Interruptible Inference
What happens when new US AI campuses without on-site generation turn on in 2027 on a politically audited, interruptible megawatt allocation, while firm MW remains a priced contract and a turbine? The model that trains at 3 a.m. is often not the model that serves at 6 p.m. Queue position plus interruptibility plus a named shed topology become the binding constraint on training compute. Hollis Brenner walks a warm Texas aisle at 03:00 after a QSE congestion instruction hits the campus EMS and sheds armed training MW; the horn, the red badge, the tagged breaker, and a quiet canteen are the operations layer of that shed. Patrice Voss opens a Harrisburg PPL default-service bill where the generation charge moved with the PJM capacity print, not the heat. Wendell Ortiz carries a ride-through log through a Northern Virginia hall that still dumps to UPS because a Texas vote and a NERC Phase-1 filing did not bind PJM racks. Residential ratepayers discover they have been financing forecast load that does not yet exist. Daily life is allocation letters, curtailment contracts, night-shift windows, and audit clipboards. Not sentient models. Not a blackout opera. A market that learned to sell non-firm MW as if it were a product.
The constraint is power-systems physics and queue externalities, not model scaling. A bulk-power system is balanced in real time: generation must equal load plus losses at 60 Hz. When a large generator trips, frequency falls. When a large load trips (the data-center failure mode) frequency and voltage rise. PJM's 2026-07-22 Northern Virginia event is the textbook: a correctly-cleared 230 kV fault, two waves of customer-side transfer to backup (2,970 MW then 1,099 MW), system load 99,984 to 96,205 MW, ACE recovered in nine minutes. ERCOT has logged 28 events since January 2023 of computational-load trips of 100 MW or more. Ride-through requirements (hold through a specified voltage/frequency envelope instead of dumping to UPS) are the same class of remedy already imposed on inverter-based generation after similar early-trip behavior. Interconnection queues are a negative-externality machine: each new large load changes power-flow and stability cases for every other request, which is why ERCOT abandoned serial large-load studies for a system-wide batch. Cluster allocation computes a feasible MW vector subject to N-1 contingency limits, voltage stability, and thermal ratings; it is not a waiting list. Resource adequacy is a separate stack. PJM's 2027/28 Base Residual Auction cleared at the FERC-approved cap of $333.44/MW-day and still missed the reliability requirement by 6,516.6 MW. None of this requires a view on AGI. It requires Kirchhoff's laws, contingency analysis, and the empirical fact that hundreds of gigawatts of requests cannot interconnect to a ~91 GW peak system on a 12-18 month clock. The world does not depend on new 500 kV lines landing in time. It depends on tariffs, audits, curtailment, and on-site generation, which can clear in 3-18 months. Ride-through for inverter-based generation means stay connected through a voltage/frequency envelope. Ride-through for a GPU hall is a different machine. Campuses transfer to UPS because the IT load cannot drink a sag; the grid then sees a load rejection (PJM 2026-07-22). This world names the topology: a campus EMS sheds training first and keeps inference. Horn-and-badge is the operations layer of that shed, not the physics that stops a 100 MW trip. POI hold with a STATCOM or synchronous condenser, and rack-level hold with a different UPS, exist as the firm-campus minority who brought generation. If ride-through is enforced only at the POI and racks still dump, the two-wave pattern repeats. A PUCT/ERCOT ride-through vote does not automatically bind PJM campuses.
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