Mitigating Low-Frequency Oscillations and Enhancing the Dynamic Stability of Power System Using Optimal Coordination of Power System Stabilizer and Uniﬁed Power Flow Controller

: The integration of a ﬂexible alternating current transmission system (FACTS) and a power system stabilizer (PSS) can increase dynamic stability. This paper presents the enhancement of power system dynamic stability through the optimal design of a power system stabilizer and UPFC using an ant lion optimization (ALO) technique to enhance transmission line capacity. The gained damping ratio, eigenvalue and time domain results of the suggested ALO technique were compared with a base case system, ALO-based PSS and ALO-based PSS-UPFC to test the effectiveness of the proposed system in different loading cases. Eigenvalues gained from an ant lion approach-based UPFC with a PSS and a base case system are compared to examine the robustness of the ALO method for various loading conditions. Thus, this paper addresses the mechanism regarding the power system dynamic stability of transmission lines by integrating the optimal size of a PSS and UPFC into the power system. Therefore, the main contribution of this manuscript is the optimal coordination of a power system stabilizer, power oscillation damper and uniﬁed power ﬂow using ant lion optimization for the mitigation of low-frequency oscillation.


Introduction
Power system instability restricts the normal operation of a system, which influences the security and economics of the system.Furthermore, the integration of a far-end power system provides low-frequency oscillation with a frequency limit of 0.1-0.3Hz.If the oscillations are not treated early, it will lead to system instability or complete blackout, though the expansion and application of a UPFC for a power system had exposed promising results to improve the transmission line capability.Currently, numerous FACTS devices have been presented and implemented in practical power systems, such as UPFCs and other devices.The organized application of a PSS equipped with a UPFC ensures power system stability and suppresses LFO during a disturbance.The proper amendment of PSS and UPFC parameters controls their efficacy for dynamic stability in transmission lines for power system stability [1].Little or huge trouble in power systems affects the steady-state process of power systems and leads to system instability [2].The key motives of system instability are the imbalance between load and generation.Currently, a large load connected to the farthest end of transmission lines enforces the transmission of a large amount of power via extended transmission lines and leads to LFO [3].
The integration of a large number of bulk renewable energy sources, along with a conventional generation system, incorporates various controllers into the system, such as maximum power point controllers, battery charging and discharging controllers and microgrid controllers.The interaction of these controllers with the existing system controllers, such as power system stabilizers (PSSs), creates some negative impacts on the system.Therefore, the optimal coordination of various controllers in a system is very important from the point of view of the stable operation of a system.

Related Work
Numerous academics have conducted research on LFO damping.The design of the damping and internal controllers of UPFCs in relation to LFO damping was studied by the authors in [2].The improvement of a power system's dynamic stability utilizing a STATCOM and FLC-based stabilizer was discussed in [3].Researchers looked at the coordinated design of a PSO-based multi-machine power system stabilizer and TCSC damping controller in [4].The use of a unified power flow controller to control power flow and boost bus voltage in a power transmission system was studied by the authors in [5].The authors examined the effects of the UPFC settings on power flow in a power system in [6].The authors of [7] described the use of a unified power flow controller to increase the capacity of active power flow in a power system utilizing an IEEE 14 bus system.The damping of low-frequency oscillations in a linked power system was described in [8].A critical analysis of the function of unified power flow regulation in voltage power transfer was offered by the authors in [9].In [10], authors described how using several damping controllers based on PSS and the UPFC improved the performance of power system stability.The improvement of power system dampening using TCSC and controller design based on genetic algorithms was discussed in [11].The author of [12] presented the unified power flow controller's damping function.The effect of a UPFC-based damping controller on the dynamic stability of the Iraqi power network was discussed by the authors in [13].The best multi-objective design of robust power system stabilizers using evolutionary algorithms was given in [14].In [15], authors described the dynamic performance of the 48-pulse GTO thyristor-based interline unified power flow controller (IUPFC) system.An adaptive UPFCbased stabilizer for damping low frequency oscillation was presented by the authors in [16].The authors of [17] described how support vector regression improved the PSS-UPFC installed power system's stability.Particle swarm optimization was used by the authors of [18] to create an output feedback UPFC controller for dampening electromechanical oscillations.Using the firefly method, authors in [19] demonstrated the best tuning for a unified power flow controller to reduce inter-area oscillations in a multi-machine system.In [20], authors described a STATCOM controller design that dampens low frequency oscillations in the power system using a modified shuffling frog leaping algorithm.The authors of [21] described the positioning and use of STATCOM-storage for improving the voltage stability of power systems with integrated wind farms.The stability study and dynamic performance improvement of an autonomous microgrid utilizing an adaptive fuzzy PI controller were published in [22].The author of [23] described improving the dynamical properties of a fuzzy control.

Research Gaps
The weakness of the above literature is that the stability of the system is maintained by conventional PSSs and conventional unified power flow controllers.Ref. [17] presented a coordinated design of a power system stabilizer and unified power flow controller but did not use any controller for the UPFC.Ref. [18] described the improvement of a power system stabilizer and unified power flow controller used in a power system using both statistical and testing datasets to check the efficiency of the system in different loading conditions.

Contribution of the Manuscript
The key aids of this manuscript are: 1.
The optimal coordination of a power system stabilizer, power oscillation damper and unified power flow controller is proposed using ant lion optimization for lowfrequency oscillation mitigation; 2.
The controllers are optimally sized and placed using ALO; 3.
The tuning parameters of the controller are optimally computed; 4.
A detailed comparative analysis to show the dominance of the ALO-coordinated UPFC-PSS system over the existing literature is presented.Comparative analysis is presented on the performance characteristics, such as the damping ratio and eigenvalue analysis.
A detailed comparative analysis to show the dominance of the ALO-coordinated UPFC-PSS system over the existing literature is presented.Comparative analysis is presented on the performance characteristics, such as the damping ratio and eigenvalue analysis.
The superiority of the proposed ALO-based UPFC-PSS system over the others was confirmed through the presented minimum damping ratio and eigenvalue analysis, along with the time domain representations of the power system states with a properly sized damping controller.In the proposed system, the power oscillation damping controller parameters were optimally sized using ALO to produce electrical torque in the phase with speed deviation using a phase compensation technique, which meets the proposed objective function.Therefore, the ALO-based optimal sizing of the PSS and UPFC makes this manuscript superior to the other papers due to the proper sizing and installation of a power system oscillation damping controller on the UPFC.

Aims of the Manuscript
The main aims of this manuscript are to mitigate low-frequency oscillations and enhance the dynamic stability of a power system using the optimal coordination of a power system stabilizer and unified power flow controller.The specific tasks of the manuscript are described as follows:

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To collect and analyze the necessary data from different sources;

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To obtain the synchronous machine rotor angle value, rotor speed deviation and DC-link voltage;

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To ensure the size of the power oscillation damping controller is a properly sized damping controller;

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To perform eigenvalue and time domain analyses.

Scope of the Study
This manuscript is concerned with mitigating low-frequency oscillations and enhancing the dynamic stability of a power system using the optimal coordination of a power system stabilizer and a unified power flow controller.This problem will be solved by maintaining the rotor angle of a synchronous machine in stable or optimum conditions or minimizing low-frequency oscillation by employing ALO.This study is limited to the simulation of a Tana Beles 400 kV transmission network with optimally placed and sized UPFC system components and power system stabilizer and performs a mathematical analysis.In addition, this paper provides eigenvalue and time domain analyses to determine the maximum overshoot and settling time of power system states.

Methodology
The document is structured as follows: Section 1 discusses the introduction of the manuscript; Section 2 discusses the modeling of the system applied in this paper; Section 3 discusses the methodology of the completed manuscript; and Section 4 discusses the results, followed by the conclusion.

Modeling of Proposed System
Synchronous generator small signal analysis, excitation system model, PSS and UPFC are momentarily presented.This paper is composed of mathematical modeling of synchronous generator, transmission line, power system stabilizer and UPFC. Figure 1 presents the overall diagram of SMIBs of the considered network [4].
to the simulation of a Tana Beles 400 kV transmission network with optimally placed and sized UPFC system components and power system stabilizer and performs a mathematical analysis.In addition, this paper provides eigenvalue and time domain analyses to determine the maximum overshoot and settling time of power system states.

Methodology
The document is structured as follows: Section 1 discusses the introduction of the manuscript; Section 2 discusses the modeling of the system applied in this paper; Section 3 discusses the methodology of the completed manuscript; and Section 4 discusses the results, followed by the conclusion.

Modeling of Proposed System
Synchronous generator small signal analysis, excitation system model, PSS and UPFC are momentarily presented.This paper is composed of mathematical modeling of synchronous generator, transmission line, power system stabilizer and UPFC. Figure 1 presents the overall diagram of SMIBs of the considered network [4].

Modeling of Synchronous Generator
The single line diagram of synchronous machine described by the classical model with reactance and resistance included is shown in Figure 2 below [5].The terminal current It in the above generator model presented in [5] can be obtained from terminal voltage and bus voltage:

Ra+jX'd RE+jXE EB EB
The complex power behind the transient reactance can be described as:

Modeling of Synchronous Generator
The single line diagram of synchronous machine described by the classical model with reactance and resistance included is shown in Figure 2 below [5].
sized UPFC system components and power system stabilizer and performs a mathemat ical analysis.In addition, this paper provides eigenvalue and time domain analyses to determine the maximum overshoot and settling time of power system states.

Methodology
The document is structured as follows: Section 1 discusses the introduction of the manuscript; Section 2 discusses the modeling of the system applied in this paper; Section 3 discusses the methodology of the completed manuscript; and Section 4 discusses the results, followed by the conclusion.

Modeling of Proposed System
Synchronous generator small signal analysis, excitation system model, PSS and UPFC are momentarily presented.This paper is composed of mathematical modeling o synchronous generator, transmission line, power system stabilizer and UPFC. Figure 1 presents the overall diagram of SMIBs of the considered network [4].

Modeling of Synchronous Generator
The single line diagram of synchronous machine described by the classical mode with reactance and resistance included is shown in Figure 2 below [5].The terminal current It in the above generator model presented in [5] can be ob tained from terminal voltage and bus voltage:

Ra+jX'd RE+jXE EB EB
The complex power behind the transient reactance can be described as: The terminal current It in the above generator model presented in [5] can be obtained from terminal voltage and bus voltage: The complex power behind the transient reactance can be described as: Sustainability 2023, 15, 6980 In pu, To linearize rotor angle of the system, the equation provides new representation as expressed by considering various loading conditions given by δ = δ0: The equation in pu is represented in equations below: Linearizing the above equation and rearranging the new equation are obtained as follows: The following equations are obtained in vector matrix form as follows: p∆δ = ω 0 ∆ω r (11) d dt This is the form: .
x = Ax + bu The characteristics are: The overall formula with s-operator is: Undamped natural frequency can be described as: The damping ratio is obtained as: Eigenvalues are gained from Equation ( 16): The damped frequency is: where K s is synchronizing torque coefficient, K D is damping torque coefficient, H is inertia constant, ∆ω r is ((ω r − ω 0 )/ω 0 ), ∆δ is rotor angle deviation, and ω 0 = 2π f 0 , f 0 = 50Hz).

Modeling of Excitation System
To excite field winding of generator, DC power is used.Furthermore, excitation system performs control and protective functions necessary for the efficient control of field current.The protective function ensures the ability to restrict generator excitation system and other devices [6]. Figure 3 presents the excitation system with power system stabilizer.

Modeling of Excitation System
To excite field winding of generator, DC power is used.Furthermore, excitation system performs control and protective functions necessary for the efficient control of field current.The protective function ensures the ability to restrict generator excitation system and other devices [6]. Figure 3 presents the excitation system with power system stabilizer.

Power System Stabilizer
PSS is used to increase system stability by controlling the excitation system.It affords supplementary control signal to enhance damping torque of generator.To enhance capability of avoiding system LFO, power system stabilizer uses rotor speed (∆), frequency (∆), accelerating power (Pm − Pe), electrical power (∆) and combination of input signals.  is the washout time.T1-T4 represent time constants [7].

Optimal Parameter of PSS
Figure 4 below involves a gain block (  ), Tw and lead lag time constant [8].
Time constant is chosen between 0.01 and 1 s.The time constant T 1 − T 4 and gain   are optimally selected using ALO algorithm [8].

PSS Model
The techniques of integrating excitation system into power system stability enhancement are shown in Figure 5 below.

Power System Stabilizer
PSS is used to increase system stability by controlling the excitation system.It affords supplementary control signal to enhance damping torque of generator.To enhance capability of avoiding system LFO, power system stabilizer uses rotor speed (∆ω), frequency (∆ f ), accelerating power (Pm − Pe), electrical power (∆Pe) and combination of input signals.T w is the washout time.T1-T4 represent time constants [7].

Optimal Parameter of PSS
Figure 4 below involves a gain block (K PSS ), Tw and lead lag time constant [8].

Modeling of Excitation System
To excite field winding of generator, DC power is used.Furthermore, excita system performs control and protective functions necessary for the efficient contr field current.The protective function ensures the ability to restrict generator excita system and other devices [6]. Figure 3

Power System Stabilizer
PSS is used to increase system stability by controlling the excitation system.I fords supplementary control signal to enhance damping torque of generator.To enh capability of avoiding system LFO, power system stabilizer uses rotor speed (∆), quency (∆), accelerating power (Pm − Pe), electrical power (∆) and combinatio input signals.  is the washout time.T1-T4 represent time constants [7].

Optimal Parameter of PSS
Figure 4 below involves a gain block (  ), Tw and lead lag time constant [8].
Time constant is chosen between 0.01 and 1 s.The time constant T 1 − T 4 and   are optimally selected using ALO algorithm [8].

PSS Model
The techniques of integrating excitation system into power system stability hancement are shown in Figure 5 below.Time constant is chosen between 0.01 and 1 s.The time constant T 1 -T 4 and gain K PSS are optimally selected using ALO algorithm [8].

PSS Model
The techniques of integrating excitation system into power system stability enhancement are shown in Figure 5 below.

Modeling of UPFC
A UPFC is a flexible device that has the capability to tune control parameters, such as V, X and , between two buses.UPFC has two VSC, series and shunt converters interconnected with DC-link capacitor.The single line diagram of UPFC of SMIBs is shown in Figure 6 below.Excitation transformer and boosting transformer are connected with UPFC in the transmission line.The VSC B or SSSC is used to inject series voltage with boosting transformer (BT), which is connected in series with TL, while VSC E (STATCOM) is used to absorb (supply) real power that supports VSC B as needed.There are four parameters of UPFC which are   ,   ,   and   , where   and   are the phase angle of   and   , respectively, and   and   are the amplitude modulation ratio of   and   , respectively.

Mathematical Model of SMIB with UPFC
The model of UPFC with damping controller is presented in Figure 7 [10] below, where  can be   ,   ,   and   , which are input parameters for UPFC.

Modeling of UPFC
A UPFC is a flexible device that has the capability to tune control parameters, such as V, X and δ, between two buses.UPFC has two VSC, series and shunt converters interconnected with DC-link capacitor.The single line diagram of UPFC of SMIBs is shown in Figure 6 below.

Modeling of UPFC
A UPFC is a flexible device that has the capability to tune control parameters, such as V, X and , between two buses.UPFC has two VSC, series and shunt converters interconnected with DC-link capacitor.The single line diagram of UPFC of SMIBs is shown in Figure 6 below.Excitation transformer and boosting transformer are connected with UPFC in the transmission line.The VSC B or SSSC is used to inject series voltage with boosting transformer (BT), which is connected in series with TL, while VSC E (STATCOM) is used to absorb (supply) real power that supports VSC B as needed.There are four parameters of UPFC which are   ,   ,   and   , where   and   are the phase angle of   and   , respectively, and   and   are the amplitude modulation ratio of   and   , respectively.

Mathematical Model of SMIB with UPFC
The model of UPFC with damping controller is presented in Figure 7 [10] below, where  can be   ,   ,   and   , which are input parameters for UPFC.Excitation transformer and boosting transformer are connected with UPFC in the transmission line.The VSC B or SSSC is used to inject series voltage with boosting transformer (BT), which is connected in series with TL, while VSC E (STATCOM) is used to absorb (supply) real power that supports VSC B as needed.There are four parameters of UPFC which are m E , m B , δ E and δ B , where δ E and δ B are the phase angle of E T and B T , respectively, and m E and m B are the amplitude modulation ratio of E T and B T , respectively.

Mathematical Model of SMIB with UPFC
The model of UPFC with damping controller is presented in Figure 7 [10] below, where N; can be m E , m B , δ E and δ B , which are input parameters for UPFC.

Modeling of UPFC
A UPFC is a flexible device that has the capability to tune control parameters, such as V, X and , between two buses.UPFC has two VSC, series and shunt converters interconnected with DC-link capacitor.The single line diagram of UPFC of SMIBs is shown in Figure 6 below.Excitation transformer and boosting transformer are connected with UPFC in the transmission line.The VSC B or SSSC is used to inject series voltage with boosting transformer (BT), which is connected in series with TL, while VSC E (STATCOM) is used to absorb (supply) real power that supports VSC B as needed.There are four parameters of UPFC which are   ,   ,   and   , where   and   are the phase angle of   and   , respectively, and   and   are the amplitude modulation ratio of   and   , respectively.

Mathematical Model of SMIB with UPFC
The model of UPFC with damping controller is presented in Figure 7 [10] below, where  can be   ,   ,   and   , which are input parameters for UPFC.

Non Linear Dynamic form of UPFC
From Figure 8 above, the non-linear equation describes the characteristics of UPFC with three phase excitation and boosting current [12].
The shunt converter current can be described as: The series converter current can be described as: DC-link capacitor voltage can be:

Non Linear Dynamic form of UPFC
From Figure 8 above, the non-linear equation describes the characteristics of UPFC with three phase excitation and boosting current [12].
The shunt converter current can be described as: The series converter current can be described as: DC-link capacitor voltage can be: where V Et , i E , r E and l E are voltage, current, resistance and inductance of ET, respectively, while V Bt , i B , r B and l B are for BT, respectively; and C dc , V dc are capacitance and voltage of DC link, respectively.The voltage equation of UPFC can be [12]: where V E , X E and i E , and V B , X B and i B are voltage, reactance and current of ET and BT, respectively.V DC and C DC are DC-link voltage capacitance.Equations below show nonlinear model of UPFC [12]: .
Real power balance equation of UPFC is shown below: where δ is rotor angle, ω and ωb are rotor speed and synchronous speed, P m and P e are mechanical and electrical power, D is damping coefficient, and M inertia E fd , .E q and E q are the field, internal voltage and transient of the generator, respectively.
The terminal voltage V t is: V td = v d − x t i q = x q i q (34) where In addition, v td , v tq and i d ; i q v d ; and v q are d and q axes components of terminal voltage V t .
The terminal voltage is [13]: where K pd , K pe , K pδe , K pb , K pδb , K qd , K qe , K qδe , K qb , K qδb , K vd , K ve , K vδe , K vb , K vδb , K ce , K cδe , K cb and K cδb are constants, and K 1 to K 9 are system coefficients.In state space, the power system can be represented as: where X is state vector, and U is control vector: Matrices A and B are represented, as shown below [13]: where ∆m E , ∆m B , ∆δ E and ∆δ B are input signals of UPFC.The DC-link capacitor voltage δ E is [13]: where K dp is controller proportional gain, and k S is proportional gain of SSSC.

Dynamic Form of DC-Link Capacitor
The active power maintained in the capacitor is given by: P dc = P sh − P se (48) where the shunt power and series power are given by: P sh = V shd i shd − V shq i shq , P se = V sed i sed − V seq i seq and P dc = I DC * V dc Dc-link capacitor current is given by: where P se , P sh and P dc are real power of series, shunt converter and DC-link capacitor, respectively.

PSS and UPFC Controllers
The structure of PSS used is lead-lag controller, which is described as: Figure 9 below shows the UPFC with damping controller and PSS: where   ,  ℎ and   are real power of series, shunt converter and DC-link capacitor, respectively.

PSS and UPFC Controllers
The structure of PSS used is lead-lag controller, which is described as: In this case, ∆u is either   ,   ,   or   .Figure 10 presents the UPFC controller with POD and DC voltage regulator.

Methodology
This section discusses the methodology utilized in this research.where   ,  ℎ and   are real power of series, shunt converter and DC-link capacitor, respectively.

PSS and UPFC Controllers
The structure of PSS used is lead-lag controller, which is described as: In this case, ∆u is either   ,   ,   or   .Figure 10 presents the UPFC controller with POD and DC voltage regulator.

Methodology
This section discusses the methodology utilized in this research.

Methodology
This section discusses the methodology utilized in this research.

Ant Lion Optimization Technique
For the optimal parameter computation, ant lion optimization technique was utilized in this work.

Objective Function
Damping factor as an objective function is given by (J1) [15]: Damping ratio as second objective function (J2): The general objective function J3 is given by [15]: Constraint Equation Minimize J subject to controller gain: Phase-compensating time constants [15]: where NP is the number of operating points, and ζ i is damping ratio of i th eigenvalues, respectively.Table 1 presents the typical range of constraint parameters of PSS. Figure 11a presents the objective function J1 that carries out eigenvalues to the left side of the jω axis, and Figure 11b shows objective function J2, which restricts maximum overshoot.Figure 11c shows the combination of the above two objective functions.

Optimal Sizing of Power System Stabilizer
T1-T4 and controller gain   are properly sized using ALO techniques.Table 2 presents the optimal values of PSS using ALO. Figure 12 presents the structure of PSS.

Optimal Sizing of Power System Stabilizer
T 1 -T 4 and controller gain K PSS are properly sized using ALO techniques.Table 2 presents the optimal values of PSS using ALO. Figure 12 presents the structure of PSS.

Optimal Sizing of Power System Stabilizer
T1-T4 and controller gain   are properly sized using ALO techniques.Table 2 presents the optimal values of PSS using ALO. Figure 12 presents the structure of PSS.The optimal method used here is ant lion optimization technique, and the parameter values of power system stabilizer and unified power flow controller with optimal tuning are used.Therefore, the eigenvalue analysis method and time domain simulation method are used to obtain damping ratio, damping factor, maximum overshoot and settling time of the system , respectively.

Design of UPFC Supplementary Controllers
Optimal design of PSS parameters was used to obtain quick responses and attain normal operation of the system [16].The input was speed deviation, while the output was stabilized [17].Optimal parameters were selected to achieve maximum damping efficiency using ALO [18].The transfer function of POD controller is given by: The optimal method used here is ant lion optimization technique, and the parameter values of power system stabilizer and unified power flow controller with optimal tuning are used.Therefore, the eigenvalue analysis method and time domain simulation method are used to obtain damping ratio, damping factor, maximum overshoot and settling time of the system, respectively.

Design of UPFC Supplementary Controllers
Optimal design of PSS parameters was used to obtain quick responses and attain normal operation of the system [16].The input was speed deviation, while the output was stabilized [17].Optimal parameters were selected to achieve maximum damping efficiency using ALO [18].The transfer function of POD controller is given by: H(s) = 14.265 * 10s 1 + 10s 1 + 0.01968s 1 + 0.3608s The above transfer function of POD controller in Equation ( 61) is designed for damping of low-frequency oscillation of Tana Beles 400 kV transmission line, but it may not be universal as all the parameters are tuned based on the data obtained from Tana Beles power plant.

Simulation Results and Discussion
The eigenvalue simulation and time domain analyses were carried out for power system stability enhancement.

Eigenvalue Analysis and Minimum Damping Ratio (MDR)
The system is stable if and only if, all the eigenvalues are located on the left of the jw axis, otherwise the system is unstable.To obtain better controller eigenvalues, MDRs of the different loading conditions were compared for the following figures: Figures 13-15 below show the eigenvalues of the base case in normal, light and heavy operating conditions, respectively, which are located on the right of the jω plane.Therefore, the system is not stable.Figure 13 shows the eigenvalues in normal operating conditions in which the first three eigenvalues (indicated in bold) are positive before the PSS and UPFC are placed into the system In Figure 14 eigenvalues in light loading conditions are presented, while Figure 15 shows the eigenvalues in heavy operating conditions in which the first three eigenvalues are positive, but the magnitude of the eigenvalues is different, as indicated in Table 3 below.Therefore, the system is not stable.Figure 13 shows the eigenvalues in normal operating conditions in which the first three eigenvalues (indicated in bold) are positive before the PSS and UPFC are placed into the system In Figure 14 eigenvalues in light loading conditions are presented, while Figure 15 shows the eigenvalues in heavy operating conditions in which the first three eigenvalues are positive, but the magnitude of the eigenvalues is different, as indicated in Table 3 below.tions in which the first three eigenvalues are positive, but the magnitude of values is different, as indicated in Table 3 below.Figures 16-18 present the eigenvalues when the PSS is used in the system, which are located on the right of the jω axis.Therefore, the system is unstable.18 present the eigenvalues when the PSS is used in the system, wh located on the right of the  axis.Therefore, the system is unstable.4 above with their specific locations of eigenvalues.

Time Domain Analysis
This section presents the time domain analysis of the optimally coordinated PSS and UPFC integrated system.

PSS and UPFC Parameters
Table 4 presents the optimal parameters of the POD controller using algorithms.ALO has relatively robust controller parameters compared to GA, TLBO and PSO.

Time Domain Analysis
This section presents the time domain analysis of the optimally coordinated PSS and UPFC integrated system.

Time Domain Analysis
This section presents the time domain analysis of the optimally coordinated PSS and UPFC integrated system.

PSS and UPFC Parameters
Table 4 presents the optimal parameters of the POD controller using algorithms.ALO has relatively robust controller parameters compared to GA, TLBO and PSO.
The recorded average time to optimally tune the PSS parameters was approximately 15.531407, 19.4363, 106.3817 and 203.4058 s for ALO, GA, PSO and TLBO, respectively.Consequently, the average time required to tune the parameters of the PSS-UPFC optimized by ALO was 15.531407 s, which is pretty small and indicates real-time implementation of the ALO-developed model in the power system, and the proposed method is fast, which confirms the superiority of the developed method.The recorded average time to optimally tune the PSS parameters was approximately 15.531407, 19.4363, 106.3817 and 203.4058 s for ALO, GA, PSO and TLBO, respectively.Consequently, the average time required to tune the parameters of the PSS-UPFC optimized by ALO was 15.531407 s, which is pretty small and indicates real-time implementation of the ALO-developed model in the power system, and the proposed method is fast, which confirms the superiority of the developed method.From Figure 24, the results present slight oscillations due to the shunt converter controlling the DC-link voltage efficiently.The aim of the low-frequency oscillation study was to attain stability and clear fault disturbances.Figure 25 presents the positive voltage (a), real power (b) and reactive power of each bus (c).The recorded average time to optimally tune the PSS parameters was approximately 15.531407, 19.4363, 106.3817 and 203.4058 s for ALO, GA, PSO and TLBO, respectively.Consequently, the average time required to tune the parameters of the PSS-UPFC optimized by ALO was 15.531407 s, which is pretty small and indicates real-time implementation of the ALO-developed model in the power system, and the proposed method is fast, which confirms the superiority of the developed method.From Figure 24, the results present slight oscillations due to the shunt converter controlling the DC-link voltage efficiently.The aim of the low-frequency oscillation study was to attain stability and clear fault disturbances.Figure 25 presents the positive voltage (a), real power (b) and reactive power of each bus (c).From Figure 24, the results present slight oscillations due to the shunt converter controlling the DC-link voltage efficiently.The aim of the low-frequency oscillation study was to attain stability and clear fault disturbances.Figure 25

Simulation Results Using Different Techniques
The comparison of different optimization methods and the simulation results of the proposed ALO-based PSS and UPFC controller show better efficiency for the damping of LFO compared to the base case model and GA, PSO and TLBO methods.The UPFC controller can effectively damp out LFO when the ALO method is applied.

Simulation Results Using Different Techniques
The comparison of different optimization methods and the simulation results of the proposed ALO-based PSS and UPFC controller show better efficiency for the damping of LFO compared to the base case model and GA, PSO and TLBO methods.The UPFC controller can effectively damp out LFO when the ALO method is applied.Table 5 presents values which are illustrated in Figures 26-28 shown below.In Table 5 below, the maximum overshoot and settling time of the ALO optimization technique are more accurate than and superior to the remaining techniques.The simulation results clearly explain how this optimization technique is more advantageous than the remaining techniques.The comparison of different optimization methods and the simulation results o proposed ALO-based PSS and UPFC controller show better efficiency for the dampin LFO compared to the base case model and GA, PSO and TLBO methods.The U controller can effectively damp out LFO when the ALO method is applied.Table 5 sents values which are illustrated in Figures 26-28 shown below.In Table 5 below maximum overshoot and settling time of the ALO optimization technique are mor curate than and superior to the remaining techniques.The simulation results clearly plain how this optimization technique is more advantageous than the remaining t niques.Figure 27 above shows that the angle deviation of the proposed ALO technique has less maximum overshoot and settling time than the other applied methods.Therefore, the proposed ALO technique takes less time for the damping of LFO and attains a steady-state system.From Figure 28 above, the proposed ALO provides good results in terms of reducing the variations of LFO and presents the robustness of the system.

Simulation Results in Different Loading Conditions
As the operating load is continuously varying, it is significant to examine the disparity of loading conditions on the efficiency of the system.The different power system states, such as speed deviation, angle deviation and the rotor angle, were used with the Figure 26 above shows that the speed deviation of the proposed ALO technique has less maximum overshoot and settling time than the other remaining techniques.Therefore, the ALO technique is superior to damp out low-frequency oscillation compared to the GA, TLBO and PSO applied methods.
Figure 27 above shows that the angle deviation of the proposed ALO technique has less maximum overshoot and settling time than the other applied methods.Therefore, the proposed ALO technique takes less time for the damping of LFO and attains a steadystate system.
From Figure 28 above, the proposed ALO provides good results in terms of reducing the variations of LFO and presents the robustness of the system.

Simulation Results in Different Loading Conditions
As the operating load is continuously varying, it is significant to examine the disparity of loading conditions on the efficiency of the system.The different power system states, such as speed deviation, angle deviation and the rotor angle, were used with the base case system, PSS and UPFC PSS system.Three different scenarios, such as normal, light and heavy loading conditions, were considered for comparison.

Simulation Results in Normal Operating Conditions
A simulation in normal loading conditions was performed to compare the efficiency of the ALO-based PSS and UPFC with the base case system.From the results shown below, the oscillations do not effectively dampen the oscillation for the base case system.Table 6 presents the power system states in normal operating conditions.Figure 29 above shows the speed deviations demonstrated with the base case, PSS only and UPFC-PSS in normal operating conditions.Due to little oscillation of the generator turbine, the maximum overshoot varies from 0.08 to 5.45% and the settling time from 49.25 to 78.54% for the PSS only and ALO-based PSS-UPFC, respectively.Figure 30  Figure 29 above shows the speed deviations demonstrated with the base case, only and UPFC-PSS in normal operating conditions.Due to little oscillation of the erator turbine, the maximum overshoot varies from 0.08 to 5.45% and the settling from 49.25 to 78.54% for the PSS only and ALO-based PSS-UPFC, respectively.Figur presents the rotor angle deviation of the system in normal operating conditions.Figure 29 above shows the speed deviations demonstrated with the base case only and UPFC-PSS in normal operating conditions.Due to little oscillation of the erator turbine, the maximum overshoot varies from 0.08 to 5.45% and the settling from 49.25 to 78.54% for the PSS only and ALO-based PSS-UPFC, respectively.Figu presents the rotor angle deviation of the system in normal operating conditions.The rotor angle deviation in the base case is oscillatory and takes a long duration for power system stability enhancement, but the UPFC is coordinated with the PSS, and the system damps out the LFO.When the angle deviation is exposed to a change in angle, then the power is exposed to ∆P, and the system is unstable.Figure 31 presents the rotor angle of the base case and the PSS with the UPFC under normal loading.
The settling time of the PSS and the PSS-UPFC was 64.13 and 82.35%, and the maximum overshoot was 0.17 and 11.35%, respectively.When compared to the base case, the ALO-based PSS-UPFC controller can effectively stabilize the system under the perturbation existing in the system.

Simulation Results in Heavy Operating Conditions
The proposed PSS with the UPFC controller at a rapid load increment was chosen as a disruption in heavy operating conditions.Table 7 presents the power system states in heavy operating conditions.
The rotor angle deviation in the base case is oscillatory and takes a long du power system stability enhancement, but the UPFC is coordinated with the PS system damps out the LFO.When the angle deviation is exposed to a change then the power is exposed to∆P, and the system is unstable.Figure 31 presents angle of the base case and the PSS with the UPFC under normal loading.The settling time of the PSS and the PSS-UPFC was 64.13 and 82.35% maximum overshoot was 0.17 and 11.35%, respectively.When compared to the the ALO-based PSS-UPFC controller can effectively stabilize the system unde turbation existing in the system.

Simulation Results in Heavy Operating Conditions
The proposed PSS with the UPFC controller at a rapid load increment was a disruption in heavy operating conditions.Table 7 presents the power system heavy operating conditions.In Figure 32 above, due to little perturbation of the generator turbine, the is 0.0173, 0.0172 and 0.0162 pu, and the settling time is 20, 10.24 and 4.67 fo case, PSS and ALO-based PSS with the UPFC, respectively.Therefore, the ro deviation of the ALO-based PSS-UPFC controller improves power system stabi tively compared to the base case and PSS controller in heavy operating conditio 33 presents the angle deviation in heavy operating conditions.In Figure 32 above, due to little perturbation of the generator turbine, the overshoot is 0.0173, 0.0172 and 0.0162 pu, and the settling time is 20, 10.24 and 4.67 s for the base case, PSS and ALO-based PSS with the UPFC, respectively.Therefore, the rotor speed deviation of the ALO-based PSS-UPFC controller improves power system stability effectively compared to the base case and PSS controller in heavy operating conditions.Figure 33 presents the angle deviation in heavy operating conditions.The angle deviation of the system in the base case is oscillatory, but when UPFC-PSS is used, the system diminishes the oscillations and attains a steady s Therefore, using an ALO-based UPFC damping controller improves power system bility effectively.When a deviation in the rotor angle is exposed to a negative change machine attains a steady state.Figure 34 presents the rotor angle of the base case and PSS with the UPFC under heavy loading.The angle deviation of the system in the base case is oscillatory, but when the UPFC-PSS is used, the system diminishes the oscillations and attains a steady state.Therefore, using an ALO-based UPFC damping controller improves power system stability effectively.When a deviation in the rotor angle is exposed to a negative change, the machine attains a steady state.Figure 34 presents the rotor angle of the base case and the PSS with the UPFC under heavy loading.Based on the angle stability, the machine achieves inter-area mode or inter-area o cillation.Subsequently, δ decreases after a maximum value then the machine reaches normal value.Using PSS has a settling time of 69.3%, and the ALO-based PSS-UPFC ha settling time of 83.1%.

Simulation Results in Light Operating Conditions
A rapid change in load is considered as a disturbance.Table 8, shown below, re resents the overshoot and settling time in light operating conditions.Based on the angle stability, the machine achieves inter-area mode or inter-area oscillation.Subsequently, δ decreases after a maximum value then the machine reaches its normal value.Using PSS has a settling time of 69.3%, and the ALO-based PSS-UPFC has a settling time of 83.1%.

Simulation Results in Light Operating Conditions
A rapid change in load is considered as a disturbance.Table 8, shown below, represents the overshoot and settling time in light operating conditions.Figure 35 above is due to the perturbation of the generator turbine in which the maximum overshoot of speed deviation changes from 0.0172, 0.0171 and 0.0160 pu and a settling time of 20, 9.87 and 4.24 s for the base case, PSS only and PSS-UPFC, respectively.Generally, the speed deviation of the proposed system presents improved damping when compared to the base case and PSS-only controller.Figure 36   When the rotor angle deviation is exposed to a change in the angle then the a power is exposed to a change in power, and the machine is not stable, but the angl machine achieves is its normal value.Figure 37 presents the rotor angle of the base and the PSS with the UPFC in light loading conditions.When the rotor angle deviation is exposed to a change in the angle then the power is exposed to a change in power, and the machine is not stable, but the an machine achieves is its normal value.Figure 37 presents the rotor angle of the ba and the PSS with the UPFC in light loading conditions.When the rotor angle deviation is exposed to a change in the angle then the active power is exposed to a change in power, and the machine is not stable, but the angle the machine achieves is its normal value.Figure 37 presents the rotor angle of the base case and the PSS with the UPFC in light loading conditions.The rotor angle is about 2.25, 2.24 and 2.12 rad with the base case, PSS only a PSS-UPFC, respectively.Generally, during light loading conditions, the proposed syst has better-damping behavior to improve power system stability under disturbance.general, if the settling time is more, the power system stability improvement is le Therefore, the simulation results reveal that the fine-tuning of the damping controll demonstrates their superiority over the improper sizing of the base case system.

General Description of Results
Figures 28, 31 and 34 show the maximum overshoot and settling time of speed viation in normal, heavy and light loading conditions.The figures look similar, but magnitude of the maximum overshoot and settling time is different.The above Tables 8 clearly show the magnitude of the maximum overshoot and settling time of norm heavy and light loading conditions, respectively.
In addition, Figures 29, 32 and 35 show the maximum overshoot and settling time rotor angle deviation in normal, heavy and light loading conditions.The figures also lo similar, but the magnitude of the maximum overshoot and settling time is different.T above Tables 6-8 also clearly show the magnitude of the maximum overshoot and s tling time of rotor angle deviation in normal, heavy and light loading conditions, resp tively.
Further, Figures 30, 33 and 36 show the maximum overshoot and settling time of rotor angle in normal, heavy and light loading conditions.The figures also look simi but the magnitude of the maximum overshoot and settling time is different.The abo Tables 6-8 also clearly show the magnitude of the maximum overshoot and settling ti of the rotor angle in normal, heavy and light loading conditions, respectively.Genera to know the difference between all these figures, carefully observe the magnitude of maximum overshoot and settling time from the above tables.The rotor angle is about 2.25, 2.24 and 2.12 rad with the base case, PSS only and PSS-UPFC, respectively.Generally, during light loading conditions, the proposed system has better-damping behavior to improve power system stability under disturbance.In general, if the settling time is more, the power system stability improvement is less.Therefore, the simulation results reveal that the fine-tuning of the damping controllers demonstrates their superiority over the improper sizing of the base case system.

General Description of Results
Figures 28, 31 and 34 show the maximum overshoot and settling time of speed deviation in normal, heavy and light loading conditions.The figures look similar, but the magnitude of the maximum overshoot and settling time is different.The above Tables 6-8 clearly show the magnitude of the maximum overshoot and settling time of normal, heavy and light loading conditions, respectively.
In addition, Figures 29, 32 and 35 show the maximum overshoot and settling time of rotor angle deviation in normal, heavy and light loading conditions.The figures also look similar, but the magnitude of the maximum overshoot and settling time is different.The above Tables 6-8 also clearly show the magnitude of the maximum overshoot and settling time of rotor angle deviation in normal, heavy and light loading conditions, respectively.Further, Figures 30, 33 and 36 show the maximum overshoot and settling time of the rotor angle in normal, heavy and light loading conditions.The figures also look similar, but the magnitude of the maximum overshoot and settling time is different.The above Tables 6-8 also clearly show the magnitude of the maximum overshoot and settling time of the rotor angle in normal, heavy and light loading conditions, respectively.Generally to know the difference between all these figures, carefully observe the magnitude of the maximum overshoot and settling time from the above tables.Figures 38 and 39 show the maximum overshoot and settling time of the speed deviation and rotor angle in normal, heavy and light loading conditions.These figures look similar, but the magnitude of the maximum overshoot and settling time is different.To identify the difference between Figures 38 and 39, clearly observe the magnitude of the maximum overshoot and settling time.

Conclusions
The proposed PSS-UPFC approach was quite compatible to investigate dynamic stability in terms of the presented results.Moreover, the proposed technique needs a very small tuning time to estimate the main parameters of the objective functions provided.Thus, the robustness, efficiency and convergence criteria of the system have established that the applied technique improves dynamic stability.In addition, heftiness analysis was carried out by changing the operating conditions.The efficiency of the proposed PSS-UPFC controller for system stability was confirmed using the Tana Beles 400 kV line.As the Tana Beles 400 kV transmission line is sensitive to low-frequency oscillation, this method is applied to maintain the stability of the Ethiopian power system.The time domain and eigenvalue analyses present the robustness of the proposed PSS and UPFC system.Generally, when the PSS-UPFC is used for power system stability, a maximum overshoot of 12.67% and settling time of 79.8% improvement is obtained, but when only the PSS is used, the maximum overshoot is 1.78%, and a settling time of 48.15% improvement is made.This means that when we use the PSS-UPFC, the stability of the power system is improved by 12.67% maximum overshoot, and a 79.8% improvement is made for the settling time.However, for the PSS, the maximum overshoot is improved by only 1.78%, and the settling time is improved by only 48.15%.Figures 38 and 39 show the maximum overshoot and settling time of the speed deviation and rotor angle in normal, heavy and light loading conditions.These figures look similar, but the magnitude of the maximum overshoot and settling time is different.To identify the difference between Figures 38 and 39, clearly observe the magnitude of the maximum overshoot and settling time.

Conclusions
The proposed PSS-UPFC approach was quite compatible to investigate dynamic stability in terms of the presented results.Moreover, the proposed technique needs a very small tuning time to estimate the main parameters of the objective functions provided.Thus, the robustness, efficiency and convergence criteria of the system have established that the applied technique improves dynamic stability.In addition, heftiness analysis was carried out by changing the operating conditions.The efficiency of the proposed PSS-UPFC controller for system stability was confirmed using the Tana Beles 400 kV line.As the Tana Beles 400 kV transmission line is sensitive to low-frequency oscillation, this method is applied to maintain the stability of the Ethiopian power system.The time domain and eigenvalue analyses present the robustness of the proposed PSS and UPFC system.Generally, when the PSS-UPFC is used for power system stability, a maximum overshoot of 12.67% and settling time of 79.8% improvement is obtained, but when only the PSS is used, the maximum overshoot is 1.78%, and a settling time of 48.15% improvement is made.This means that when we use the PSS-UPFC, the stability of the power system is improved by 12.67% maximum overshoot, and a 79.8% improvement is made for the settling time.However, for the PSS, the maximum overshoot is improved by only 1.78%, and the settling time is improved by only 48.15%.Figures 38 and 39 show the maximum overshoot and settling time of the speed deviation and rotor angle in normal, heavy and light loading conditions.These figures look similar, but the magnitude of the maximum overshoot and settling time is different.To identify the difference between Figures 38 and 39, clearly observe the magnitude of the maximum overshoot and settling time.

Conclusions
The proposed PSS-UPFC approach was quite compatible to investigate dynamic stability in terms of the presented results.Moreover, the proposed technique needs a very small tuning time to estimate the main parameters of the objective functions provided.Thus, the robustness, efficiency and convergence criteria of the system have established that the applied technique improves dynamic stability.In addition, heftiness analysis was carried out by changing the operating conditions.The efficiency of the proposed PSS-UPFC controller for system stability was confirmed using the Tana Beles 400 kV line.As the Tana Beles 400 kV transmission line is sensitive to low-frequency oscillation, this method is applied to maintain the stability of the Ethiopian power system.The time domain and eigenvalue analyses present the robustness of the proposed PSS and UPFC system.Generally, when the PSS-UPFC is used for power system stability, a maximum overshoot of 12.67% and settling time of 79.8% improvement is obtained, but when only the PSS is used, the maximum overshoot is 1.78%, and a settling time of 48.15% improvement is made.This means that when we use the PSS-UPFC, the stability of the power system is improved by 12.67% maximum overshoot, and a 79.8% improvement is made for the settling time.
However, for the PSS, the maximum overshoot is improved by only 1.78%, and the settling time is improved by only 48.15%.

Recommendation
It is strongly recommended that the northwest region of the Ethiopian power system should use a UPFC to reduce low-frequency oscillations and related problems to minimize system instability.Using a UPFC at the Bahir Dar substation is important for damping out the LFO caused by the number of overloaded lines.Additionally, very little research has been undertaken in the area of designing a control system and operation of UPFC.The main difficulty in using a UPFC is the complexity of its controller.Therefore, researchers should do a lot to reduce the complexity of its controller and recommend power companies to use.

Figure 1 .
Figure 1.One-line representation of the overall transmission line with UPFC.

Figure 1 .
Figure 1.One-line representation of the overall transmission line with UPFC.

Figure 1 .
Figure 1.One-line representation of the overall transmission line with UPFC.

Figure 8 .
Figure 8. UPFC with damping controller and DC voltage regulator.

Figure 9 Figure 9 .
Figure 9 below shows the UPFC with damping controller and PSS:

Figure 9 .
Figure 9. UPFC with damping controller.In this case, ∆u is either m E , m B , δ E or δ B .Figure10presents the UPFC controller with POD and DC voltage regulator.

51 )Figure 9 Figure 9 .
Figure 9 below shows the UPFC with damping controller and PSS:

Figure 30 Figure 14 .
Figure Eigenvalues in light loading conditions.

Figure 16 .
Figure 16.Eigenvalues with PSS only in normal operating conditions.

Figure 17 .
Figure 17.Eigenvalues with PSS only in light operating conditions.

Figure 17 .
Figure 17.Eigenvalues with PSS only in light operating conditions.

Figure 18 .
Figure 18.Eigenvalues with PSS only in heavy operating conditions.

Figure 18 .
Figure 18.Eigenvalues with PSS only in heavy operating conditions.

Figures 19 -
Figures 19-21 describe the eigenvalues with the PSS-UPFC in different operating conditions.These figures are clearly presented in Table4above with their specific locations of eigenvalues.

Figure 17 .
Figure 17.Eigenvalues with PSS only in light operating conditions.

Figure 18 .
Figure 18.Eigenvalues with PSS only in heavy operating conditions.

Figures 19 -
Figures 19-21 describe the eigenvalues with the PSS-UPFC in different operat conditions.These figures are clearly presented in Table4above with their specific lo tions of eigenvalues.

Figures 22 and 23
Figures 22 and 23 describe the results of the UPFC parameters.

Figures 22 and 23
Figures 22 and 23 describe the results of the UPFC parameters.

Figure 22 .
Figure 22.Modulation index of series (m B ) and shunt converter (m E ).

Figures 22 and 23
Figures 22 and 23 describe the results of the UPFC parameters.
presents the positive voltage (a), real power (b) and reactive power of each bus (c).

Figure
Figure (a) Voltage, (b) active and (c) reactive power using UPFC.

Figure 27
Figure27above shows that the angle deviation of the proposed ALO technique has less maximum overshoot and settling time than the other applied methods.Therefore, the proposed ALO technique takes less time for the damping of LFO and attains a steady-state system.

Figure 28 .
Figure 28.Overshoot and settling time of rotor angle.

Figure 28 .
Figure 28.Overshoot and settling time of rotor angle.

Figure 29 .
Figure 29.Speed deviation of the system in normal loading conditions.Figure 29.Speed deviation of the system in normal loading conditions.

Figure 29 .
Figure 29.Speed deviation of the system in normal loading conditions.Figure 29.Speed deviation of the system in normal loading conditions.

Figure 29 .
Figure 29.Speed deviation of the system in normal loading conditions.

Figure 31 .
Figure 31.Rotor angle of base case and PSS with UPFC under normal loading.

Figure 31 .
Figure 31.Rotor angle of base case and PSS with UPFC under normal loading.

Sustainability 2023 ,Figure 32 .
Figure 32.Generator rotor speed deviation in heavy operating conditions.

Figure 32 .
Figure 32.Generator rotor speed deviation in heavy operating conditions.

Figure 32 .
Figure 32.Generator rotor speed deviation in heavy operating conditions.

Figure 33 .
Figure 33.Angle deviation in heavy operating conditions.

Figure 33 .
Figure 33.Angle deviation in heavy operating conditions.

Sustainability 2023 ,Figure 34 .
Figure 34.Rotor angle of base case and PSS with UPFC in heavy operating conditions.

Figure 35 .
Figure35above is due to the perturbation of the generator turbine in which the maximum overshoot of speed deviation changes from 0.0172, 0.0171 and 0.0160 pu and a settling time of 20, 9.87 and 4.24 s for the base case, PSS only and PSS-UPFC, respectively.Generally, the speed deviation of the proposed system presents improved damping when compared to the base case and PSS-only controller.Figure36presents the rotor angle deviation in light operating conditions.Sustainability 2023, 15, x FOR PEER REVIEW 26

Figure 36 .
Figure 36.Angle deviation in light operating conditions.

Figure 36 .
Figure 36.Angle deviation in light operating conditions.

Figure 36 .
Figure 36.Angle deviation in light operating conditions.

Sustainability 2023 ,Figure 37 .
Figure 37. Rotor angle of base case and PSS with UPFC at light loading.

Figures
Figures 38 and 39 present the maximum overshoot and settling time in numero operating conditions.

Figure 37 .
Figure 37. Rotor angle of base case and PSS with UPFC at light loading.

Figures
Figures 38 and 39 present the maximum overshoot and settling time in numerous operating conditions.

Figure 38 .
Figure 38.Time domain simulation of rotor speed deviation.

Figure 39 .
Figure 39.Time domain simulation of rotor angle.

Figure 39 .
Figure 39.Time domain simulation of rotor angle.

Figure 39 .
Figure 39.Time domain simulation of rotor angle.

Table 1 .
Power system stabilizer parameter limits.

Table 2 .
Optimal values of PSS.

Table 2 .
Optimal values of PSS.
Figure 12.Structure of PSS using ALO.

Table 3 .
Eigenvalues of base case system in different operating conditions.

Table 3 .
Eigenvalues of base case system in different operating conditions.

Table 3 .
Eigenvalues of base case system in different operating conditions.

Table 4 .
PSS and UPFC-POD parameters using different approaches.

Table 4 .
PSS and UPFC-POD parameters using different approaches.

Table 4 .
PSS and UPFC-POD parameters using different approaches.
Table 5 presents values which are illustrated in Figures 26-28 shown below.In Table 5 below, the maximum overshoot and settling time of the ALO optimization technique are more accurate than and superior to the remaining techniques.The simulation results clearly ex-

Table 5 .
The comparison of different optimization methods for power system states.

Table 5 .
The comparison of different optimization methods for power system states.

Table 6 .
Power system states in normal operating conditions.
presents the rotor angle deviation of the system in normal operating conditions.

Table 7 .
Power system states in heavy operating conditions.

Table 7 .
Power system states in heavy operating conditions.

Table 8 .
System states in light operating conditions.Figure 34.Rotor angle of base case and PSS with UPFC in heavy operating conditions.

Table 8 .
System states in light operating conditions.