The six-page paper examines both time-related (intermittency) and location-related (geographical) constraints impacting DER integration, including a framework to minimize their impact. It offers suggestions on how to begin the integration process and also takes a look at IEEE Standard 1547, the de-facto interconnection standard for DERs in North America.
A snippet of the report is presented here:
Whether a utility is adding conventional or renewable distributed energy resources (DERs) to their system, successful integration requires a fundamentally different approach than when adding conventional base load generation.
This is especially true if the penetration level of such generation is already large or expected to increase significantly in the not-too-distant future. In all likelihood, the proliferation of DERs (solar, wind, combined heat and power, microgrids, energy storage, and someday even electric vehicles) will necessitate the development of a smarter grid – one that can coordinate and balance these various technologies under a variety of operational constraints to: a) mitigate technical challenges such as the variability of renewable generation; b) support grid stability and reliability; and c) maximize benefits to consumers and other stakeholders.
In spite of the challenges utilities confront in creating a smart grid, the effort promises significant benefits above and beyond the expansion of renewable energy. As a recent report for the California Energy Commission (CEC) notes: “The investment in doing so… is desirable or even necessary for reasons other than reducing carbon emissions – namely, economy and reliability of electric service.”
The full report can be read at this link.
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