What triggered it: Multiple sudden GW-scale load drops at data centers on the East Coast and in Texas in 2024-25. These unfolded in seconds—too speedy for real-time response—straining transformers, generators, and overall grid stability.

The plan: NERC aims to register companies with computational loads >20 MW (read: Amazon, Google, Meta). The end goal? Data center reliability standards on par with those for power plants, which could become mandatory with FERC approval. 

In the meantime: NERC has laid out “essential actions” for grid operators, including data center monitoring and grid scenario modeling, along with non-binding risk mitigation guidelines.

On turf: Over 150 wind projects planned for private land are stuck in Pentagon purgatory. Its cited rationale: national security. Sound familiar? It’s the same justification wielded for Trump’s now-defeated offshore project work delays.

On surf: The 2.6-GW Coastal Virginia Offshore Wind project is around 75% complete and on track to wrap up in June 2027. The capex estimate actually fell slightly to $11.4B after the stop-work order was lifted and SCOTUS scrapped President Trump's sweeping tariffs.

Last month, TerraPower kicked off construction on its 345-MW sodium-cooled fast reactor, and it’s on track to bring the country’s first utility-scale advanced nuclear plant online. The company has an agreement with Meta for up to eight Natrium plants by 2035.

Construction is also underway at what could become the first SMR in a G7 nation. OPG is building the first of four planned GE Hitachi BWRX-300s at Canada’s Darlington New Nuclear Project, targeting grid connection for unit one by year-end 2030.

While we’re here: The NRC recently announced Part 57, a streamlined licensing pathway for microreactors. It could compress construction permit and operating license timelines to under a year. The agency estimates $3.76B–$11.84B in industry cost savings.

The pitch: The enhanced geothermal developer applies horizontal drilling and multi-stage hydraulic fracturing—borrowed straight from the shale playbook. Fervo says it cut drilling times by 75% and drilling costs by 70% from 2022 to 2025. 

The pipeline: Fervo's full portfolio includes 2.6 GW in advanced development, 38+ GW in the early stages, and $7.2B in potential revenue from PPAs (including agreements with SCE, Google, and Shell).

As worker shortages loom and Trump pushes for US “energy dominance,” the administration is pouring funding into training and credentialing programs for the natural gas, oil, coal, and geothermal industries (no mention of wind and solar).

The new math: The region’s annual consumption will climb 9% by 2035, hitting 128 TWh—down from last year's 11% projection and the 17% it pegged in 2024. The grid operator’s explanation? "More conservative assumptions" on EV and heat pump adoption following federal incentive rollbacks and state policy tweaks.

Dual peaks ahead: Heating electrification is set to push winter peaks to roughly match summer's by 2035, both landing near 26.5 GW.

The context: North Carolinians’ electric bills have climbed an average of 22% since 2020, and Duke is asking for another 15%+ residential hike. In March, customers urged an audit of Duke’s rates.

The breakdown: The credits—earned through nuclear and solar investments and expected to pile up through 2029—will split $2B for Duke Energy Carolinas, $700M for Duke Energy Progress, and $350M for the company’s Florida operations. The buyer? An undisclosed third party.

The long game: Duke also estimates $2.3B in savings from 2027-40 by consolidating its two Carolinas units, which state regulators signed off on last week. Duke says “all savings will flow to customers.”