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TABLE 32
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Calculating Expected Sag Performance at a Specific Customer Site for a Given Voltage Level Voltage at monitored bus (pu) 0 023 033 038 041 042 045 048 048 05 05 05 052 052 055 057 059 059 059 06 063 063 065 065 067 067 067 07 07 072 073 076 076 077 077 078 078 079 079 08
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Fault type 3LG 3LG 3LG 2LG 2LG 3LG 1LG 2LG 3LG 3LG 1LG L-L 2LG L-L L-L 2LG L-L 3LG 2LG 1LG L-L 1LG L-L 3LG 1LG 1LG 2LG 2LG L-L 3LG L-L 2LG 3LG 1LG 3LG L-L 1LG 2LG L-L 3LG
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Faulted bus Tennessee Nevada Texas Tennessee Nevada Claytor Tennessee Texas Glen Lyn Reusens Nevada Tennessee Claytor Nevada Texas Glen Lyn Claytor Arizona Reusens Texas Glen Lyn Claytor Reusens Ohio Glen Lyn Reusens Arizona Ohio Arizona Fieldale Ohio Fieldale New Hampshire Ohio Vermont Fieldale Arizona Vermont Vermont Minnesota
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Bus voltage 132 132 132 132 132 132 132 132 132 132 132 132 132 132 132 132 132 132 132 132 132 132 132 132 132 132 132 132 132 132 132 132 33 132 33 132 132 33 33 33
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Sag type A A A C C A D C A A D C C C C C C A C D C D C A D D C C C A C C A D A C D C C A
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Voltage Sags and Interruptions 56 Three
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Estimated voltage sag performance at customer equipment due to transmission system faults FUSED LATERAL BRANCH
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3 SYSTEM SOURCE SUBSTATION 2 FEEDERS
1 RECLOSING BREAKERS
LINE RECLOSER
Typical distribution system illustrating protection devices
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Voltage Sags and Interruptions Voltage Sags and Interruptions 57
Feeder reactors, if any Average feeder fault performance which includes three-phase-lineto-ground (3LG) faults and single-line-to-ground (SLG) faults in faults per mile per month The feeder performance data may be available from protection logs However, data for faults that are cleared by downline fuses or downline protective devices may be difficult to obtain and this information may have to be estimated
There are two possible locations for faults on the distribution systems, ie, on the same feeder and on parallel feeders An area of vulnerability defining the total circuit miles of fault exposures that can cause voltage sags below equipment sag ride-through capability at a specific customer needs to be defined The computation of the expected voltage sag performance can be performed as follows:
Faults on parallel feeders Voltage experienced at the end-user facility
following a fault on parallel feeders can be estimated by calculating the expected voltage magnitude at the substation The voltage magnitude at the substation is impacted by the fault impedance and location, the configuration of the power system, and the system protection scheme Figure 311 illustrates the effect of the distance between the substation and the fault locations for 3LG and SLG faults on a radial distribution system The SLG fault curve shows the A-B phase bus voltage on the secondary of a delta-wye grounded step-down transformer, with an A phase-to-ground fault on the primary The actual voltage at the enduser location can be computed by converting the substation voltage using Table 31 The voltage sag performance for a specific sensitive equipment having the minimum ride-through voltage of vs can be computed as follows: Eparallel (vs) N1 Ep1 N3 Ep3
where N1 and N3 are the fault performance data for SLG and 3LG faults in faults per miles per month, and Ep1 and Ep3 are the total circuit miles of exposure to SLG and 3LG faults on parallel feeders that result in voltage sags below the minimum ride-through voltage vs at the end-user location
Faults on the same feeder In this step the expected voltage sag magni-
tude at the end-user location is computed as a function of fault location on the same feeder Note that, however, the computation is performed only for fault locations that will result in a sag but will not result in a momentary interruption, which will be computed separately Examples of such fault locations include faults beyond a downline recloser or a
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