Autoresearch: FERC RM26-4-000 large-load interconnection — status and CEG implications, June 2026

Generated by /autoresearch on 2026-06-08. Synthesized across 3 rounds from 13 web pages, no Grokipedia anchor (no entry for this specific rulemaking). See Provenance. Treat as raw material — review before promoting into a project or thread. Context: vault/projects/stock-market

Summary

As of June 8, 2026, FERC has not yet issued a final rule in Docket RM26-4-000 (Large Load Interconnection). The Commission committed on April 16, 2026 to act "by end of June 2026" — but the form of action remains ambiguous and is likely a NOPR (Notice of Proposed Rulemaking) rather than a final rule, given the compressed timeline from the October 2025 ANOPR. The more direct operational unlock for Constellation Energy's co-location pipeline is the PJM framework submission, which management says is targeting June 2026 and is progressing "faster than expected." FERC upheld its 2024 Susquehanna/Amazon nuclear co-location block in March 2026, signaling behind-the-meter netting arrangements face real regulatory headwinds — but the PPA model (TMI/Microsoft) cleared a FERC waiver on June 1, 2026. CEG's nuclear co-location pipeline (~5 GW in PJM queue) remains paused-not-cancelled, with hyperscaler demand running ~75% above 2025 levels.

Findings

FERC RM26-4-000: Background and Current Status

Origin and scope: On October 23, 2025, the Secretary of Energy directed FERC to issue an Advance Notice of Proposed Rulemaking (ANOPR) on how large loads — generally defined as demand >20 MW — interconnect to the interstate transmission system. Docket RM26-4-000 opened in response. The rulemaking targets data centers, AI compute facilities, manufacturing, and other high-demand users seeking transmission interconnection (FERC docket page, 403 at fetch — confirmed via secondary sources).

April 16, 2026 Order of Intent: FERC announced it will "take action by the end of June 2026" in a manner that is "quick, efficient, and legally durable." The April order explicitly does not adopt new rules — it is a commitment notice, not rulemaking. FERC cited three primary concerns: reliability challenges from unprecedented large-load growth, cost allocation problems, and timing delays in interconnection processes (Holland & Knight, April 2026).

Key ambiguity — form of June action: The expected June action's regulatory form is unspecified in FERC's order. Legal analysts note the 8-month timeline from ANOPR (Oct 2025) to "action" (June 2026) is extremely compressed for a final rule; a NOPR (which would then open a comment period before a final rule) is more legally consistent with the "quick, efficient, and legally durable" framing. If FERC issues a NOPR rather than a final rule, co-location deal approvals remain gated on a further 12–18 month rulemaking cycle (HData analysis).

What FERC has already done pre-RM26-4-000 final action:

• December 18, 2025: Ordered PJM to create transparent co-location rules — four transmission service options for co-located loads (full NITS, interim non-firm, firm contract demand, non-firm contract demand) and behind-the-meter generation rule revisions. Established "Necessary Studies" process where generators reduce capacity interconnection rights and bear upgrade costs. Directed a new MW threshold for BTM netting (Akerman analysis).
• January 2026: Approved Southwest Power Pool's High Impact Large Load (HILL) protocols.
• March 2026: Upheld Susquehanna/Amazon nuclear co-location block (see below).
• June 1, 2026: Granted FERC waiver for TMI Unit 1 restart under PJM rules — specifically clearing the 837 MW Constellation/Microsoft deal (ANS Nuclear Newswire / Utility Dive).

The Susquehanna Precedent: What FERC Considers Unacceptable Nuclear BTM

The block: In November 2024, FERC voted 2–1 to reject a PJM proposal to expand Amazon Web Services' co-located load at Talen Energy's Susquehanna Nuclear Station from 300 MW to 480 MW. In March 2026, FERC upheld this decision on rehearing, denying Talen's request (Power Magazine; National Law Review).

Grounds for rejection:

1. Cost-shifting: AEP and Exelon argued the arrangement would shift ~$140M/year in transmission costs onto other PJM ratepayers. FERC agreed the proposal lacked adequate protections.
2. Non-standard provisions without justification: The amended ISA deviated from standard tariff without sufficient demonstration of necessity.
3. Market integrity: PJM's independent market monitor warned the arrangement created incentives for large loads to disconnect from the grid entirely, socializing costs broadly.

Dissenting view (Chairman Phillips, since departed): The rejection "threatened national security" and created "unnecessary roadblocks to an industry that is necessary for national security."

Implications for CEG: The Susquehanna block establishes that behind-the-meter co-location arrangements — where a data center netting its load against nuclear generation avoids most transmission charges — face a high bar at FERC. The December 2025 PJM order's 50 MW threshold for BTM netting is the direct operational response: arrangements above 50 MW face the "Necessary Studies" process and cannot net transmission charges freely.

Two Different Models: BTM vs. PPA — FERC Treats Them Differently

The regulatory divergence is critical for understanding CEG's contract pipeline:

Behind-the-Meter (BTM) / fully isolated co-location: Data center physically co-located at nuclear plant, draws power directly without using transmission grid, avoids most transmission charges. This is the model FERC blocked at Susquehanna. FERC scrutinizes this heavily for cost-shifting and reliability.

Power Purchase Agreement (PPA) / network interconnection: Nuclear plant sells all power into the grid under a long-term PPA; data center draws grid power and has contractual rights to CECs (clean energy certificates) from that plant. The plant remains fully grid-connected; no transmission cost bypass. This is the TMI/Microsoft model — and FERC granted a waiver on June 1, 2026.

Implications: Constellation's declared strategy leans toward the PPA model for large hyperscaler deals (Microsoft/TMI is the template). The CEG complaint about Exelon blocking "fully isolated co-located load" projects suggests CEG also wants BTM arrangements, but the PPA path is regulatory-cleared while BTM remains contested.

Constellation Energy: Pipeline, Pause, and Post-Calpine Position

Current financial state (Q1 2026): Revenue $11.1B (+64% YoY, Calpine consolidation); adj. EPS $2.74; full-year 2026 guidance $11–12/share affirmed. Nuclear fleet capacity factor 92.3% (TIKR Q1 2026 summary).

Calpine acquisition: Closed January 7, 2026 at $16.4B equity value. DOJ consent decree required divestiture of 5 gas plants (4.4 GW, primarily in PJM: Bethlehem, York 1, York 2, Hay Road, Edge Moor) to LS Power. Combined capacity: ~60 GW nuclear + gas + geothermal. Separately, CEG divesting ~$5B of additional gas assets (Utility Dive antitrust coverage).

Co-location pipeline and deal pause: Constellation agreed to pause new nuclear co-location deals pending regulatory clarity — conditions tied to DOJ consent decree and/or FERC PJM framework. Q1 2026 CEO comments: deals are "paused but not cancelled"; hyperscaler spending ~75% above 2025; 5,000 MW of new capacity resources submitted to PJM interconnection queue. Customers are "waiting for final rules before signing agreements." PJM framework targeting submission to FERC in June — described as "moving faster than management expected" (TIKR).

Confirmed deal (PPA model): Microsoft/TMI Unit 1 restart — 20-year PPA for 100% of 837 MW; FERC waiver granted June 1, 2026. This arrangement is cleared and proceeding.

Confirmed deal (natural gas, not nuclear): CyrusOne/Freestone Energy Center — 380 MW Phase 1 + 380 MW Phase 2 exclusive via Calpine natural gas assets in Texas (ERCOT jurisdiction, outside PJM rules).

Open nuclear co-location pipeline: 5 GW in PJM queue, deals unspecified. Analyst estimates put this at 3–5 hyperscaler-scale contracts. Resolution gated on PJM framework FERC filing.

Key Provisions of the Emerging Framework (Pre-Final Rule)

Based on FERC's December 2025 PJM order and related actions, the emerging framework that RM26-4-000 is expected to formalize includes:

1. Four transmission service tiers for co-located load (full NITS → interim non-firm → firm contract demand → non-firm contract demand) with progressively less reliability guarantee.
2. 50 MW BTM threshold: Below this, existing behind-the-meter netting arrangements likely tolerated; above this, "Necessary Studies" process required and generators must reduce capacity interconnection rights and bear all upgrade costs.
3. Cost causation: Load triggering transmission upgrades bears those costs — not socialized.
4. Flexibility requirements: Large co-located loads must demonstrate ability to curtail consumption to protect grid reliability.
5. Jurisdictional expansion: 20 MW floor for federal large-load interconnection authority — contested by states as encroachment on retail jurisdiction.

RM26-4-000 and the "Legally Durable" Framing

FERC's stated goal of a ruling that is "quick, efficient, and legally durable" is a direct response to the Susquehanna rejection's legal vulnerability — that case-by-case approvals without a clear tariff framework are hard to defend. The Commission wants a rule that survives judicial review. This suggests the June action will focus on establishing process (who can interconnect, how studies work, who pays) rather than blessing specific deal structures. The legal durability goal is more consistent with a NOPR than a final rule.

Contradictions and Open Questions

• NOPR vs. final rule: Multiple legal commentators expect a NOPR rather than a final rule in June, but FERC's language ("act in a manner that is quick, efficient, and legally durable") is ambiguous. If it's a NOPR, the CEG deal pipeline remains gated until a final rule ~12–18 months later.
• PJM framework vs. RM26-4-000: It is unclear whether CEG's deal pause condition is tied to RM26-4-000 specifically or to PJM's FERC-approved framework. If it's the latter, the PJM framework submission in June (separately from RM26-4-000) may be the direct trigger.
• BTM model viability: The Susquehanna block (upheld March 2026) suggests the "fully isolated" BTM model Constellation complained about in November 2024 remains blocked. If CEG's queued deals assume BTM arrangements, the December 2025 PJM framework (which limits BTM above 50 MW) may constrain the deal economics.
• Deal economics post-framework: The "Necessary Studies" process and cost-causation rules will require data center co-locators to fund transmission upgrades rather than free-riding on existing infrastructure — which may reduce the economics of nuclear co-location deals relative to a pure BTM arrangement.
• FERC's political composition: Commissioner Phillips (pro-co-location) has since departed. The current 2–1 majority that blocked Susquehanna reflects a more cautious posture on BTM netting.

Implications for the CEG Thesis (Stock-Market Project)

Thesis intact, but binary catalyst risk is real:

• The June 2026 FERC action (RM26-4-000 + PJM framework) is the catalyst that unlocks CEG's queued co-location deals
• If the June action is a NOPR (not a final rule), the deal pipeline unlock delays ~12–18 months — thesis intact but timeline elongates
• If PJM framework submission in June is the operative trigger (separate from RM26-4-000), CEG may begin closing deals even before a final rule on RM26-4-000
• TMI/Microsoft PPA (837 MW) is cleared and proceeding — floor revenue secured
• Calpine acquisition introduces 380+ MW natural gas co-location (CyrusOne/Freestone) outside PJM — diversifies the bet
• CEG financial guidance ($11-12 EPS) is not contingent on new nuclear co-location deals closing in 2026 — the thesis upside is from the pipeline, not the floor
• Key watch item: Whether the June FERC/PJM action is described as unlocking the deal pause or merely advancing the process — management language in the next earnings call (Q2 2026) will be the tell

Entry point context: CEG at $264.59 (per prior dispatch) vs. $270–285 entry window — the June catalyst is still pending (as of June 8), making the current discount a rational expression of binary timing risk.

Provenance

Rounds run: 3 of 3

Sub-questions by round:

Round 1 (broad survey):

1. What is FERC RM26-4-000 and what has happened with it since June 5, 2026?
2. What are the key provisions regarding data center co-location, BTM, and large-load interconnection?
3. How does RM26-4-000 affect Constellation Energy and nuclear baseload prospects?
4. What are industry stakeholder reactions (hyperscalers, utilities, nuclear operators)?

Round 2 (drill-down):

1. FERC's Susquehanna/Amazon nuclear co-location block — grounds and implications for CEG — targeted: reliability rationale constraining nuclear BTM
2. Constellation post-Calpine: specific FERC/nuclear co-location pipeline and contract risks — targeted: direct CEG thesis impact
3. Ratepayer protection framework and 50 MW threshold — targeted: whether June rule expands or constrains existing framework

Round 3 (resolve remaining uncertainty):

1. Exact conditions under which CEG can close new nuclear co-location deals — targeted: precise catalyst definition
2. Form of FERC's June action (NOPR vs. final rule) — targeted: whether June ruling is the trigger CEG is waiting for

Anchor source: No Grokipedia entry found for "FERC RM26-4-000 large load interconnection rulemaking" (general FERC page exists but does not cover this docket).

URLs fetched (13 successful, 3 failed):

Round 1:

• FERC RM26-4 docket page — official — fetch failed: HTTP 403
• FERC intent-to-act news — official — fetch failed: HTTP 403
• Holland & Knight: FERC to Act in June — law firm analysis — April 2026 timeline, expected provisions
• Troutman Energy Report: FERC June commitment — law firm analysis — timeline and background actions
• Utility Dive: FERC orders PJM co-location rules — trade press — December 2025 PJM order, 3 new transmission services
• K&L Gates: FERC PJM co-location tariff reform — law firm — specific provisions of December 2025 PJM order
• Power Magazine: FERC June deadline — trade press — Susquehanna block reference, BTM 50 MW threshold, ratepayer protection pledge

Round 2:

• Power Magazine: FERC blocks Susquehanna/Amazon — trade press — reliability/cost grounds for November 2024 block
• CSIS: What's at stake in FERC's large-load proposal — think tank — jurisdictional tension, cost allocation debates
• Akerman: FERC directs PJM co-location rules — law firm — four transmission service options, timeline
• Utility Dive: Constellation FERC complaint PJM — trade press — Nov 2024 CEG complaint, Exelon blocking co-location projects
• DCD: Constellation doubles down on AI datacenter strategy — fetch failed: HTTP 403

Round 3:

• TIKR: CEG Q1 2026 earnings — financial analysis — pipeline pause, PJM timeline, EPS guidance
• JDSupra: FERC June 2026 action — law firm — form of action ambiguity
• HData: 2026 FERC rulemaking analysis — analyst blog — key contested issues, threshold debates
• Utility Dive: antitrust/Calpine settlement — trade press — DOJ consent decree terms

Tools used: WebSearch, WebFetch. Generated: 2026-06-08