Large loads co-located with generation have moved from niche arrangements to a central market-design problem. Technology firms want speed and firm power. Generators want new offtake. Other retail customers want assurance they are not paying for private campuses. By autumn 2025 the outlines are clear even before any later nationwide show-cause climax: opaque, case-by-case deals will not scale, and RTOs need transparent tariff language for high-impact loads and electrically proximate generation.
Cost causation principles
If a campus requires network upgrades, the campus should face those costs unless a transparent shared-benefit finding says otherwise. If a co-located generator reduces network use, credits must be measured, not assumed. If reliability services are still drawn from the system during generator outages, the load must not escape capacity and ancillary obligations by creative metering.
Interconnection dual queues
Generator interconnection under Order No. 2023 and load interconnection processes must be studied together when electrically proximate. Treating them as strangers recreates surprise constraints. Rising national demand growth described by EIA in January 2025, with commercial sales rising on data-centre consumption and industrial loads from manufacturing, makes the cost of surprise higher. Order No. 2023-A's readiness and cure clarifications harden generator queues; load queues need comparable discipline.
Reliability
Co-location can improve local energy balance and reduce some transmission loadings. It can also create new contingencies if a large load and its host generator trip together or if islanding assumptions fail. Operators need visibility and enforceable operating procedures. Regions experimenting with high-impact load study processes, including approaches of the kind later cited in FERC discussions of SPP's initiative, are responding to that need.
State and federal roles
States oversee retail service and many siting questions. FERC oversees wholesale market rules and transmission. Large-load tariffs sit on that seam. Order No. 1920's emphasis on state engagement in transmission planning is a reminder that political legitimacy matters as much as power-flow models.
Transparent tariff language beats clever private contracts when the volumes at stake can move zonal prices and reserve margins. October 2025 is late enough in the data-centre cycle to demand that transparency before the next wave of campuses locks in assumptions the residual system cannot support.
The practical discipline is unchanged across fuel types and market constructs. Read the primary docket or statistical release before arguing about national destiny. Separate nameplate megawatts from accredited capacity, and contracted offtake from commissioned trains. Map interconnection and transmission lead times onto customer energisation promises rather than the other way round. Treat winter and summer extreme cases as design conditions. When federal policy shifts, update the slope of the forecast without rewriting physical laws. When state commissions push back on cost allocation, treat that push-back as part of the build path rather than as noise. United States energy infrastructure is financed, permitted and operated by people who must reconcile those constraints daily. Analysis that ignores them will not survive first contact with a peak day. Regional operators will continue to publish winter assessments, summer reliability outlooks and interconnection status reports. Those documents, read together with EIA inventories and FERC orders, give a clearer picture than any single speech. Investors should price execution risk honestly. Policymakers should resist the urge to treat one statute or one survey table as the whole system. The grid is a machine. Machines care about margins, not metaphors.