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Electrical grids across the world are undergoing a period of prolonged transformation, from centralized, utility-controlled systems with unidirectional power flows (from generators to end-users) and captive customers, to grids that are increasingly integrating Distributed Energy Resources (DERs) at the “grid edge”. The grids taking shape in the 21st century are subsequently becoming more decentralized/distributed, with bi-directional flows (of energy and data) and an ever-increasing number of “prosumers” that are capable of exporting power to the grid from their homes and/or electric vehicles.

At the same time, local- and state-level policies are increasing the presence of renewable energy sources (especially wind and solar), which is having an impact on both wholesale and retail markets, systems and reliability requirements [1]. This growth in renewables has, in turn, created new challenges and considerations for electric utilities as they make determinations for the most cost-effective strategies to modernize their distribution and transmission grids through traditional resource, transmission and distribution planning efforts [2].

One of the key drivers shaping the grid of tomorrow is the threat of climate change—in particular, the need for stakeholders of all kinds to reduce their carbon emissions. The Pacific United States’ states of Washington, Oregon and California have been relatively aggressive in addressing the challenges associated with carbon-emission reduction (compared to other state and federal parties). Having already taken some substantive steps to clean their power generation portfolios, each of the three Pacific states have now begun to target emissions from the transportation sector, which has become the lead sector in emissions in each state (for California, see [3]; for Washington, see [4]; for Oregon, see [5]). Toward this end, Electric Vehicles (EVs) are not the only solution being pursued, but they play a significant role in each state’s climate action plans. However, while these states (along with many of their larger cities and electric utilities) are developing and promoting policies meant to increase their constituents’ adoption of EVs, there are issues that must be addressed to maintain reliability and cost-effective services in light of the increasing likelihood of a scenario that will see rapid and significant market adoption of EVs over the coming decades.

From a utility (or even transmission operator) perspective, the nightmare scenario of EV penetration involves the specter of uncoordinated charging. In particular, there is concern that if all EV owners charge their vehicles at the end of a work-day, the aggregate demand could dramatically increase evening peak loads. Ultimately, uncoordinated charging introduces a dual threat of higher costs (to build more peak-serving generation) and diminished reliability of the grid (at overtaxed portions within distribution systems) [6].