Since the rise of green energy, many countries have seen a growing share of renewable sources in their electricity mix. Critics often argue that renewables are "unstable," but this perception is increasingly outdated. With advanced satellite imagery and improved weather forecasting, grid operators now have more accurate insights into cloud cover and wind patterns. Even when solar output drops due to clouds or wind power decreases due to lulls, the grid can anticipate these changes and respond proactively. There's no true sudden instability—rather, the problem lies not with the energy itself, but with the lack of traditional "stable power."
Traditional "stable power" comes from large rotating machines like turbines and flywheels that are synchronized with the grid’s AC frequency. These devices have massive inertia, which helps maintain grid stability during sudden disturbances. For example, if a power plant trips or a unit fails, the grid frequency may dip. The inertia of these rotating machines resists the drop, allowing them to instantly boost output and stabilize the frequency, giving operators time to react and prevent blackouts.
Solar power lacks this built-in stability, and even wind turbines, despite their large rotating masses, aren’t directly connected to the grid in the same way. As a result, they haven't traditionally been considered "stable." However, modern technology has changed that. Wind turbines can now simulate inertial response by intentionally slowing down and then rapidly increasing output, a process known as "synthetic inertia." This innovation addresses one of the main concerns about renewable integration: grid stability.
Synthetic inertia isn’t without its costs. When a turbine slows down to provide extra power, it uses up kinetic energy, and the speed must be restored later. If not managed properly, this could lead to further instability. For instance, if too much energy is drawn during recovery, it might cause a second crisis. That’s why the latest developments in synthetic inertia include safeguards to limit how much energy is used during re-acceleration, preventing additional problems.
One of the earliest real-world applications of synthetic inertia was in Quebec, Canada. Hydro-Québec, the country’s largest electricity transmission company, became the first grid operator to actively manage synthetic inertia. With 3,300 MW of wind capacity on its grid, Quebec faces unique challenges due to its relatively small size. Any disruption can have a significant impact, making stability a top priority.
Since 2005, Quebec has required wind turbines to contribute synthetic inertia in case of frequency drops. By 2011, the first wind turbines with this feature were online, manufactured by companies like Suzlon, Senvion, and Enercon. Today, two-thirds of the wind turbines on the Quebec grid are equipped with synthetic inertia.
In December 2015, the system was tested when a major substation failure caused a 1,600 MW power loss. The synthetic inertia from the wind turbines provided 126 MW of emergency support, keeping the grid frequency from dropping too low. Without it, the frequency would have dropped an additional 0.1–0.2 Hz. This proved that synthetic inertia can perform just as well as traditional inertia during the initial phase of a crisis.
However, during the recovery phase, some turbines had to slow down significantly to regain speed, which delayed the grid’s return to normal frequency. To address this, Quebec now limits how much wind energy can be used during recovery, capping it at 20% of the turbine’s rated capacity.
The Quebec experience shows that wind turbines with synthetic inertia can act as a reliable "stability force," just like traditional power plants. As more wind farms adopt this technology, the perception of wind energy as unstable will gradually fade. This is a major step forward for both grid operators and the wind energy industry, ensuring a smoother transition to a cleaner, more resilient energy future.
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