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ANNA UNIVERSITY: CHENNAI -600 025
B.E/B.TECH DEGREE EXAMINATIONS NOV/DEC 2015
(B.E. ELECTRICAL AND ELECTRONICS ENGINEERING)
SEVENTH SEMESTER
REGULATIONS : R-2008
EE2404- Power System Simulation Laboratory
Time 3 Hours Max: 100 Marks
1. Develop a program to obtain bus admittance matrix Y‐bus of the given power
system. Use any suitable assumptions
G1 G2
T1 T2
1 2
0.1+0.3j 0.15+0.5j
0.02j
0.2+0.6j
0.028j 0.0125j
3
Line Starting Ending Series Line Number Bus Bus Line Changing
Impedance Admittance
1 1 2 0.1+0.3j 0.02j 2 2 3 0.15+0.5j 0.0125j 3 3 1 0.2+0.6j 0.028j
Figure 1 Table 1
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2. An isolated power station has the following parameters Turbine time constant, τT = 0.5sec, Governor time constant, τg = 0.2sec Generator inertia constant, H = 5sec. Governor speed regulation = R per unit
The load varies by 0.8 percent for a 1 percent change in frequency, i.e, D =
0.8 Find the load frequency dynamics of the system
3. Perform load flow analysis by Newton raphson method. Use any suitable assumptions
Line Starting Bus Voltage Magnitude Angle Real power Reactive power No.
1 1 1.04 0 0 0 2 2 1 10.69 0 0 3 3 1.05 20 0 0
Table 4.1
G1 G2
T1 T2
G1
G1 G1
Line Starting Ending Series Line Line
Changing
No. Bus Bus Impedance
Admittance
1 1 2 0.2+0.6j 0.05j
2 2 3 0.25+0.0125j 0.035j
3 3 1 0.02+0.28j 0.015j
Figure 4 Table 4.2
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4. Develop a program to carry out simulation of a symmetrical three phase short circuit
on a given power system. Use any suitable assumptions
1
1
3
Line Starting
Ending Line
2
G1 3 No. Bus Bus Changing
G1
Admittance
2
G1
1 1
2
0.05j
G2 2 1 2 0.05j
3 1 3 0.1j
4
4 2 3 0.06j
Figure 5
Table 5.1
Transformer Data Transient
Generator Data
Gradient Reactance
Reactance
G1
0.25j
T1 0.10j
G2
0.20j
T2 0.08j
Table 5.2
Table 5.3
5. The fuel cost functions for three thermal plants in $/h are given by
C1 = 500 + 5.3 P1 + 0.004 P12 ; P1 in MW
C2 = 400 + 5.5 P2 + 0.006 P22 ; P2 in MW
C3 = 200 +5.8 P3 + 0.009 P32 ; P3 in MW
The total load , P D is 800MW.Neglecting line losses and generator limits, find the optimal dispatch and the total cost in $/h by analytical method. Verify the result using MATLAB program
6. Develop a program to obtain bus impedance matrix Z-bus of the given power system. Use
any suitable assumptions
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Figure 7
Line Starting Ending Series Line Line
Changing
No. Bus Bus Impedance
Admittance
1 1 2 0.1+0.4j 0.15j
2 2 3 0.15+0.6j 0.02j
3 2 4 0.18+0.55j 0.018j
4 3 4 0.1+0.35j 0.012j
5 4 1 0.25+0.7j 0.03j
Table 7
7.Develop a program to compute bus admittance matrix for the given power system
network. Also verify the obtained results with calculated values. Use any suitable
assumptions
Figure 8 LINE DATA:
Line Impedance Charging Admittance
Bus code
1 – 2 0.2 + j 0.8 j 0.02
2 – 3 0.3 + j 0.9 j0.03
2 – 4 0.25 + j 1.0 j 0.04
3 – 4 0.2 + j 0.8
j0.02
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1 – 3 0.1 + j 0.4 j0.01
8.Develop a program to compute bus admittance matrix for the given power system
network. Line admittance values are shown in the figure. Also verify the obtained
results with calculated values. Use any suitable assumptions
Figure 9
9.Develop a program to compute bus impedance matrix for the given power system
network shown in figure 10. Use any suitable assumptions
Generator reactance : 0.2 p.u & 0.25 p.u for G1 and G2 respectively. Transformer leakage reactance: 0.08 p.u & 0.1 p.u for T1 and T2 respectively.
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10.Develop a program to compute bus imp edance matrix for the given p ower system
network. Line imped ance values and transient reactance of generator & transformer
are in p.u is shown in the figure. 11. Use any suitable assumptions
Figure 11
11. Determine fault current, bus voltages and line flows, when short circuit fault occurs at
bus 3 for the system in figure 12 by using available soft ware. Use any suitable
assumptions
Figure 12
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12.A power system consists of two, 100 MW units, whose input cost data are represented by
the following equations:
F1 = 0.05 P12 + 20 P1 + 800 Rs/hr.
F2= 0.06 P22 + 15 P2 + 1000 Rs/hr. If the total received power P = 150 MW. What would be the division of load between the
units for the most economic operation? Assume the initial Lambda value. Also verify the
obtained result with calculated value.
13. The fuel cost of two units are given by
F1 = 0.1 P12 + 20 P1 + 1.5 Rs/hr.
F2= 0.1 P22 + 30 P2 + 1.9 Rs/hr.
If the total demand on the generation is 200 MW, find the economic load scheduling of
the two units. Assume the initial Lambda value. Also verify the obtained result with the
calculated value.
14. The fuel cost of two units are given by
F1 = 0.04 P12 + 16 P1 + 2.8 Rs/hr.
F2= 0.04 P22 + 12 P2 + 4.6 Rs/hr.
The B mn matrix is given by
0.01 ‐0.005
‐0.005 0.024
Determine the economic schedule for the incremental cost of received power of Rs
20 / MWhr. Also find a) Total generation b) Transmission losses and c) Demand. Verify
the obtained result with calculated value.
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15. Considering the two area system, find the new steady state frequency and change in tie
line flow for a load change of area two by 100 MW. Area one is operating with the spinning
reserves of 1000 MW. Area two is operating with the spinning reserves of 1000 MW.
Assume following data for the system.
Capacity of area 1, Pr1 = 1000 MW
Capacity of area 2, Pr2 = 2000 MW
Nominal load of area 1, PD1 = 500 MW
Nominal load of area 2, PD2 = 1500 MW
Regulation of area 1, R1 = 5%
Regulation of area 2 R2 = 4%
Nominal frequency Fo = 50 Hz
For both areas, each percent change in frequency causes 1% change in load. Also
verify the obtained result with calculated value.
16. For an isolated single area consider the following data:
Total rated area capacity Pr = 3000 MW
Normal operating load Pd = 2000 MW
Inertia constant H = 5 Secs
Regulation R = 2.5 Hz / p.u.M.W
Normal frequency F = 50 Hz Assume that the load frequency characteristic is linear meaning that the load will
increase 1 % for 1 % frequency increase. Find 1) Gain & Time constant of power system
and 2) Change in frequency under static condition. Also verify the obtained result with
calculated value.
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17.Develop a program to carryout load flow analysis of the given power system
network shown in figure 19 by using Gauss – Seidel method. Use any suitable
assumptions
Figure 19
BUS SPECIFICATIONS:
BUS V GENERATION LOAD
Q MIN Q MAX
BUS specified (p.u) (p.u)
NO (p.u) (p.u)
SLACK (p.u)
P
Q P Q
1 1.06 ‐ ‐
‐ ‐ ‐ ‐
2 P‐V 1.00 0.6 ‐ 0.0 0.1 ‐1.0 1.5
3 P‐Q ‐ ‐ ‐ 0.45 0.15 ‐ ‐
4 P‐Q ‐ ‐ ‐ ‐0.40 0.05 ‐ ‐
5 P‐Q ‐ ‐ ‐ 0.6 0.1 ‐ ‐
LINE DATA: LINE
SB EB SERIES HALF LINE CHARGING
NO IMPEDANCE(p.u) ADMITTANCE(p.u)
1 1 2 0.02 + j 0.06 j 0.03
2 1 3 0.08 + j 0.24 j 0.025
3 2 3 0.06 + j 0.18 j 0.02
4 2 3 0.02 + j 0.08 j 0.02
5 2 5 0.04 + j 0.12 j 0.015
6 3 4 0.01 + j 0.03 j 0.01
7 4 5 0.08 + j 0.24 j 0.035
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18.a) Write the program in transient stability analysis of Single‐Machine Infinite Bus
System by using available software. b) For a two bus explain the procedure of forming Z bus by bus building algorithm.
19.Develop a program to compute bus admittance matrix for the given power system
network shown in figure 22 Also verify the obtained results with calculated values. Use
any suitable assumptions
Figure 22
LINE DATA:
Line Impedance Charging Admittance
Bus code
1 – 2 0.2 + j 0.8 j 0.02
2 – 3 0.3 + j 0.9 j0.03
2 – 4 0.25 + j 1.0 j 0.04
3 – 4 0.2 + j 0.8 j0.02
1 – 3 0.1 + j 0.4 j0.01
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20.Develop a program to compute bus admittance matrix for the given power system
network. Line admittance values are shown in the figure. Also verify the obtained
results with calculated values. Use any suitable assumptions
Figure 23
21Develop a program to compute bus impedance matrix for the given power system
network shown in figure 24. Use any suitable assumptions
Generator reactance : 0.2 p.u & 0.25 p.u for G1 and G2 respectively. Transformer leakage reactance: 0.08 p.u & 0.1 p.u for T1 and T2 respectively.
Figure 24
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22.Develop a program to compute bus impedance matrix for the given power system
network. Line impedance values and transient reactance of generator & transformer
are in p.u is shown in the figure 25. Use any suitable assumptions
Figure 25
22.(a)Write the program in transient stability analysis of Single‐Machine Infinite Bus
System by using available software.
(b)A single phase overhead transmission line delivers 1100 kW at 11 kV at 0.8 P.F.
lagging. The total resistance and inductive reactance of the line are 8 ohm and 16 ohm
respectively. Determine a) Receiving end current. b) Sending end voltage. c) Sending
end power. d) Transmission efficiency and E) Percentage regulation.
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23.A power system consists of two, 100 MW units, whose input cost data are
represented by the following equations:
F1 = 0.05 P12 + 20 P1 + 800 Rs/hr.
F2= 0.06 P22 + 15 P2 + 1000 Rs/hr. If the total received power P = 150 MW. What would be the division of load between the
units for the most economic operation? Assume the initial Lambda value. Also verify the
obtained result with calculated value.
24.. The fuel cost of two units are given by
F1 = 0.1 P12 + 20 P1 + 1.5 Rs/hr.
F2= 0.1 P22 + 30 P2 + 1.9 Rs/hr.
If the total demand on the generation is 200 MW, find the economic load scheduling of
the two units. Assume the initial Lambda value. Also verify the obtained result with the
calculated value.
25. The fuel cost of two units are given by
F1 = 0.04 P12 + 16 P1 + 2.8 Rs/hr.
F2= 0.04 P22 + 12 P2 + 4.6 Rs/hr.
The B mn matrix is given by
0.01 ‐0.005
‐0.005 0.024
Determine the economic schedule for the incremental cost of received power of Rs
20 / MWhr. Also find a) Total generation b) Transmission losses and c) Demand. Verify
the obtained result with calculated value.
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26. Determine the Zbus matrix for the given system shown in figure 31 using available software
Figure 31
Buses : 6, numbered serially from 1 to 6 Lines : 5, numbered serially from L1 to L5 Base MVA : 100
Transmission Line Data: Half Line
Rating
Line ID No Send Bus Receive Resistance Reactance charging
No Bus No p.u p.u Suscept. MVA
P.u
1 1 6 0.123 0.518 0.0 55
2 1 4 0.080 0.370 0.0 65
3 4 6 0.087 0.407 0.0 30
4 5 2 0.282 0.640 0.0 55
5 2 3 0.723 1.050 0.0 40
Table 31
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27.Conduct fault analysis on two alternative configurations of the 4 - bus system given in Figure
32 below. Determine the fault current and MVA at faulted bus 4, post fault bus voltages, fault
current distribution in different elements of the network. Also draw a single line diagram
showing above results. For a given system of figure 32, following are the fault conditions.
(i) Three phase to ground fault (ii) Line to ground fault (iii) Line to line fault
(iv) Double line to ground fault.
Fig:32 Four bus system
G1, G2 : 100MVA, 20KV, X+ = X
- = Xd’’ = 20%; X
0 = 4%; Xn =
5% T1, T2 : 100MVA, 20KV/345KV; X leak = 8%
L1, L2 : X+ = X
- = 15%; X
0 = 50% on a base of 100MVA
The first configuration, case (a), comprises star-star transformer and the second
configuration, case (b), comprises star-delta transformers.
28. Determine the Ybus matrix for the given system in figure 34 using available software.
Figure 34
Buses : 6, numbered serially from 1 to 6
Lines : 5, numbered serially from L1 to L5
Base MVA : 100
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Transmission Line Data:
Half Line Rating
Line ID No Send Bus Receive Resistance Reactance charging
No Bus No p.u p.u Suscept. MVA
P.u
1 1 6 0.123 0.518 0.0 55
2 1 4 0.080 0.370 0.0 65
3 4 6 0.087 0.407 0.0 30
4 5 2 0.282 0.640 0.0 55
5 2 3 0.723 1.050 0.0 40
Table 34.1
Transmission Line Data:
Half Line Rating
Line ID No Send Bus Receive Resistance Reactance charging
No Bus No p.u p.u Suscept. MVA
P.u
1 1 6 0.123 0.518 0.0 55
2 1 4 0.080 0.370 0.0 65
3 4 6 0.087 0.407 0.0 30
4 5 2 0.282 0.640 0.0 55
5 2 3 0.723 1.050 0.0 40
Table 34.2
29. Simulate the load frequency dynamics of a single area power system whose data are given
below: Rated capacity of the area = 2000MW Normal operating load = 1000MW Nominal frequency = 50 Hz Inertia constant of the area = 5.0 s Speed regulation(governor droop) of all regulating generators = 4 percent Governor time constant = 0.08 s
Turbine time constant = 0.3 s
Assume linear load-frequency characteristics which mean the connected system load increases by one percent if the system frequency increases by one percent. The area has a governor control but not a load-frequency controller. The area is subjected to a load increase of
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20 MW. Plot the time response of frequency deviation ∆f in Hz and change in turbine power
∆PT in p.u MW upto 20 sec. What is value of the peak overshoot in ∆f?
(ii) Simulate the load frequency dynamics of a two area power system. Both the area are identical and has the system parameters givem in (i). Assume that the tie-line has a capacity of Pmax 1-2 = 200MW and is operating at a power angle of (δ 1
0 – δ2
0) = 30
°. Assume that
both the areas do not have load-frequency controller. Area 2 is subjected to a load increase of 20 MW. Plot the time responses, ∆f1(t), ∆f2(t), ∆PT1(t), ∆PT2(t) and ∆P12(t).
Comment on the peak overshoot of ∆f1 and ∆f2.
30.Simulate and run the NRLF program for the system in figure 36 with a convergence
for p and q for power tolerance of 0.001p.u. and no of iteration is 10. Determine the
following values,
(i) Total active power generation in MW and total active power load in MW (ii) Total reactive power generation in MVAR and total reactive power in load (iii) Total system active power loss as a percentage of generator (iv) Line flows and bus voltage.
Single -line Diagram
Figure 36
Data for the system Buses : 6, numbered serially from 1 to 6 Lines : 5, numbered serially from L1 to L5 Transformer : 2, numbered serially from T1 to T2 Shunt Load : 2, numbered serially from S1 to S2 Base MVA : 100 Bus Data – P V Buses ( 1 slack bus; remaining P-V buses)
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Bus ID Generation, MW Demand Gen.Limit, MVAR Scheduled
No.
Volt (p.u)
Schedule
Max
Min
MW
MVAR Max
Min
1 ? 200 40 0.0 0.0 100.0 -50.0 1.02
2 80.0 100 20 0.0 0.0 50.0 -25.0 1.02
Bus Data – PQ Buses
Bus ID Demand Volt. Mag.
No MW MVAR Assumed (p.u)
3 10.0 5.0 1.0
4 57.7 30.0 1.0
5 20.0 15.0 1.0
6 25.0 15.0 1.0
Transmission Line Data:
Half Line
Line ID No Send Bus Receive Resistance Reactance charging Rating
No Bus No p.u p.u Suscept. MVA
P.u
1 1 3 0.01 0.030 0.000 60.0
2 1 5 0.05 0.180 0.005 40.0
3 2 4 0.03 0.080 0.005 60.0
4 3 4 0.02 0.035 0.0 60.0
5 3 5 0.04 0.150 0.0 40.0
Transformer Data:
Transformer Send Receive Resistance Reactance Tap Ratio
Rating
ID No Bus(*) No Bus No p.u p.u MVA
1 2 6 0.0 0.06 1.02 60.0
2 5 6 0.0 0.08 1.01 60.0
(*) Note: The sending end bus of a transformer should be the tap side
Shunt Element Data:
Shunt ID No
Bus ID No Rated Capacity
MVAR (*)
1 4 0.5
2 6 0.5
(*) Note: Sign for capacitor : +ve
Sign for inductor : -ve
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