Suppressing subsynchronous resonance with static filters

Limebeer, D.J.N.; Harley, R.G.; Lahoud, M.A.

doi:10.1049/ip-c.1981.0006

Cited by 9 publications

(3 citation statements)

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“…Figs. 6, 9 and 11 are calculated for only one generator as a base case which is the same station representation that has been used in the previous studies [1][2][3][4][5][6][7][8][9][10][11]. Figs.…”

Section: Resultsmentioning

confidence: 99%

“…The present line is rated at 400 kV and is equipped with series capacitor compensation. The possibility of subsynchronous resonance (SSR) occurring in this system has been investigated and reported elsewhere [1]; this first paper has been followed by many others dealing with topics such as system modelling, multi-machine SSR and possible SSR countermeasures [2][3][4][5][6][7][8][9][10][11]. All previously reported investigations were based only on the first 1072 MVA generator at this power station; however, a second identical generator is currently being commissioned.…”

Section: Introductionmentioning

confidence: 99%

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Subsynchronous resonance of a power station with two identical generating units

Jennings

Harley

Levy

1986

IEE Proc. C Gener. Transm. Distrib. UK

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The paper investigates the effect of adding a second 1072 MVA turbogenerator to an existing one in a power station feeding a series capacitor compensated transmission line. In carrying out the investigation, the new two-generator system is modelled as one equivalent generator with increased capacity, and also as a multimachine system with two separate generators. A comparison of these models shows that, for this type of stability study and this transmission system configuration, there is no advantage gained in modelling the two generators separately rather than as one equivalent generator. The results further show that conditions can exist where the system is stable with one generator but unstable with two, and vice versa. List of principal symbols d, q = d, g-axis of a machine rotating reference frame D, Q = D, Q-axis of the synchronously rotating reference frame [D] = shaft damping matrix [G] = rotational voltage inductance matrix H = inertia constant in seconds i = vector of axis currents [/] = identity matrix [J] = shaft inertia matrix [X] = shaft stiffness matrix [L] = machine inductance matrix N = compensation level p = derivative operator d/dt P t = generator terminal power [A] = machine resistance matrix s ( = ith natural frequency T = forcing torque vector T e = electric torque T m = shaft mechanical torque v = vector of axis voltages V b = infinite bus voltage V t = generator terminal voltage H>,-= ith mode shape vector X c = transmission line capacitive reactance 0 = null vector q> = flux linkage A = small change operator ) H = ith eigenvalue 8 = rotor angle vector co 0 = system frequency in rad/s (electrical) co = angular velocity of rotor in rad/s (electrical)

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Section: Resultsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Subsynchronous resonance of a power station with two identical generating units

Jennings

Harley

Levy

1986

IEE Proc. C Gener. Transm. Distrib. UK

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“…2) Case 2: Line Impedance Change: The effects of changes in transmission system impedance on system stability have been reported in the technical literature [23]. In this section, the effect of such changes (rather than load scaling, as in case 1) on the system stability is studied and the application of the proposed operating point tuning method to stabilize the system, subsequent to a line outage, is demonstrated.…”

Section: B Case Studies On the 3-segment Systemmentioning

confidence: 98%

Dynamic Stability Enhancement of a DC-Segmented AC Power System Via HVDC Operating-Point Adjustment

Azad

Iravani

Tate

2015

IEEE Trans. Power Delivery

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Hopf bifurcation phenomenon of a power system results in oscillatory dynamics which can lead to instabilities in the system. Therefore, it is desirable to operate the system such that a sufficient margin to Hopf bifurcation is ensured. This paper presents a methodology based on the adjustment of the setpoint values of the HVDC link controllers, to prevent instability or increase the stability margin of the system subject to Hopf bifurcation. In this paper, the first-order sensitivities of the Hopf stability margin to the setpoint values of the HVDC links are presented. These sensitivities identify the optimum direction to change the HVDC setpoints to steer the system away from instability, increase the stability margin, and improve the damping of oscillatory modes. The proposed method is evaluated on various system configurations subject to Hopf bifurcation phenomena caused by a variety of events, such as load and line impedance variations. Simulation results show that at the optimum operating point, for a variety of Hopf bifurcations, the stability margin and damping of the oscillatory modes improve.Index Terms-HVDC transmission control, power system control, power system dynamic stability.

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2021

Power System Protection

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Suppressing subsynchronous resonance with static filters

Cited by 9 publications

References 1 publication

Subsynchronous resonance of a power station with two identical generating units

Subsynchronous resonance of a power station with two identical generating units

Dynamic Stability Enhancement of a DC-Segmented AC Power System Via HVDC Operating-Point Adjustment

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