The note about ramping faster than the hydro units is something else. I've had to standby while Diablo would ramp & that was a painful experience lol. Several of my hydro stations can ramp from bottom to the top of their range in 1-2min.
Several years ago now WECC experienced a large disturbance that knocked offline every large generator in CA. It was the hydro & smaller CT's that were able to ride through & keep portions of the system online (including most of the geothermal at the Geysers).
So, Bruce is about 300km from the GTA and has a large swath of 500kV lines running from it into the GTA (and a few more local 230kV lines that run to closer load centres). When Bruce was built, it was on the site of Canada's first "large scale" (220MWe) nuclear reactor, at Douglas Point. The site is a sprawling 2,500 acres and was originally planned for 16 reactors: Bruce A/B/C/D.
The original transmission corridor from the Bruce, given the weather conditions experienced on the shores of Lake Huron, was somewhat fragile and not sized adequately to handle the total generation the site was capable of producing.
The Bruce A units were oversized thermally, with 750MWe electrical sides with process steam being diverted to various operations around the grounds including district heating and running the developing crop of heavy water plants that were being constructed. The Bruce Energy Centre was also privy to this process steam, which was planned to be able to be used to heat greenhouses and other benefits.
The Bruce B units featured the same reactor cores but without the steam drum arrangement present on the A units and no process steam production. These units were originally rated at 860MWe.
Because of its location and expectation of regular transmission interruptions (and inadequacy) the Bruce plant was both designed, and operated around the concept of flexibility. The premise that the plant was going to experience disturbances and load rejections and would need to ride them out, with the ability to island indefinitely if required. The operators of this behemoth, which, at the time, with all 8 units operational was 6,440MWe, were dubbed "Cowboys", since it wasn't uncommon for them to be riding these units through major disturbances and doing so successfully.
So, when we had the grid collapse in 2003, it was just "another day" for the Bruce group. They islanded the units and waited for a call from the IESO as to what the plan was. The IESO called them, as expected, and they said they had 3x units (all B units, one was offline for maintenance and A was not restarted yet at this point) hot and ready to go. These were the building blocks used to bring the grid back up, in conjunction with Niagara, Lennox and other large generators. Darlington was also brought back up and used later on in the restorative process, though it was not used for the initial black start because the units had been shutdown after initially islanding. Pickering units don't have steam bypass like the Bruce and Darlington (based on Bruce) units do, so it had to shutdown.
Every plant that was planned after Bruce was based on the standardized CANDU 9 design (Darlington), which had been developed and refined at Bruce. 8 units were planned for Darlington, another 8 for Wesleyville, the aforementioned 16 at the Bruce site. Hydro's plans were predicated on a steady >3% load growth rate that never materialized after the economic collapse in the 80's. Darlington B was never built and the other sites lay dormant. It isn't until now, decades later, that Darlington B is back on the table, along with Bruce C and Wesleyville.