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⚡ THIS WEEK'S SIGNAL
Everyone is arguing about behind-the-meter co-location rules. Meanwhile, the two largest nuclear-to-hyperscaler contracts in the country — Talen/Amazon at Susquehanna and Constellation/Meta at Clinton — are both front-of-the-meter. One was deliberately restructured that way because the front-of-the-meter version did not require FERC approval. The industry is litigating the door while the money walks past it, and the term that actually allocates the risk has never appeared in a public filing.
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📰 MAIN STORY
The question underneath every nuclear offtake deal is simple: who pays if the data center never gets built? Contract lawyers call the answer a minimum take — the obligation to pay for a defined volume whether or not you consume it. It is the number that determines whether merchant nuclear is a financeable asset class or a very expensive bet on someone else's construction schedule. It is also, in both of the deals that set the benchmark, entirely confidential. We covered the announced-versus-operating gap in 90 Gigawatts Announced, 2 Gigawatts Running and the hyperscaler nuclear pipeline in 9.8 GW of Hyperscaler Nuclear — and How Much Actually Arrives This Decade. This is the contractual layer underneath both.
Talen is optimizing for contracted revenue and balance-sheet flexibility; its own investor materials say the Amazon amendment was designed to decrease market risk and reduce reliance on the federal nuclear production tax credit. Amazon is optimizing for optionality — the restructured agreement eliminated its ability to cap commitments at 480 MW, but replaced a fixed number with a delivery band tied to its own build pace. Constellation is optimizing for a post-subsidy revenue floor at a plant that was scheduled to close in 2017. Meta is buying clean energy attributes at scale to match 100% of its electricity use. Note what none of them is optimizing for: a published term sheet.
Here is the contrast. Clinton was saved by Illinois's Zero Emission Credit program, enacted under the Future Energy Jobs Act, which supports the plant with ratepayer funds through mid-2027. Illinois ratepayers financed that bridge for roughly a decade. Constellation's release describes the Meta agreement as a market-based solution that replaces the ZEC program and sustains the plant without ratepayer support. That is accurate, and it is also the whole story: the public paid the bridge toll from 2017 to 2027, and the next twenty years of the asset's output are contracted to one counterparty.
The numbers. Talen's expanded PPA with Amazon, announced June 11, 2025, reaches 1,920 MW at full contract quantity and runs through 2042 with extension options. Deliveries are scheduled at 840–1,200 MW by 2029 and 1,680–1,920 MW by 2032, with the range set by Amazon's development pace. Susquehanna is a two-unit, roughly 2,476 MW station; Talen owns 90%, Allegheny Electric Cooperative 10%. The Clinton PPA, announced June 3, 2025, covers 1,121 MW for 20 years beginning June 2027, plus 30 MW of uprate. And the federal floor under all of it — the Section 45U credit, worth up to $15/MWh with prevailing wage compliance, phasing out as gross receipts rise from $25/MWh to $43.75/MWh — applies only to tax years beginning before January 1, 2033. Talen's contract runs ten years past that. Clinton's runs fifteen.
Scenario A: If FERC's Section 206 show-cause dockets produce the pro forma cost recovery agreements the June 18 orders called for — instruments requiring large-load customers to bear the risks and costs of the network upgrades built for them — then a published, standardized load-side floor exists for the first time. Infrastructure credit investors gain a comparable to underwrite against, and utility planners get a security instrument they can point to when a developer asks for a study slot.
Scenario B: If the regions answer on reliability and defer cost allocation — MISO's August 28 filing covered ramp rates, ride-through, and monitoring, with its full show-cause response not due until November 16 — then cost allocation slips into 2027, and the next three to five nuclear deals get negotiated against a benchmark nobody outside the room has read. Ratepayer advocates lose their best forum, and generators keep pricing the floor privately.
Watch September 16: the 30-day window for interested parties to respond to the August show-cause filings.
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🧾 DEAL DECODER
The instrument: a delivery band, not a take-or-pay volume.
Who signs what. Talen Energy and Amazon, under a long-term PPA in which Talen acts as retail electric generation supplier and PPL Electric Utilities handles transmission and delivery. Name what it is not: not a co-location agreement, not behind-the-meter, not a tolling arrangement, and — per Talen's own investor materials — not something requiring FERC approval. The prior behind-the-meter structure is what FERC rejected in November 2024. This replaced it.
Who fronts capital, who gets it back. Amazon acquired the adjacent data center campus outright; Talen monetizes a second unit's output over seventeen years to 2042.
Who eats the loss if the load never shows. Read the band. Deliveries of 840–1,200 MW by 2029 leave a 360 MW spread, explicitly set by Amazon's development pace. A band is not a floor. It is closer to a hotel block booking than a lease — a room count committed within a range, with the final number set by how fast the guests actually arrive.
Precedent. The next developer asks for a band too. Generators will resist; that resistance is the negotiation nobody gets to watch.
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⚡ QUICK HITS
MISO Filed the Engineering Bar Before the Cost Bar. On August 28 MISO asked FERC to approve reliability requirements for loads above 50 MW, with a separate "computational load" class for facilities drawing at least 25 MW through IT equipment, requesting a December 4 effective date. Cost-shift protections and co-located generation treatment were held back for later filings — which means the technical gate closes before the cost gate does, and Meta's Louisiana campus is inside the first one. Utility Dive
Delaware Put Large Loads in Their Own Rate Case. Governor Matt Meyer signed a package of bills including HB 233, which creates a separate utility rate case for large energy-use facilities so they carry the full cost of their own upgrades. For ratepayer advocates in PJM states, this is the cleanest statutory version yet of cost-causation — no rider mechanism, no allocation formula, a separate proceeding. Stoel Rives
DOE's $1.9B SPARK Selections Are Still Not Public. DOE's Office of Electricity indicated selection notifications in August 2026, with awards anticipated October 2026 through January 2027; no selection list has appeared on the program page. Western applicants planning reconductoring work around the award date are now carrying schedule risk on a date that has already moved once. energy.gov
The CPUC Opened the Proceeding That Will Price Data Centers. R.26-04-009 was issued April 10 to modernize residential and non-residential rate design so rates better reflect cost of service. For anyone with a California interconnection request in flight, the tariff you will actually be served under is being written in this docket, not in your study. CPUC
The Nuclear Credit's 2032 Cliff Is Now Inside Every Contract Term. Section 45U applies to tax years beginning before January 1, 2033, while the Talen and Constellation offtake agreements run to 2042 and roughly 2047. Every merchant nuclear model being underwritten today has a decade or more of unsubsidized tail that no current statute covers. Congressional Research Service
🧭 THE EXPOSURE MAP
If you hold equities. The structure described here strengthens contracted merchant generation relative to uncontracted merchant generation, and it concentrates that advantage in operators who signed before the regulatory framework existed. The exposure that is least discussed is the post-2032 tail: contracts extending past 45U's statutory window carry pricing assumptions no current law supports. The reporting events that would confirm or contradict this: Q3 and Q4 earnings calls where management is asked to characterize contracted volume ranges versus firm floors, and any capex guidance revision tied to uprate programs. Nothing here is a recommendation about any security.
If you run projects at a utility. Your five-year load forecast probably counts contracted hyperscaler volume as firm. In at least one benchmark deal it is a band with a several-hundred-megawatt spread set by the customer's build pace. The question your organization should be able to answer and probably cannot: how much of the large load in your plan is firm obligation versus contractual range, and what is your obligation if the top of the range arrives early?
If you set or influence policy. The precedent in play is whether a pro forma cost recovery agreement becomes standard across all six RTO regions or fragments into six versions. The next venue is the September 16 response window, then the November filings from regions that took the suspension.
If you pay a utility bill or buy AI compute. Nothing here changes your bill this quarter. The mechanism that will is the large-load tariff — PG&E's proposed Rule 30 in California, HB 233's separate rate case in Delaware — and those take quarters to litigate and longer to show up in a rate. Watch the tariff, not the deal announcement.
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🔧 TOOL / RESOURCE OF THE WEEK
CAISO Large Loads resource page: CAISO's own explanation of which entity studies what when a large load seeks service in California, including where ISO jurisdiction ends and utility tariff jurisdiction begins. If you are a project or program manager trying to work out who actually owns your interconnection question, this is the clearest free statement of the division of roles I have found. → https://www.caiso.com/generation-transmission/load/large-loads
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💬 CLOSING THOUGHT
The thing I keep turning over is that both benchmark deals went front-of-the-meter, and one of them did so specifically because that version did not need permission. We spent two years building a regulatory apparatus for behind-the-meter co-location, and the largest transactions routed around it. That is not a failure of the rules. It is a reminder that contract structure moves faster than tariff structure, and always will.
So the open question. Will the September filings push any of these contract terms into daylight? Or does the floor stay private while the public dockets argue about wires? I think that is the part none of us can see yet.
