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Even though synchronous machines use old technology, are common on power systems, and are well understood, there are some concerns when they are applied in grid parallel DG applications They are the primary type of electric machine used in backup generation applications With proper field and governor control, the machine can follow any load within its design capability The inherent inertia allows it to be tolerant of step-load changes While this is good for backup power, it is the source of much concern to utility distribution engineers because this technology can easily sustain inadvertent islands that could occur when the utility feeder breaker opens It also can feed faults and possibly interfere with utility overcurrent protection Unless the machines are large relative to system capacity, interconnected synchronous generators on distribution systems are usually operated with a constant power factor or constant var exciter control For one thing, small DG does not have sufficient capacity to regulate the voltage while interconnected Attempting to do so would generally result in the exciter going to either of the two extremes Secondly, this avoids having the voltage controls of several small machines competing with each other and the utility voltage regulation scheme A third reason this is done is to reduce the chances that an inadvertent island will be sustained A nearly exact match of the load at the time of separation would have to exist for the island to escape detection It is possible for a synchronous machine that is large relative to the capacity of the system at the PCC to regulate the utility system voltage This can be a power quality advantage in certain weak systems However, this type of system should be carefully studied and coordinated with the utility system protection and voltage regulation equipment It would be possible to permit only one generator on each substation bus to operate in this fashion without adding elaborate controls The generation will likely take over voltage regulation and can drive voltage regulators to undesirable tap positions Conversely, utility voltage regulators can drive the generator exciter to undesirable set points To ensure detection of utility-side faults when the interconnected generator is being operated under automatic voltage control, many utilities will require a direct transfer trip between the utility breaker and the generation interconnection breaker One aspect of synchronous generators that is often overlooked is their impedance Compared to the utility electrical power system, generators sized for typical backup power purposes have high impedances The subtransient reactance Xd , which is seen by harmonics, is often.



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for new documents It s a font that s acceptable in business and personal documents; it s highly legible, photocopies well, and is web-safe, meaning that browser software (Internet Explorer or Netscape) happily displays it

Figure 7-4

Downloaded from Digital Engineering Library @ McGraw-Hill (wwwdigitalengineeringlibrarycom) Copyright 2004 The McGraw-Hill Companies All rights reserved Any use is subject to the Terms of Use as given at the website

View buttons FIGURE 4-1

The output of the traceNode() function provides a concise description of the properties of a given node For example, consider a node represented by an unordered list:

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about 15 percent of the machine s rating The transient reactance, Xd , which governs much of the fault contribution, might be around 25 percent The synchronous reactance Xd is generally over 100 percent In contrast, the impedance of the power system seen from the main load bus is generally only 5 to 6 percent of the service transformer rating, which is normally larger than the machine rating Thus, end users expecting a relatively seamless transfer from interconnected operation to isolated backup operation are often disappointed Some actual examples of unexpected consequences are 1 The harmonic voltage distortion increases to intolerable levels when the generator is attempting to supply adjustable-speed-drive loads 2 There is not enough fault current to trip breakers or blow fuses that were sized based on the power system contribution 3 The voltage sag when elevator motors are being started causes fluorescent lamps to extinguish Generators must be sized considerably larger than the load to achieve satisfactory power quality in isolated operation Another aspect that is often overlooked is that the voltage waveform produced by a synchronous machine is not perfect In certain designs, there are considerable third-harmonic currents in the voltage Utility central station generation may also have this imperfection, but the delta winding of the unit step-up transformer blocks the flow of this harmonic The service transformer connection for many potential enduser DG locations is not configured to do this and will result in high third-harmonic currents flowing in the generator and, possibly, onto the utility system This is discussed is greater detail in Sec 95 The net result is that synchronous generators for grid parallel DG applications should generally be designed with a 2/3 winding pitch to minimize the third-harmonic component Otherwise, special attention must be given to the interface transformer connection, or additional equipment such as a neutral reactor and shorting switch must be installed.

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The traceObject() function performs almost the same function as traceNode(), but with generic JavaScript objects The source for the function is shown in Listing 7-5

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In many ways, it is simple to interface induction machines to the utility system Induction generators are induction motors that are driven slightly faster than synchronous speed They require another source to provide excitation, which greatly reduces the chances of inadvertent islanding No special synchronizing equipment is necessary In fact, if the capacity of the electrical power system permits, induction generators can be started across the line For weaker systems, the prime mover is started and brought to near-synchronous speed before the machine is interconnected There will be an inrush transient upon clo-

Listing 7-5

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