Following FERC’s rejection of the amended Susquehanna Interconnection Service Agreement (Docket No. ER24-2172) and subsequent technical conference proceedings, we corrected an earlier procedural misstatement and shifted conviction toward front-of-the-meter dispatchable fleets (VST, CEG) over fast-track behind-the-meter co-location assumptions.
Demonstrates Roarable Public Correction & Revision Standards (#59) on a high-stakes FERC order governing multi-gigawatt nuclear data-center power agreements.
The Federal Energy Regulatory Commission (FERC) issued an order rejecting the proposed amended Interconnection Service Agreement (ISA) expanding co-located load at the Susquehanna nuclear facility (Docket No. ER24-2172), citing insufficient demonstration of extraordinary circumstances regarding grid reliability and transmission cost allocation.
Constellation Energy (CEG) executed a 20-year front-of-the-meter power purchase agreement with Microsoft (Crane Clean Energy Center / Three Mile Island Unit 1 restart), which connects directly through standard grid transmission tariffs rather than behind-the-meter load isolation.
FERC subsequently initiated a broader co-location and large-load interconnection review proceeding in PJM (Docket No. EL25-49 / AD24-11) to establish uniform transmission cost-allocation rules for data centers co-locating with existing generators.
Behind-the-meter co-location attempted to bypass multi-year transmission queues and network charges, triggering fierce intervention from regulated utilities (AEP, Exelon) over grid cost-shifting to residential ratepayers. By contrast, front-of-the-meter PPAs (like CEG’s Crane restart and VST’s gas + nuclear portfolio) pay full transmission tariffs while still capturing premium 24/7 clean-baseload pricing.
Investors who sold all independent power producers indiscriminately on FERC behind-the-meter headlines conflated isolated co-location tariff disputes with front-of-meter wholesale power scarcity.
Even front-of-meter merchant generators face political and regulatory pushback when PJM capacity clearing prices jump 9x and flow into consumer utility bills. Governors in PJM states have already petitioned for capacity auction price-collar adjustments, while nuclear restarts and gas acquisitions carry multi-billion-dollar capex execution and outage risks.
FERC approving retroactive PJM capacity auction price caps below $175/MW-day or state legislation imposing windfall surcharges on merchant PPA contracts.
CEG and VST exhibit ±7.5%–8.2% implied moves around FERC docket rulings and quarterly guidance updates—nearly triple traditional regulated-utility volatility.
Updated immediately upon FERC final order issuance in Docket No. EL25-49 or PJM tariff revisions.
| Symbol | Status | Setup Structure | Spot | Trigger | Invalidation | Pre-Published Rule / Audit Note |
|---|---|---|---|---|---|---|
| MSFT | DEVELOPING | 200D SMA Mean-Reversion Watch | $521.91 | $534.44 | $499.99 | Wait for RTH reclaim >= $534.44 (above 50D SMA $512.91) confirming Azure CapEx digestion is complete. |
| VST | TRIGGERED | IPP Capacity Auction Momentum Trigger | $140.95 | $138.41 | $128.97 | TRIGGERED: Daily close cleared pre-published trigger with >$1.1B dollar volume; trailing invalidation floor remains active and unaltered. |
Initial regulatory note evaluated nuclear data-center PPA announcements across PJM generators.
PUBLIC CORRECTION (#59): An earlier summary paragraph inaccurately implied FERC Docket No. ER24-2172 imposed a blanket ban on all nuclear data-center PPAs rather than rejecting a specific behind-the-meter amended ISA over transmission cost-allocation standards. We corrected the legal scope, added exact docket citations (ER24-2172 & EL25-49), and extended our modeled behind-the-meter regulatory timeline by 9–12 months.
What Changed Our Mind: Shifted relative preference toward front-of-the-meter grid-tariff-compliant PPA structures (CEG Crane model & VST merchant dispatch fleet) pending FERC uniform co-location rules.