Like maybe that means we're getting better value for money for the system and customers but also feels like a massive undercutting of the popularity and potential for expanded VPP and DER participation, especially at a time post market renewal where some hours still spike above $1000/MW.

Anyway here's hoping this kicks some of Canada in gear to get with the program already.

In Ontario (and most of Canada) we're beginning to work through what will be complicated coordination between electric utilities and Enbridge/Fortis, to determine optimal integrated energy planning. But for places with a utility that does both it might be a lot quicker and less complicated.

Another thing that's relevant is utilities that do both electric and gas. For utilities like Eversource in MA. (their Framingham geothermal pilot seems to be the BQDM project of TENs), the option to use geothermal heat networks to replace aging gas infra could mitigate pressure on electric systems.

Being able to ratebase the thermal energy network is essential for scaling alternative heating options, and would help push gas utilities toward thinking of becoming heat utilities. Many of these examples of legislation include some allowance for rate basing district heating!

Many are also quite assertive and ambitious. Washington state for ex redefines electric and gas utilities to allow them to operate TENs, and requires gas utilities to propose a TEN pilot within a year (from it's 2024 legislation).
Importantly it also allows merging rates for TENs to be rate based.