FERC RM26-4-000 Section 403 ruling → large-load interconnection streamlined → AI DC power bottleneck cleared → PWR/GEV/VRT accelerated order intake

The FERC invoked Section 403 of the Federal Power Act on October 23, 2025 to require NERC/RTOs to standardize large-load interconnection procedures. FERC Chair Swett committed April 16, 2026 to issue a final ruling by end of June 2026. The ruling is expected to create a 60-day fast path for curtailable loads, standardized deposit/withdrawal frameworks, and 100% developer cost responsibility — clearing the grid-access bottleneck that has delayed $725B in hyperscaler AI DC capex. PWR (grid construction), GEV (grid equipment), and VRT (power conversion) are the primary picks-and-shovels beneficiaries.

• Step 1: FERC delays or narrows the ruling scope post-June 30, 2026 — binary catalyst doesn't arrive
• Step 3: PWR, GEV, VRT report order intake not accelerating despite FERC ruling — indicates construction bottleneck is not regulatory but physical (equipment/labor)
• Step 4: NARUC wins preliminary injunction before the FERC rule takes effect — ruling is stayed; grid interconnection queue reopens

• **⚠ RESOLUTION OF THE JUNE BINARY (2026-07-13): FERC's action was SHOW CAUSE ORDERS to the RTOs — neither a final rule nor a NOPR.** robin-millican (Columbia CGEP, ep. recorded ~June 30) in 2026-06-30-podcast-columbia-energy-exchange-doug-arent-and-robin-millican-on-what-s-really: "FERC issued a series of show cause orders to the regional grid operators, the RTO ISOs, to essentially ask them to justify why their existing tariff structure is quote, unquote, just and reasonable and if they find that it isn't to... propose changes. So instead of doing... a rulemaking which would have gotten into some thorny challenges around sort of pursuing a one size fits all approach, getting into sort of state jurisdiction around retail tariffs in particular, instead they chose a very practical path." Implications for this chain: (a) the Step 2 expectation of a single standardized national framework (60-day fast path etc.) did **not** arrive in that form — reforms will be per-RTO tariff proposals, so the order-intake catalyst is staggered, not binary; (b) the Step 4 NARUC/state-jurisdiction risk is *reduced* — Millican reads the tailored path as deliberately avoiding intrusion "on areas that the states feel very strongly about," and calls it "a very smart move and... very promising" toward "predictable processes for connecting those very large loads, while ensuring infrastructure costs are allocated fairly." (c) She flags **interregional transmission cost-causation** as the thorniest open front (possible rebate structures if directly-assigned assets later benefit broader customers) — a watch item for how much network-upgrade cost lands on developers vs. ratepayers.
• **NOPR risk: June action likely a Notice of Proposed Rulemaking, not a final rule — 12-18 month delay.** From 2026-06-08-autoresearch-ferc-rm26-4-ceg-nuclear-colocation-june-2026: multiple legal commentators expect a NOPR rather than a final rule from the FERC RM26-4-000 proceeding in June 2026. A NOPR initiates a public comment period and requires another round of commission deliberation before a final rule — pushing the standardized large-load framework to mid-2027 at earliest. This means the end-of-June "binary catalyst" narrative (PWR/GEV/VRT order-intake acceleration) may be premature by 12-18 months. Step 1 cites Swett's April 16 commitment to a "final ruling" but that phrasing may have been interpreted too literally.
• **BTM nuclear co-location model blocked; PPA model cleared separately.** From 2026-06-08-autoresearch-ferc-rm26-4-ceg-nuclear-colocation-june-2026: FERC upheld the PJM decision blocking the Susquehanna/Amazon behind-the-meter (BTM) co-location arrangement in March 2026 — grounds: cost-shifting ~$140M/yr to other ratepayers and non-standard provisions. The power-purchase agreement (PPA) model (TMI/Microsoft) was separately cleared June 1, 2026 via CIR waiver. RM26-4 governs grid-interconnection (this chain's domain); the BTM block is a separate proceeding. Two distinct regulatory paths; the cheaper/faster BTM path remains blocked regardless of RM26-4 outcome.
• Supply-chain constraints (transformer lead times, copper, steel) are FERC-independent — a favorable ruling unlocks demand but doesn't accelerate equipment supply.
• NARUC challenge could take 2+ years in courts — FERC ruling may be stayed pending appeal.
• Hyperscalers may increase behind-the-meter (co-located) power deployment if grid interconnection remains slow — reducing FERC's relevance as a bottleneck gate. alice-yake (ex-Xcel chief planning officer) in 2026-07-07-podcast-columbia-energy-exchange-alice-yake-on-planning-for-a-reliable-cleaner-grid reframes that BTM path constructively — behind-the-meter DC generation can be "a great asset to the grid if there's a way to access it in times of need," i.e. a curtailable/dispatchable resource the operator calls on in emergencies "if there's collaboration and cooperation with the data center to turn down their load... or to fire up that generation." So the "bring-your-own-power" trend that erodes FERC's gate can, under the right tariff, become a grid asset rather than a pure bypass — which is exactly the cost-allocation / large-load-tariff design question this proceeding is trying to settle.

• Binary catalyst: end-of-June 2026 FERC ruling is a datable event. A favorable outcome is a near-term catalyst for PWR, GEV, VRT, FIX, ETN.
• PWR is the most directly gated: grid interconnection construction is the first physical step after a regulatory approval. Stifel PT raised to $784 from $654 (May 1).
• GEV is the longer-duration play: transformer backlog already $163B; FERC ruling adds incremental tailwind but doesn't change the 5-year equipment lead time math.
• NARUC challenge is the key bear risk: if courts stay the FERC rule pending litigation, the grid bottleneck persists and DC capex deployment is further delayed.