Certainly, the perspective of the system operator is always a good one to solicit in terms of looking to see how these resources are being deployed in the market and at what marginal cost.
There's been a lot of learning in Ontario in terms of adapting to variable generation, generation that isn't on demand when you need it. For example, one of the things, the evolutions, that we've seen in the market is the manoeuvring of nuclear, particularly at the Bruce Power asset in Kincardine.
The system has adapted quite a bit, and there are new tools in place to better predict, not only when that variable generation will be able to supply into the market but also how the system operator is optimizing the use of those assets to lower costs. We're seeing that this is continuing. The technology is evolving quite a bit.
I'll pick up on a comment that Lisa made about storage and the opportunities for storage. Obviously, part of the challenge with any electrical system is that when you supply the electricity, it might not align perfectly with when you require it. Of course, the thing about electricity is that it's all about physics, in terms of the creation of the electrons and when they're actually consumed. The opportunity that lies in harnessing storage is quite vast in terms of helping to level the balance of the system between periods of high demand, or as we refer to it “on the peak”, and periods of low demand, or the “off peak”.
In the context of interties, which I know is the subject matter for this committee, they have always been used by the system operators as “virtual storage”, in their ability to transmit electricity across the tie lines to maintain reliability in the system. You move electricity out of your market when you don't need it, to a market that might require it and vice versa. We see that quite a bit between Ontario and Quebec, but we see it between Ontario and New York, and Ontario and Michigan as well. That's something that will increase, we predict, in the future as well.