VOLTAGE STABILITY ANALYSIS OF POWER SYSTEMS USING … · the system affects directly the voltage...
Transcript of VOLTAGE STABILITY ANALYSIS OF POWER SYSTEMS USING … · the system affects directly the voltage...
VOLTAGE STABILITY ANALYSIS OF POWER
SYSTEMS USING THE CONTINUATION METHOD
Code: 19.003
A. D. Vasquez, T. Sousa
Federal University of ABC, Brasil
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1. Objectives
2. Introduction
3. The Voltage Stability
5. The Continuation Power Flow
6. Voltage Stability Margin (VSM)
7. Tests and Results
8. Discussion
9. Conclusions
Summary
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Inclusion of renewable energy sources in the system.
Impacts in the normal functioning of electric grids, caused by the
integration of intermittent sources in the system.
Voltage stability researching based in the determination of the
maximum loading of the electrical power system.
Application of the continuation method to the power flow problem
to improve the simulations performance.
Computing the algorithm by parallel programation techniques to
decrease the simulation time.
Objectives
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GROWING PLANNING AND VOLTAGE
DEMAND OPERATION SECURITY
TRANSFER OF LARGE
AMOUNTS OF POWER OPERATION IN CONTINUATION
STRESSFUL POWER FLOW
ECONOMIC AND CONDITIONS (CPF)
ENVIRONMENTAL P-V Curve drawing and
REQUIREMENTS computation of the system
Maximum Loading Point (MLP)
- Voltage stability margin and modal analysis studies;
- Determining effective measurements for strengthening the system;
- Analysis of static phenomenon such as the voltage stability.
Introduction
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Ability of a power system to maintain acceptable 𝑉𝑖 (𝑖 = 1,… ,𝑁𝐵) under
normal conditions and after being subjected to a disturbance.
Disturbances
CAUSED BY Increase in load demand
Change in system condition
There is a need for analytical tools capable of:
Predicting voltage collapse in complex networks;
Accurately quantifying stability margins and power transfer limits;
Identifying voltage-weak points and areas susceptible to voltage
instability;
Identifying key contribution factors and sensitivities that provide insight
into system characteristics to assist in developing remedial actions.
The Voltage Stability
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Captures “snapshots” of system conditions at various
time frames along the time-domain trajectory
Static analysis of voltage stability involves the static model
of the power system and it is based on the modal analysis
of the power flow Jacobian matrix, as shown in (1)
∆𝑃𝑃𝑄,𝑃𝑉∆𝑄𝑃𝑄
=𝐽𝑃𝜃 𝐽𝑃𝑉𝐽𝑄𝜃 𝐽𝑄𝑉
∙∆𝜃∆𝑉𝑃𝑄
(1)
A. Static Analysis
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This theory is used to describe changes in the qualitative structures of the
phase portrait when certain system parameters change.
SADDLE-NODE BIFURCATION Point of voltage collapse
A saddle-node bifurcation is the disappearance of a
system equilibrium as parameters change slowly.
The saddle-node bifurcation occurs when a stable
equilibrium at which the power system operates disappears.
𝑓 𝑥, 𝜆 = 𝑥 = 𝜆 − 𝑥2 (2)
system state
system parameter
B. Bifurcation Theory
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Using the continuation method, a solution branch
around the turning point can be tracked without
difficulties. The CPF captures the path-following
feature by means of a predictor-corrector scheme
that adopts locally parameterized continuation
techniques to trace the Power Flow solution paths. Adapted from [7].
Reformulation of Power Flow (PF) Equations
The PF equations are reformulated including a
load parameter λ.
Δ𝑃𝑖 = 𝑃𝐺𝑖 𝜆 − 𝑃𝐿𝑖 𝜆 − 𝑃𝑇𝑖 = 0 (3)
Δ𝑄𝑖 = 𝑄𝐺𝑖 𝜆 − 𝑄𝐿𝑖 𝜆 − 𝑄𝑇𝑖 = 0 (4)
The Continuation Power Flow
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Fig. 1. Predictor-corrector scheme used in the CPF.
The entire set of
equations is
denoted as 𝐹 and
the problem can be
expressed as (5). 𝐹 𝛿, 𝑉, 𝜆 = 0 0 𝑜𝑢 𝟏 ≤ 𝜆 ≤ 𝜆𝑐𝑟𝑖𝑡𝑖𝑐𝑎𝑙 (5)
𝑭𝜹 𝑭𝑽 𝑭𝝀
𝒅𝜹𝒅𝑽𝒅𝝀
= 𝟎 (6)
If the index 𝑘 represents the continuation parameter position and it is
chosen properly, the tangent vector is determined as the solution by (7).
𝑭𝜹 𝑭𝑽 𝑭𝝀
𝒆𝒌𝒕 =
𝟎𝒕𝒌
, 𝒕𝒌 = ±𝟏 (7)
𝜹𝒑
𝑽𝒑
𝝀𝒑 𝒋+𝟏
=𝜹𝑽𝝀 𝒋
+ 𝝈𝒋
𝒅𝜹𝒅𝑽𝒅𝝀
(8)
𝝈𝒋 𝒏𝒆𝒘=
𝝈𝒋 𝒐𝒍𝒅
𝒕 (9)
A. Prediction Step
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Tangent predictor technique
Predicted Solution
Step Size
The original set of equations is
augmented by one equation that
specifies the value of one of the state
variables. The 𝑘𝑡ℎ element has a
proper value considering that 𝑥𝑘 = 𝜂
and the new set of equations will be
as follows in (10).
𝐹(𝑥)𝑥𝑘 − 𝜂
= 0 (10)
Once the original equations system is
altered by an additional equation and
one additional state variable is
involved, a corrector method (NR) is
used to solve the system.
B. Local Parameterization
and Corrector Step
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C. The Critical Bus
Identification
P and Q transmission is very close
to the limit value.
The voltage control actions in a
critical bus may have opposite
consequences than expected
More sensitive due to
disturbances in the power system.
Mathematically, using the tangent
vector method, the critical bus will be
denoted by the index 𝑐 and will be
obtained by (11).
𝑐 ← 𝑚𝑎𝑥𝜕𝑉1
𝜕𝜆,𝜕𝑉2
𝜕𝜆, …
𝜕𝑉𝑛
𝜕𝜆 (11)
KNOW THE INSTABILITY MARGIN FOR THE SAFETY OPERATION PROXIMITY POINT OF THE POWER SYSTEM A widely accepted measure of voltage stability monitoring is expressed by
the load power margin which is defined to be the distance between the
current operating point 𝜆0 and system maximum loading point 𝜆𝑚𝑎𝑥 .
Thus, the system voltage stability margin (VSM) defined by the percentage
of the load power margin as proposed by (19).
𝑉𝑆𝑀 =𝜆𝑚𝑎𝑥 − 𝜆0
𝜆0× 100% 12
Voltage Stability Margin (VSM)
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IEEE-57-bus Test System
Fig. 2. Diagram for the IEEE 57-bus test system.
Test and Results
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1 1.05 1.1 1.15 1.2 1.250.8
0.82
0.84
0.86
0.88
0.9
0.92
0.94
0.96
0.98
1
Load ()
Vo
ltag
e m
ag
nitu
de
[p
u]
PV Curve
Critical bus: Bus31
7 Generators
15 LTCs 65 transmission elements
42 loads
Fig. 3. Voltage Profile in the critical bus for original IEEE 57-bus test system.
VSM= 17.68%
Case 1: Distributed Generator (DG) in B-31
For the first test case, a large generator with
50 [MW] and 30 [MVAr] in the original critical
bus of the system is incorporated.
Fig. 4. Voltage Profile in the critical bus for Case 1.
Critical Bus: 25
VSM= 28.68%
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Case 2: DG in a High Load Area
In the northeast area of the system is
concentrated the 48.24% of the active load
and 26.53% of the reactive For this reason,
the same DG is allocated in the B-37.
Fig. 5. Voltage Profile in the critical bus for Case 2.
Critical Bus: 31
VSM= 28.16%
1 1.05 1.1 1.15 1.2 1.25 1.3 1.35 1.41.06
1.07
1.08
1.09
1.1
1.11
1.12
Load ()
Vo
ltag
e m
ag
nitu
de
[pu
]
PV Curve
Critical bus: Bus25
1 1.05 1.1 1.15 1.2 1.25 1.3 1.35 1.40.93
0.94
0.95
0.96
0.97
0.98
0.99
1
Load ()
Vo
ltag
e m
ag
nitu
de
[pu
]
PV Curve
Critical bus: Bus31
Case 3: DG in a distant bus from the original
generation: A bus is selected in the middle
of the mesh transmission network. Thus, for
guarantee its similar distance with all the
generators located in the original system:
Bus 36.
Fig. 6. Voltage Profile in the critical bus for Case 3.
Critical Bus: 31
VSM= 28.70%
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Case 4: 2 DG’s connected in strategic buses
The additional generation for the system is
included using two identical distributed
generators. Each of them injects 25 [MW]
and 15 [MVAr] to the system and are
allocated in buses 36 and 37.
Fig. 7. Voltage Profile in the critical bus for Case 4.
Critical Bus: 31
VSM= 35.93%
1 1.05 1.1 1.15 1.2 1.25 1.3 1.35 1.40.96
0.97
0.98
0.99
1
1.01
1.02
Load ()
Vo
ltag
e m
ag
nitu
de
[p
u]
PV Curve
Critical bus: Bus31
1 1.05 1.1 1.15 1.2 1.25 1.3 1.35 1.4 1.45
0.97
0.98
0.99
1
1.01
1.02
Load ()
Vo
ltag
e m
ag
nitu
de
[p
u]
PV Curve
Critical bus: Bus31
The Case 4 obtains the best stability scenario where the VSM has the
greatest value, increasing from 17.68% in the original case to 35.93% and
the final magnitude voltage in the critical bus (bus 31) is 0.98 [pu].
This results shows injection of distributed generation in strategic points of
the system affects directly the voltage stability margin and the voltage
profile of the buses in the system.
Based in this information, it is possible to affirm that is better divide the
power injection in a mesh system than concentrate the distributed
generation just in a strategic bus. Thus, using different criteria for selecting
strategic connection points in the system and installing the same total
additional power distributed in these points, the voltage stability improves
considerably.
Discussion
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The CPF methodology is considering a computational simulation tool to
aid in operating, planning and investment decisions in power systems.
The injection of active power and compensation of reactive power in
the system was studied using different allocations for the same
apparent power.
The best criteria to include distributed generation in the system is
selecting more than one injection point in different areas of the system
and divide the total apparent power in these connection points.
The simulation time for this system using parallel programation
techniques corresponds to 2.66 milliseconds.
The future work consists in improving this time, including a Graphic
Processing Unit in the methodology to process the information in large
transmission and distribution systems.
Conclusions
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