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Power System Dynamics

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1350 min

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Electrical Engineering

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Why enroll

Participants join this course to understand how power systems behave during disturbances and faults. It helps students build a strong conceptual base required for higher studies, research, and careers in power system analysis and operation.

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5+ yrs experience·India

Is this course for you?

You should take this if

You work in Energy & Utilities
You're a Electrical Engineering / Power Plant Engineering professional
You have 3+ years of hands-on experience in this field
You want to build skills in Engineering & Design

You should skip if

You're new to this field with no prior experience
You need a different specialisation outside Electrical Engineering
You need live interaction with an instructor

Course details

This course introduces the basic ideas of power system dynamics and stability in a clear and easy way. It explains what power system stability means and why it is important for the safe and reliable operation of electric power systems. The course discusses the different types of stability problems that can occur when a system is disturbed by faults or sudden load changes. Students learn about rotor dynamics and how generators respond to these disturbances. The swing equation is introduced to describe the motion of generator rotors in a simple mathematical form. The course also explains how power systems are modeled for dynamic studies. Basic mathematical models of generators and power systems are covered without heavy complexity. Numerical methods used to solve dynamic equations are introduced step by step. Real-world operating challenges and stability issues are highlighted through practical examples. By the end, learners gain a strong foundation for understanding advanced power system stability topics.

Source: nptelhrd [Youtube Channel]

Course suitable for

Key topics covered

Introduction to Power System Stability Problem – Part 1
Introduction to Power System Stability Problem – Part 2
Introduction to Power System Stability Problem – Part 3
Solution of Switching Equation
The Equal Area Criterion for Stability – Part 1
The Equal Area Criterion for Stability – Part 2
Transient Stability Analysis of a Multi Machine System
Modeling of Synchronous Machine – Part 1
Modeling of Synchronous Machine – Part 2
Modeling of Synchronous Machine – Part 3
Modeling of Synchronous Machine – Part 4
Synchronous Machine Representation for Stability Studies – Part 1
Synchronous Machine Representation for Stability Studies – Part 2
Excitation Systems – Part 1
Excitation Systems – Part 2
Modeling of Excitation Systems – Part 1
Modeling of Excitation Systems – Part 2
Small Signal Stability of a Single Machine Infinite Bus System – Part 1
Small Signal Stability of a Single Machine Infinite Bus System – Part 2
Small Signal Stability of a Single Machine Infinite Bus System – Part 3
Small Signal Stability of a Single Machine Infinite Bus System – Part 4
Small Signal Stability of a Single Machine Infinite Bus System – Part 5
Dynamic Modeling of Steam Turbines and Governors
Dynamic Modeling of Hydro Turbines and Governors
Load Modeling for Stability Studies

Course content

The course is readily available, allowing learners to start and complete it at their own pace.

25 lectures22 hr 30 min

Introduction to Power System Stability Problem-Part-1
52 min
Introduction to Power System Stability Problem-Part-2
52 min
Introduction to Power System Stability Problem-Part-3
41 min
Solution of Switching Equation
59 min
The Equal Area Criterion for Stability-Part-1
52 min
The Equal Area Criterion for Stability-Part-2
57 min
Transient Stability Analysis of a Multi Machine System
51 min
Modeling of Synchronous Machine-Part-1
55 min
Modeling of Synchronous Machine-Part-2
55 min
Modeling of Synchronous Machine-Part-3
58 min
Modeling of Synchronous Machine-Part-4
54 min
Synchronous Machine Representation for Stability Studies-Part-1
55 min
Synchronous Machine Representation for Stability Studies-Part-2
56 min
Excitation Systems-Part-1
58 min
Excitation Systems-Part-2
52 min
Modeling of Excitation Systems-Part-1
56 min
Modeling of Excitation Systems-Part-2
56 min
Small Signal Stability of a Single Machine Infinite Bus System-Part-1
52 min
Small Signal Stability of a Single Machine Infinite Bus System-Part-2
55 min
Small Signal Stability of a Single Machine Infinite Bus System-Part-3
57 min
Small Signal Stability of a Single Machine Infinite Bus System-Part-4
58 min
Small Signal Stability of a Single Machine Infinite Bus System-Part-5
56 min
Dynamic Modeling of Steam turbines and Governors
51 min
Dynamic modeling of Hydro Turbines and Governors
47 min
Load modeling for Stability Studies
55 min

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Questions and Answers

Q: You're reviewing a protection log after a nuisance trip and you google "generator loss of excitation relay failure physical consequence". The LOE relay was blocked during testing and never re-enabled. What hazard does this safeguard NOT protect against once it's disabled?

A: The boundary here is excitation state, not network resonance. Loss of excitation protection acts when field current collapses and the machine pulls vars, heating the rotor and risking pole slip. Sub-synchronous resonance is a line-compensation and shaft-system issue; LOE logic doesn't see it, blocked or not.

Q: During grid-code review you search "IEEE 1547 ride through frequency threshold why required". A DER inverter trips at 59.3 Hz after 300 ms. Why does IEEE 1547 require a minimum ride-through window instead of immediate trip?

A: The hard number is the UFLS timing. Grid events dip below 59.5 Hz briefly while load is shed; instant trips would remove generation when it's needed. The standard forces ride-through so DERs don't amplify a bulk system event.

Q: After 40,000 km field returns, you google "EV traction inverter oscillation at constant torque root cause". Vehicles show audible whine and DC bus ripple only at steady cruise, not during accel. What's the most likely root cause?

A: The frequency matters. A lightly damped LCL will sing at a fixed operating point and show up as DC ripple and audible noise. Transient-only issues point elsewhere, but this one lives at steady state.

Q: It's 02:00, the substation is energised, and you search "pre-commissioning generator AVR step response field test sequence". What do you verify first to avoid a forced outage?

A: The trip point is wrong feedback. A reversed or mis-scaled PT will drive the AVR unstable the moment auto is enabled. Step tests and limits come later, once the loop is sane.