Abstract:
A power generating system wherein a variable speed turbine is mounted on top of a tower or tethered underwater. The reactive component of turbine generated electrical power is corrected automatically through electronic switched power-factor capacitor banks that are divided into sub-system modules coupled to a central turbine park sub-station. The sub-system modules are of a fixed size and are easily adaptable to different turbine generator types, sizes and groupings. By employing SCR switched power factor capacitors grouped in sub-system modules of fixed size, coupled to a central turbine park sub-station, the converter allows fast, real time control of the utility interconnected power line voltage or power factor.

Description:
BACKGROUND OF THE INVENTION 
     1. Field of the Invention 
     This invention relates to electric power-generating devices, such as wind turbines and ocean current turbines, and more particularly to an apparatus for correcting the reactive component of wind or water generated electrical power through electronic switched capacitor banks. 
     2. Description of the Prior Art 
     Wind power and tidal action in the oceans produce mechanical energy that can be captured to make electricity. Because wind and ocean energy is abundant and non-polluting, and are renewable energy sources, efforts are underway to make both wind and ocean energy economically competitive with fossil fuels and nuclear energy. Wind turbines are arrayed on land in rows where wind currents are steady, called wind farms. Tidal turbines are similar to wind turbines and would be arrayed underwater in rows, called tidal turbine farms. 
     Wind turbines and tidal turbines, when operating with standard induction generators, achieve output power with a lagging current with reference to the voltage. Those wind and tidal turbines with output corrected to unity will also have a lagging current with reference to the voltage at the sub-station or distribution collection point within the wind farm or tidal turbine farm. A load that tends to cause the current to become out of phase with the voltage is called a reactive load. Reactive loads are measured in Volt-Ampere Reactive units (VARs). When the current and voltage are exactly in phase this is called a unity power factor. In order to provide a power factor of unity to a utility power grid, compensation must be provided to pull the current back in phase with the voltage. This compensation must have an ability to select the number of VARs necessary to precisely compensate for the VARs introduced by the turbines and thereby bring the current and voltage in phase. The mathematical relationships between reactive power, apparent power and real power are shown by the following formulas:
 
Apparent Power=Volts×Amperes
 
True Power=Volts×Amperes×the cosine of the phase angle between volts and amps.
 
Reactive Power=Volts×Amperes×the sine of the phase angle between volts and amps.
 
     The relationships between apparent, true and reactive power are represented by a standard trigonometric function in  FIG. 5 . 
     Utilities and power producers have employed various methods of reactive power compensation for decades. These include correction through the generator at the generation source; correction through the use of synchronous condensers; correction through the use of contactor-switched capacitors; correction through Static VAR Compensators (SVC&#39;s); and correction through Static Synchronous Compensators (STATCOMS). These five methods are described below. 
     Correction Through the Generator at the Generation Source 
     Through their field exciters, synchronous generators have the ability to provide reactive power. Both automatic and manual controls are available to employ this reactive component to regulate line voltage, provide a fixed power factor or provide a fixed VAR (volt-ampere reactive) load for the distribution grid. 
     Induction generators, rectified synchronous generators and rectified permanent magnet generators employing solid state power electronics can also provide reactive power for line compensation. 
     When synchronous generators are corrected through their exciter, or when power electronics are employed with induction generators, the generators themselves must be capable of providing reactive power. This becomes a capital expense as the cost of the generator increases due to the increase in current requirements for the reactive load. Solid state power electronics costs also increase as the reactive load increases. 
     The response speed of these systems can be quite fast, on the order of ten&#39;s of milliseconds. They also offer excellent short-term capacity to help provide stability to the power distribution system. 
     Correction Through the Use of Synchronous Condensers 
     All synchronous machines (both motors and generators) are capable of generating reactive power. A synchronous condenser is simply a synchronous motor with its exciter tied to a control system to provide reactive power for a distribution grid. These are often modeled as generators with no prime mover, powered by the grid. As a motor they require real power or about 3% of the machines reactive-power rating. Therefore they are relatively inefficient, have a high capital cost and are expensive to operate and maintain. Despite these drawbacks, they are quite effective in maintaining line stability. Prior to the days of solid state power electronics they were quite popular as a means of reactive compensation for utility grids. 
     Correction Via Contactor-Switched Capacitors 
     A common method of reactive support is through mechanical contactor-switched capacitor banks. These are used on many wind farm applications where induction generators are used. Because the induction generator absorbs reactive power, the line voltage will drop as the output power from the wind farm increases (due to wind). Since capacitors generate reactive power without significant real-power losses or operating expense, they are attractive as compensation for induction generator systems. 
     Capacitor banks are usually stages in steps allowing for line voltage control as the power output of the wind farm changes. The use of contactors limits the switching times to no more then once per cycle, while the capacitors are limited in their re-connection capability due to requirements for discharge prior to re-connection. Contactor-switched capacitor banks are therefore quite slow in response to line voltage changes. 
     Non-wind farm applications employ both capacitors and inductors (called reactors) to allow for both absorption and generators of reactive power at the utility distribution level. 
     Capacitor banks do not have the ability to provide short-term generator support during fault or low line voltage conditions. They are also relatively expensive since most are designed for operation at medium and high voltage distribution levels. 
     Correction Through Static VAR Compensators (SVC&#39;s) 
     A Static VAR (volt-ampere reactive) Compensator or SVC is the name given to the combination of conventional capacitors and inductors with a fast solid state switch. Such systems can provide an automatic means of fast reactive support and line voltage control. 
     Passive Reactive components do not have the ability to provide short-term generation support during fault or low line voltage situations. They are also expensive since most are designed for operation at medium and high voltages distribution levels. 
     Correction Through Static Synchronous Compensators (STATCOMS) 
     The advent of fast, transistor based, power conversion electronics has allowed for the development of a system that synthesizes the reactive nature of both inductors and capacitors. These systems normally employ Pulse Width Modulated (PWM) Insulated Gate Bipolar Transistor (IGBT) inverters with DC links that allow not only power factor control but also short-term generation and substantial fault ride-through capability. 
     Like the SVC, these systems can provide very fast and effective distribution line voltage control. Like the SVC they are also relatively expensive. 
     In wind farm or tidal turbine farm applications wherein the turbine generators operate at a power factor of unity or less and do not have a method of power factor correction at the generator, there is a drop in the distribution line voltage as the power output of the farm increases due to increased wind speed or water current. Even in those turbines whose full power output is corrected to a unity power factor, a line voltage drop still occurs due to the impedance of the collector system transformers. 
     What is needed is a fast, real time control of the utility interconnected power line voltage or power factor in wind or water turbine applications where the turbine generators operate at a power factor of unity or less and do not have a method of power factor correction at the generator. 
     It is also desirable to provide a modular control system that is adaptable to different wind or water turbine generator types, sizes and groupings. 
     SUMMARY OF THE INVENTION 
     The present invention relates to a system for correcting the reactive component of wind or water generated electrical power in a power generating system. In such a system a turbine is mounted on a structure (such as a tall wind tower or a tethered underwater nacelle) that is held stationary in the horizontal axis with reference to the fluid flow. 
     A number of subsystem modules are provided. Each subsystem module includes a sub-system control designed to switch power factor capacitors on and off a low voltage line that is, in turn, coupled to a pad mounted transformer for connection to a medium voltage distribution system. These subsystem modules communicate with a central computer system that measures the incoming sub-station line voltage to determine the amount of capacitance necessary to hold this line voltage at its pre-determined set point. Alternately, the central computer system may be set to a pre-determined power factor instead of voltage. In this mode, the amount of capacitance is determined and selected through the same communication system as the voltage mode. A Proportional Integral Derivative controller is used to determine the necessary reactive power required. A divider is used to determine the amount of reactive power for each of the sub-systems. Communication is provided by a fiber-optic serial connection between the sub-systems and the central computer system. 
     The sub-system controls and central computer system operate as a standard feedback control system to regulate either line voltage or line power factor. The sub modules operate much like a fast Static VAR Compensation system except that they do not contain inductors, but capacitors only. 
     The invention has the advantage that by employing SCR switched power factor capacitors grouped in sub-system modules of fixed size, coupled to a central sub-station monitor system, fast, real time control of the utility interconnected power line voltage or power factor is achieved. 
     The invention also has the advantage that the division of the switched capacitor banks into modules of a fixed size makes them easily adaptable to different wind or water turbine generator types, sizes and groupings. 
     The invention also has the advantage of field placement within the wind park. Such placement of a distributed VAR correction system allows better control of the overall wind turbine or water turbine generation voltage because the correction is closer to their generators than when placed at a central sub-station. When all of the reactive control is located at the sub-station, precise control of the output voltage at the sub-station is easily achieved at the expense of a rise in voltage at the turbine due to the reactive nature of the wind turbine collector system. When located in the field, the distance between the turbines and their associated reactive compensation network is reduced, thereby providing better voltage regulation at the turbine while still achieving voltage regulation at the sub-station. 
    
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
       The invention will be described in detail with reference to the drawings in which: 
         FIG. 1  is a block diagram of a system for correcting the reactive component of wind or water generated electrical power in a power generating system in which the invention is embodied; 
         FIG. 2  is a block diagram of the Distributed Static VAR Compensation (DSVC) sub-system module shown in  FIG. 1 ; 
         FIG. 3  is a block diagram of the wind/tidal turbine farm substation shown in  FIG. 1 ; and, 
         FIG. 4  is a more detailed block diagram of the watt &amp; VAR transducer and PLC or embedded controller shown in  FIG. 3 ; and, 
         FIG. 5  is a diagram illustrating the relationship between apparent, true and reactive power represented by a standard trigonometric function. 
     
    
    
     In these figures, similar numerals refer to similar elements in the drawings. It should be understood that the sizes of the different components in the figures may not be to scale, or in exact proportion, and are shown for visual clarity and for the purpose of explanation. 
     DESCRIPTION OF THE PREFERRED EMBODIMENTS 
     Refer to  FIG. 1 , which is a block diagram of a system for correcting the reactive component of wind or water generated electrical power in a power generating system in which the invention is embodied. Wind turbines mounted on top of a tower or tidal turbines tethered underwater generate electrical power that varies with fluctuations in wind speed or water current, or the fluid flow of wind or water past the turbine blades. The turbine generators operate at a power factor of unity or less and do not have a method of power factor correction at the generator. Under these conditions there is a drop in the distribution line voltage as the power output of the turbines increases due to increased wind speed or increased water current. 
     Within the broken lines of logic blocks  100  and  102  are groups of wind or water turbines connected by their own transformers (XFMRS) through a medium voltage collector system to a wind park sub-station  114 . Each group of turbines includes single turbines having at least one blade mounted on a rotatable shaft. Each individual turbine within the group also has a multiphase generator or generators having a stator and a rotor coupled to the rotatable shaft for rotation therewith. The generators employed for the turbines connected in  100  and  102  are induction generators that have a lagging power factor. The generators are each connected through a distribution transformer (such as XFMR  107  and XFMR  110 ) to the medium voltage collector system  109  that connects to the sub-station  114 . Nominal voltage output of these generators is shown in  FIG. 1  as 600 Volts but may be 240, 380, 480, 575 or 690 volts AC, each a standard voltage for wind turbines. The wind park utility connection,  116  is usually a high voltage of 66 kV, 138 kV, 230 kV or other standard voltage values depending upon the transmission line requirements. DSVC Sub-System modules  104  and  106  are used to correct the lagging power factor of the generators with commands received from their respective communication connections  118 , which originate at the sub-station,  114 , where the power distribution grid is measured by a central computer system. The central computer system measures an incoming sub-station line voltage  115  to determine the amount of capacitance necessary to either (1) hold this line voltage at a pre-determined set point or (2) hold the power factor at a pre-determined power factor set by the central computer  314  within the sub-station  114 . The amount of capacitance is selected through a fiber-optic serial connection  118  between the substation  114  and the subsystem modules  104 ,  106 . 
     Refer to  FIG. 2 , which is a block diagram of a typical Distributed Static VAR Compensation (DSVC) sub-system module  104  shown in  FIG. 1 . A switched capacitor bank within the sub-system module  104  of  FIG. 1  is shown in  FIG. 2 . The internal logic of sub-system module  106  shown in  FIG. 1  is the same as sub-system module  104 . The Silicon Controlled Rectifiers (SCR) are shown at  200 , with a single capacitor shown at  202 . Although only three banks of SCRs and capacitors are shown, typical systems have 8 to 12 banks allowing for fine selection of power factor or voltage regulation in incremental steps. The total VAR capacity of each DSCV sub-system module is determined by the collector system impedance and the reactive power output of the turbines themselves. Typical values range between 0.3 and 2.5 MVARs. The output  105  of the switched capacitor bank sub-system is applied through a pad-mounted transformer  108 . The output  109  of transformer  108  is the distribution system voltage and although shown as 34 kV other voltages are workable including 12 kV, 13.2 kV, and 24 kV. 
     Control of the SCR switches is provided by subsystem controller  204 . This subsystem controller  204  communicates with the turbine park substation  114  via a fiber optic communication system  118 , which is also connected to the next DSCV subsystem  106 , shown in  FIG. 1 . Although only two sub-system modules  104  and  106  are shown in  FIG. 1 , many more modules can be added to achieve the VAR level required for proper voltage or power factor regulation. A typical 100 MW wind farm, employing induction generators with 0.97 power factor would require about 25 MVAR of support to achieve unity power factor at the sub station. This would require about 10 individual 2.5 MVAR sub-system modules. 
     The overall central control system is located inside the turbine park sub-station  114  shown in  FIG. 3 . For clarity, only one phase of the three-phase medium voltage collector system  109  is illustrated in  FIG. 3 . Although only one main power transformer is shown at  300 , two or more transformers may be employed. For each main utility interface transformer  300 , a single watt &amp; VAR transducer,  306 , is used to determine the overall wind/tidal farm power, reactive power, line voltage and current. The transducer  306  is connected to the utility line  115  via a transformer  302  to sense voltage value. A current transformer (CT 1 )  305  via a connection  304  is provided to sense current value. Only one phase is shown in  FIG. 3 . These values are sent to the Programmable Logic Controller (PLC) or Embedded Controller  310  over communication bus  308 . The controller  310  determines the difference between the required voltage or power factor set point and the actual measured value. A user interface is provided by an industrial personal computer (PC),  314 , which communicates with the controller  310  over a bus  312 . 
     As shown in  FIG. 3  the embedded controller or a Programmable Logic Controller (PLC),  310 , receives the output  308  of the watt transducer  306 . This data contains utility line voltage, current, power and reactive power. 
     Refer to  FIG. 4 , which is a more detailed block diagram of the watt &amp; VAR transducer and PLC or embedded controller shown in  FIG. 3 . Note that all three phases  115  of the utility high voltage distribution line are illustrated, as are all three current sense lines  400  and all three voltage sense lines  402 . The PLC  310  determines the difference between the line voltage commanded  403  and the line voltage measured  308  through an error amplifier  404 . The error output  405  is applied to a Proportional, Integral, Derivative (PID) real-time control controller  406  for determination of the necessary reactive power required to keep the line voltage or power factor within its commanded set point. This value is then sent to a distribution divider,  408  which simply divides the VAR requirement by the number of sub-systems to obtain the VAR requirement at each sub-system module. The sub-system controller  204  within the sub-system module  104  determines the number of capacitors that are needed to achieve the required VAR level for sub-system module  104 . Similarly, a sub-system controller within the sub-system module  106  determines the number of capacitors that are needed to achieve the required VAR level for sub-system module  106 . 
     This automatic control system maintains the line voltage or power factor by direct measurement of those values through the transducer,  306  and its associated current sensors CT 1 , CT 2  and CT 3  and potential transformers PT 1 , PT 2  and PT 3 . Real time data display and modification of the set point is available through the industrial PC interface,  314 , in  FIG. 3 . 
     SUMMARY 
     A voltage or power factor method and apparatus has been described with reference to a wind or current power generating system for providing power to a power distribution grid  116 . A substation  114  includes a central computer connected to the power distribution grid for determining a difference between a required voltage or power factor set point and an actual measured value of voltage or power factor. Groups of generators are connected to a medium voltage collector system  109  and to the sub-station  114 . DSVC Sub-System modules  104  and  106  include power factor correction means connected to the medium voltage collector system  109  to correct a lagging power factor of the generators in response to commands received from the sub-station  114 . The central computer includes means for measuring line voltage  115  on the power distribution grid  116  to determine an amount of capacitance necessary to either (1) hold the line voltage at a pre-determined set point or (2) hold the power factor at a pre-determined power factor set by the central computer. 
     In this embodiment, the system becomes a Distributed Static VAR Compensation system or DSVC. It operates similarly to the conventional SVC systems described above, but does not employ inductors. This system is designed to operate with inductive type generator system used on utility grade wind or water turbines. These generators along with their associated transformers are highly inductive and require capacitors to correct their power factor and to help maintain the line voltage at a nominal required value. 
     The distributed nature of the sub-system modules allows a manufacturer to assemble the same size equipment regardless of the wind farm size. As the size of the wind farm increases, more modules can be added to assure a proper level of reactive power to maintain line voltage or power factor at the selected value. 
     The distributed nature of the sub-system modules allows the developer and farm construction engineers to install the sub-system modules at either the sub-station or within the farm itself. Since the output of the sub-system modules is connected to the farm&#39;s distribution system in the same fashion as the individual wind turbines, sub-system modules may be installed in the field next to a group of wind turbines. Installation in this fashion can be easier then direct installation at the sub-station due to the nature of sub-station construction, and its requirements. 
     The advantage of the distributed system is further enhanced when applied to turbines used in wind farm applications that maintain a unity power factor. The DSVC system will therefore need only one or two sub-systems to correct the effects of line and transformer reactance. In either case, turbines with unity power factor, or turbines with less then unity power factor, the DSVC can directly control the line voltage and power factor at the utility interconnection point of the wind farm. This leads to greater line stability and allows for higher levels of generation within the utility system than what would be allowed with a non-unity power factor output. 
     Other advantages of the distributed approach to this type of power factor correction is the ability of the field mounted DSVC system to help maintain line voltage regulation at both the power distribution grid and at the turbines themselves. If all of the correction is located within the sub-station then the correction may cause the voltage at the turbines to rise to unacceptable levels while correcting the line to within its required parameters. When located in the field, this correction keeps the turbines within their voltage limits, yet still corrects the line voltage to an acceptable value. 
     While the invention has been particularly shown and described with reference to preferred embodiments thereof, it will be understood by those skilled in the art that the foregoing and other changes in form and detail may be made therein without departing from the scope of the invention.