IEEE Electrification Magazine - December 2015 - 54
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The North China-Central ChinaEast China Power Grid
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1,000 kV Substations
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500 kV Substations
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1,000 kV Transmission Lines
500 kV Transmission Lines
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Figure 1. The Sanhua UHV grid, planned for 2020.
component. The largest value of the northward component was 0.8896 V/km, while that of the eastward component was 0.3026 V/km. This means that the GIC problem in mid- and low-latitude areas is different from that
in high-latitude areas, at least in terms of the driving
source and characteristics of ionospheric disturbance.
The conclusion that GIC is larger in eastward transmission lines than in northward lines, unfortunately, does
not hold in mid- and low-latitude areas. Moreover, in GIC
risk assessment for power grids in mid- and low-latitude
areas, the possibility of GIC induction in northward and
eastward transmission lines should be considered equal;
in other words, the direction where the transmission line
is headed has nothing to do with GIC induction. Also, the
calculation of geoelectric-field intensities in Xibei,
Guangdong, and Jiangsu have all resulted in horizontal
components close to 1 V/km, and the geomagnetic storm
in November 2004 was not the strongest one in the 23rd
solar cycle. Therefore, the research team proposed a geoelectric-field value of 1 V/km for GIC risk assessment in
the UHV power grid in China.
As for the 1,000-kV power grid, it is noted that transmission lines in a 1,000-kV power grid use 500-mm2 eightbundle conductors, which is different from those of the
500-kV power grid. Figures 3 and 4 show, respectively, the
transmission lines and the conductors used in a 1,000-kV
54
I E E E E l e c t r i f i cati o n M agaz ine / december 2015
power grid. The 500-mm2, eight-bundle conductor has a
resistance per unit length of 0.007265 Ω/km. Assuming
that all conductors in the same voltage level have the
same resistance per unit length and that the geoelectric
field intensity is 1 V/km, we established a GIC calculation
model of the grid shown in Figure 1 that consists of the
UHV network and the 500-kV network connected with
UHV substations. In this model, the GIC Benchmark,
which was developed jointly by the Electric Power
Research Institute, Natural Resource Canada, the University of Illinois Urbana-Champaign, and the Finnish Meteorological Institute, was adopted (Horton, 2012). We arrived at
the calculation result of GIC values in the UHV grid and
500-kV grid, which also provided us with insight into the
influence of GIC from the 500-kV grid on GIC in the 1,000-kV
substations (Guo, 2015).
The result revealed a tangible influence of GICs in
transformer neutral points in 500- and 1,000-kV substations when GICs in 500- and 1,000-kV transmission lines
interact with GICs in 1,000-kV transformer neutral
points. This causes the GICs to increase in transformer
neutral points in some substations but decrease in others. Overall, however, it is the GICs in transmission lines
in the highest voltage level that determine the overall
GIC level in transformer neutral points, i.e., transmission
line resistance is the determining factor. It should be
Table of Contents for the Digital Edition of IEEE Electrification Magazine - December 2015
IEEE Electrification Magazine - December 2015 - Cover1
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