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No reverse power (32) function is used at this interface because net export is expected
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50/51: overcurrent relay Responsible for tripping the main breaker for faults within the generator system May also trip for faults on the utility system that the generator feeds Therefore, the time delay must be coordinated with the other relays so that it does not trip inadvertently 46 relay at transformer: negative-sequence current Assists in the detection of faults on the utility system, particularly open-phase conditions, and trips the main breaker (Generators have a separate 46 relay) 25: synchronizing relay Controls closing of the main breaker when the generators are being interconnected to the utility (This scheme would also require synchronous check relays on the individual generators if they are to be interconnected separately)
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87G: differential ground relay For fast detection of ground faults within the generator 51G: ground overcurrent Trips the generator for high neutral currents indicative of a ground fault on the secondary system 32R: reverse-power relay This relay detects power going into the generator, which would indicate a fault Can be set very sensitive 40: loss of field relay 46: negative-sequence current Protects the machine against excessive unbalanced currents, which may result from an internal fault but may also be due to unbalance on the utility system 50/51: overcurrent relays Protects the generator against excessive loads and faults on either side of the generator breaker
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99 Summary Readers might easily get the impression from the material in this chapter that interconnecting a DG installation to the distribution system is fraught with Gordian knot like entanglement power quality problems However, few problems can be expected for most DG applications in the near future while the total penetration is relatively low There is a sig-
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nificant amount of DG that can be accommodated without affecting the operation of the distribution system, but there is a limit The grid is not infinite in capacity As a general rule, problems begin to appear when the total interconnected DG capacity approaches 15 percent of the feeder capacity11,12 This might drop to as little as 5 percent of capacity on more rural feeders or be as high as 30 percent if the DG is clustered near the substation Voltage regulation problems are often the first to appear, followed by interference with the utility fault-clearing process, which includes concerns for islanding Changes can be made to accommodate nearly any amount of DG As the amount of DG increases, the simple, low-cost distribution system design must be abandoned in favor of a more capable design It will almost certainly be more costly, but engineers can make it work Deciding who pays for it is another matter In a future of massively distributed generation, as some see it, communications and control will be key Today, most of the control of distribution systems is accomplished by local intelligence operating autonomously Systems with high penetrations of DG would benefit greatly from fast, interconnected communications networks This is one technology shift that must accompany the spread of DG if it is to be successful in contributing to reliable, high-quality electric power 910 References
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1 H L Willis and W G Scott, Distributed Power Generation Planning and Evaluation, Marcel Dekker, New York, 2000 2 N Jenkins, R Allan, P Crossley, D Kirschen, G Strbac, Embedded Generation, The Institute of Electrical Engineers, London, UK, 2000 3 W E Feero, W B Gish, Overvoltages Caused by DSG Operation: Synchronous and Induction Generators, IEEE Transactions on Power Delivery, January 1986, pp 258 264 4 R C Dugan, D T Rizy, Harmonic Considerations for Electric Distribution Feeders, ORNL/Sub/81-95011/4, Oak Ridge National Laboratory, US DOE, March 1988 5 IEEE Standard 929-2000, Recommended Practice for Utility Interface of Photovoltaic Systems 6 R C Dugan, T E McDermott, Operating Conflicts for Distributed Generation on Distribution Systems, IEEE IAS 2001 Rural Electric Power Conference Record, IEEE Catalog No 01CH37214, Little Rock, Ark, May 2001, Paper No 01-A3 7 Electrical Distribution-System Protection, 3d ed, Cooper Power Systems, Franksville, Wis, 1990 8 R H Hopkinson, Ferroresonance Overvoltage Control Based on TNA Tests of Three-Phase Delta-Wye Transformer Banks, IEEE Transactions on Power Apparatus and Systems, Vol 86, No 10, October 1967, pp 1258 1265 9 D R Smith, S R Swanson, J D Borst, Overvoltages with Remotely-Switched Cable-Fed Grounded Wye-Wye Transformers, IEEE Transactions on Power Apparatus and Systems, Vol PAS-94, No 5, September/October 1975, pp 1843 1853 10 IEEE Standard P1547, Distributed Resources Interconnected with Electric Power Systems, Draft 8, P1547 Working Group of IEEE SCC 21, T Basso, Secretary
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