor. Note that pins D and E play no role in the operation of the sensor, but are merely part of an "interrupt jumper" system which is used to notify the turbine control system that the connector has been removed. As shown in the schematic, the sensor consists of two identically wound inductor coils connected in series that have a permeable core long enough to overlap a portion of each coil. An AC voltage (Ein) is applied to pins A and C. If the core is located symmetrically between the coils, each coil has the same impedance, resulting in an Eout between pins B and C that is 1/2 of Ein.
If the core is moved to include more of the coil connected between pins A and B, the inductance, and therefore the impedance, of that winding will increase, while the inductance, and hence the impedance, of the coil connected between pins B and C will decrease. The result will be a drop in the voltage Eout. If the core were moved in the other direction, the reverse action would happen and Eout would increase.
The shaded symmetrical areas represent the different output levels developed by different sensors. Several things stand out in Figure 6. First is that the output at mid-range is not zero as with an LVDT, but is half of the AC excitation. Second, there is no 180 degree phase shift at "Null" as with an LVDT. These features specifically facilitate interfacing sensors with GE's Mark 2 - 6 turbine control systems.
There are two other very important points of note in the operation of half-bridge sensors, both of which concern the excitation of the sensors. First, the magnitude of the AC excitation voltage has no bearing on the functioning of these sensors. The choice of 7.07 Vrms (20 V p-p) by GE is merely dependent on the requirements of their control system. Second, the excitation frequency was chosen to make sure the impedance of the two windings is dominated by their inductive reactance at the chosen frequency, so that the DC resistance of the windings has a fairly small overall effect on the winding impedances.
When looking at Figure 6, it is easy to understand why it can be unduly difficult to set up and calibrate these GE half-bridge position sensors in the field. The primary reason is that a half-bridge sensor does not have a uniquely identifiable point in its range of motion like an LVDT's null point. Fortunately, ASG's S1A LVDT signal conditioner was designed not merely to work with inductive half-bridges, but to make their operation emulate that of an LVDT. Thus, anyone familiar with the techniques for calibrating an LVDT position sensor installed in a valve position feedback system using an S1A module will be able to utilize those very same techniques to calibrate a GE half-bridge sensor connected to an S1A module. Figure 7 below shows that a GE inductive half-bridge connected to an S1A signal conditioner displays exactly the same type of AC output as would be developed if the S1A were connected to an LVDT.
When using an S1A with a half-bridge sensor, the front panel LEDs function in the same way during calibration as if it were an LVDT, as does the Null Output voltage available at J4-1 and J4-2. While this application note has focused on the GE half-bridges used in power plants, these same considerations apply to using an S1A or any of its derivative signal conditioner products with any half-bridge sensor.
The connection diagram for hooking up GE half-bridges to an S1A signal conditioner module is shown above. Hook up the GE half-bridge connector's pins to the numbers on the black plug, J1, as follows: Pin A goes to J1-1, pin B goes to J1-4, and pin C goes to J1-2. Pins E and F are not connected to the S1A at all. If the directional sense of the S1A's analog output is reversed from the desired output, either interchange the connections to J1-1 and J1-2, or flip the INVERT switch, DS2-3, inside of the S1A.
Using 60 Hz GE Half-bridge Sensors with an ASG S1A signal conditioner in Steam Power Plants
This treatise was based on the most common GE half-bridge sensors likely to be found in power plants today, all of which operate at 3 kHz. However, early on, GE used some half-bridge sensors that were operated with 24 Volts AC at 60 Hz and some even used 115 Volts AC, 60 Hz. Systems integrators and utilities should both be aware of the risks of continuing to use a 50-year old design of 60 Hz operated GE half-bridges instead of the newer 3 kHz operated sensors. These 60 Hz units do not utilize much ferromagnetic material beyond their core so their windings have fairly low inductance. As a result, their impedance is largely based on the resistive component of their windings. Much of the AC input power gets dissipated in the resistance of these windings, so these sensors tend to get hot during operation.
Because of the effects of thermal expansion and contraction on the windings, these 60 Hz units have a history of developing intra-winding shorts, but which do not immediately show up in significant output changes because there are so many turns of wire on each winding. Furthermore, their output linearity is also poor to begin with, typically ± 2% at FSO, and ± 5% at 110% of FSO, which often initially masks the effects of any such internal shorts. But over a period of time, the number of internal winding shorts can and often does increase, causing a net calibration shift that could result in a significant output error.
Despite these issues, some integrators have had success operating old 60 Hz GE half-bridge sensors with an ASG S1A LVDT signal conditioner by operating them with the S1A's 1 kHz excitation frequency. Typically, those integrators have utilized old stock of unused spares or ordered new units built to the old design, mostly because their utility customers are reluctant to change sensors over to newer, more reliable products, particularly in nuclear power plants, because of issues with certifications, testing, and related documentation. Even so, it is important to bear in mind that these 60 Hz sensors utilize an obsolete 1960s design, and that contactless inductive position sensing technology and reliability have improved substantially in the intervening half century.
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