Existing nuclear fleets are operating reactors, plant licenses, fuel plans, outage crews, grid interconnections, capacity-market positions, hedge books, and customer contracts that already produce clean-firm megawatt-hours. This page ranks companies that can sell those megawatt-hours, or adjacent dispatchable power, into power markets, capacity auctions, retail books, hedges, and long-duration large-load contracts. The current basket read is that CEG has the broadest direct nuclear and customer-contracting surface; VST is the strongest relative-value challenger with signed Meta nuclear agreements; TLN has the highest Susquehanna/AWS torque with more single-asset and rule risk; NRG remains an adjacent retail, gas, VPP, and data-center power comparator after selling its South Texas Project nuclear stake in 2023.
What the stack is: operating nuclear plants plus the commercial and market machinery around them: reactors, turbine halls, switchyards, fuel contracts, outage schedules, Nuclear Regulatory Commission licenses, interconnection rights, capacity obligations, retail load, hedges, and bilateral power contracts.
What it does: the stack turns uranium fuel and plant availability into around-the-clock electricity, then sells that output as energy, capacity, clean attributes, customer supply, hedged generation, or credit-backed clean-firm power for large loads.
Where it sits: physically at nuclear generating stations and grid interconnection points; operationally inside PJM, ERCOT, retail power books, bilateral PPA desks, capacity auctions, and corporate clean-power procurement processes.
How the theme uses it: data centers and reliability-sensitive customers need firm power before new nuclear can be built, so existing fleets can become more valuable if scarce output is contracted at terms that lift realized margin and cash flow after fuel, outages, capex, collateral, debt, and acquisition costs.
Terms used later: clean-firm power means low-carbon electricity available when needed; capacity payment means market compensation for being available in reliability periods; PPA means power purchase agreement; uprate means approved plant work that raises output; FCFbG means free cash flow before growth spending; recovery here means merchant cash conversion, not regulated rate-base recovery.
Report boundary: this node is a tactical report layer. Durable company research stays in the linked knowledge pages. Contract claims are separated from undisclosed economics, and price context comes from read-only discovery daily_ohlc through 2026-06-12.
Current Setup
Operating clean-firm supplyExisting reactors matter only when scarce output becomes priced, delivered cash.
Positive proofCEG has the broadest fleet and customer route.
VST and TLN have named Meta and AWS nuclear routes; NRG adds dispatchable-power comparison rather than direct nuclear ownership.
Conversion gateSigned economics must beat fuel, outage, collateral, and debt costs.
Watch price, term, escalation, credit support, curtailment, replacement-power language, and FCF after capex.
Primary constraintRules and disclosure still leave margin unclear.
FERC, PJM, ERCOT, interconnection, co-location, outage, and acquisition-funding decisions can dilute the setup.
AssetOperating reactors
BuyerGrid, retail, hyperscale
Collection routeEnergy, capacity, PPAs
Proof pointFCF, leverage, terms
Existing nuclear fleets matter because they produce clean-firm electricity today, years before most new nuclear projects can be licensed, financed, built, and fueled. Value appears only when those megawatt-hours convert into realized power margins, capacity revenue, credit-backed PPAs, hedge settlements, nuclear production tax-credit support, or retail load matching. The useful proof is specific: MW or MWh, price or margin signal, term, escalation, customer credit, deliverability, curtailment or replacement-power language, capacity-factor performance, and free cash flow after capex, fuel, collateral, debt service, and acquisitions.
Demand evidence is strong enough to keep operating nuclear in the center of the theme. DOE data-center work points to U.S. data-center load rising from about 4.4% of electricity use in 2023 to roughly 6.7%-12% by 2028, and IEA expects data-center electricity demand to more than double by 2030. CEG has the Microsoft/Crane restart agreement, Meta's Clinton agreement, Calpine-added dispatchable scale, and a 147M MWh nuclear contracting opportunity in the local lane. VST has 20-year Meta agreements covering more than 2,600 MW of PJM nuclear energy and uprates. TLN has Susquehanna and an AWS PPA path to 1,920 MW through 2042. NRG adds large-load exposure through retail, gas generation, CPower VPP capacity, data-center agreements, and Texas Energy Fund projects. The next positive evidence is signed economics, delivered MWh, capacity-market settlements, high plant availability, and guidance that converts adjusted EBITDA into cash and per-share value.
The biggest constraint is that many contract announcements disclose counterparty, term, or MW but leave price, escalation, credit support, curtailment rights, replacement-power obligations, and margin impact unclear. The setup also depends on FERC, PJM, ERCOT, interconnection, co-location, and cost-allocation rules; plant outages and refueling schedules; NRC restart, relicensing, and uprate approvals; hedge books and collateral; and debt from Calpine, Cogentrix, Cornerstone, or LS Power. CEG must prove Calpine integration and free cash flow before growth, VST must show Meta economics and summer reliability, TLN must deliver AWS transition mechanics and debt reduction, and NRG must prove LS Power integration and FCFbG recovery while remaining an adjacent comparator. Watch filings, regulatory orders, earnings guidance, and weekly trend repair together.
Static setup labels and thresholds use weekly bars aggregated from discovery daily_ohlc through 2026-06-12. Selected-security charts call the report API with as_of=latest; refresh thresholds after the next market-data update before using them as current trading evidence.
Basket
This basket is inherited from the parent nuclear-power value-chain map and ranked by direct existing-fleet exposure, named contract evidence, risk-adjusted cash conversion, and source-backed operating fit. Chart timing only breaks ties after the business evidence is scored. PEG remains the related regulated tail because it has nuclear/PJM optionality inside PSE&G recovery, but it belongs in the regulated recovery node until direct above-market contract economics become the main equity mechanism.
Largest direct fleet and contracting surface, with nuclear output, Calpine scale, customer access, and powered-land routes.
Market cap$91.9B
Next earningsAug 6, 2026 est.
Latest qtr revenue$11.122B
Role in stack
CEG owns and markets nuclear and dispatchable generation into power markets, capacity markets, competitive retail load, and large-load contracts. Demand becomes economics if nuclear MWh, Calpine gas/geothermal assets, customer supply, and powered-land agreements lift realized cash after outages, fuel, collateral, integration, and debt.
Revenue mix
Post-Calpine CEG is a competitive generation and retail platform. Q1 2026 segment evidence includes Mid-Atlantic, Midwest, New York, ERCOT, other power regions, and a new Calpine segment; the lane frames 55 GW of capacity, about 2.5M customer accounts, and 147M MWh of nuclear contracting opportunity.
Latest qtr revenue
Q1 2026 revenue was $11.122B from the CEG security lane, routed to the SEC Q1 2026 10-Q and Q1 release. The same period showed $2.74 adjusted operating EPS, 44,666 GWh nuclear output including Salem/STP, and 92.3% nuclear capacity factor excluding Salem/STP.
Relative-value challenger with retail-generation scale, hedge coverage, and signed Meta nuclear agreements in PJM.
Market cap$49.9B
Next earningsAug 6, 2026 est.
Latest qtr revenue$5.640B
Role in stack
VST owns retail load and generation across ERCOT, PJM, ISO-NE, NYISO, MISO, and CAISO, including nuclear exposure from Energy Harbor. The conversion gate is whether Meta PPAs, PJM capacity, hedges, Cogentrix, summer reliability, and collateral discipline turn scarce firm power into durable FCFbG per share.
Revenue mix
Integrated competitive retail and generation platform with Retail, Texas, East, West, and Asset Closure adjusted EBITDA disclosure. Q1 profit contribution was led by East and Texas, while retail load and hedges support customer matching and cash visibility.
Latest qtr revenue
Q1 2026 operating revenues were $5.640B from the VST security lane, routed to the SEC Q1 2026 10-Q and Q1 release. The same period showed $1.494B ongoing adjusted EBITDA, $1.199B operating cash flow, and 98% expected 2026 generation hedged as of May 1, 2026.
Highest single-asset Susquehanna/AWS torque, with more concentration, financing, and rule-design risk.
Market cap$16.4B
Next earningsAug 6, 2026 est.
Latest qtr revenue$1.129B
Role in stack
TLN owns the PJM-centered Susquehanna nuclear route and has an AWS PPA path to carbon-free delivery through 2042. Theme pressure becomes equity value only if front-of-the-meter transition mechanics, PJM/FERC treatment, Susquehanna reliability, Cornerstone, debt, and adjusted FCF convert the contract into durable per-share cash.
Revenue mix
Mostly PJM generation and capacity exposure, with Susquehanna as the key nuclear asset. The lane records PJM at about 96% of 2025 disclosed segment revenue, Susquehanna at 2.2 GW, about 17 TWh of 2025 output, and roughly $27/MWh all-in nuclear cost.
Latest qtr revenue
Q1 2026 operating revenue was $1.129B from the TLN security lane, routed to the SEC Q1 2026 10-Q and Q1 earnings release. The same period showed $473M adjusted EBITDA, $350M adjusted FCF, 15.6 TWh generation, and 55.1% capacity factor.
Adjacent dispatchable-power comparator with retail load, gas generation, VPP capacity, and data-center exposure.
Market cap$26.5B
Next earningsAug 5, 2026 est.
Latest qtr revenue$10.256B
Role in stack
NRG no longer owns a current nuclear fleet stake after selling South Texas Project in 2023. It stays in this basket as an adjacent power-scarcity comparator because retail load, gas generation, CPower VPP capacity, TEF projects, and data-center agreements can show how dispatchable capacity monetizes reliability demand.
Revenue mix
Retail, gas generation, VPP, smart-home, and power-market exposure. Q1 2026 segment revenue was led by East at $6.432B and Texas at $2.393B, with West/Services/Other, Vivint, and Corporate/Other completing the consolidated mix.
Latest qtr revenue
Q1 2026 revenue was $10.256B from the NRG security lane, routed to the SEC Q1 2026 10-Q and Q1 release. The same period showed $1.080B adjusted EBITDA, negative $169M operating cash flow, negative $66M FCFbG, and $23.181B long-term debt including current portion.
Market caps use read-only local discovery values: latest 2026-06-12 close multiplied by weighted shares outstanding. Next-earnings dates use Nasdaq/Zacks algorithmic estimates checked on 2026-06-13, so each card labels the date est.. Latest-quarter revenue is Q1 2026 total operating or consolidated revenue from the linked security lanes and their SEC Q1 2026 source routes.
What Confirms Or Weakens
AreaWhat confirmsWhat weakens or invalidatesWatch next
01Node thesis
Scarce output becomes cash
What confirms
Operating nuclear MWh, capacity payments, retail supply, hedges, and large-load contracts show a clear bridge to realized margin, FCFbG, debt reduction, or per-share returns.
What weakens or invalidates
Announcements increase activity but do not improve cash after fuel, outages, collateral, capex, acquisition funding, replacement power, and debt service.
Watch next
CEG FCF before growth
VST FCFbG
TLN adjusted FCF
NRG cash recovery
02Contract economics
Terms show cash value
What confirms
Binding PPAs or customer agreements disclose MW or MWh, term, start date, price or margin signal, escalation, credit support, curtailment, replacement-power treatment, and EPS or FCF contribution.
What weakens or invalidates
Contract announcements remain qualitative, preserve old output without above-market margin disclosure, or shift too much delivery, curtailment, collateral, or replacement-power risk to the generator.
Watch next
CEG Microsoft and Meta terms
VST Meta economics
TLN AWS amendments
NRG large-load terms
03Customer and deliverability
Power reaches load
What confirms
Customer credit, interconnection approvals, front-of-the-meter delivery, transmission upgrades, and energized load make the power physically and contractually deliverable.
What weakens or invalidates
Co-location limits, queue delays, cost allocation fights, rehearings, appeals, customer delays, or self-supply plans reduce delivered MWh or economics.
Watch next
TLN-AWS transition path
CEG Crane delivery
VST PJM uprates
ERCOT data-center load
04Policy and market rules
Capacity value holds
What confirms
FERC, PJM, ERCOT, NRC, and state decisions preserve firm-resource accreditation, capacity value, co-location paths, license life, restart approvals, uprates, and cost allocation clarity.
Nuclear capacity factors stay in the low-to-mid 90% range where expected, refueling stays on schedule, fuel availability is adequate, and outage costs remain contained.
What weakens or invalidates
Forced outages, NRC events, refueling overruns, uprate cost inflation, fuel constraints, heat-rate or gas-cost stress, or replacement-power losses reduce available cash.
Watch next
NRC reactor status
CEG capacity factor
VST summer reliability
Susquehanna availability
06Funding and cash conversion
Adjusted metrics become cash
What confirms
Adjusted EBITDA bridges to operating cash, FCFbG, adjusted FCF, debt reduction, or buybacks after capex, nuclear fuel, collateral, acquisitions, interest, and taxes.
What weakens or invalidates
GAAP-to-adjusted gaps widen, collateral rises, M&A integration consumes cash, equity or stock consideration dilutes returns, or leverage and credit costs stay elevated.
Watch next
CEG Calpine bridge
VST Cogentrix funding
TLN Cornerstone debt
NRG LS Power leverage
07Stale condition
Refresh trigger
What confirms
Knowledge lanes, filings, earnings releases, web-sourced earnings calendars, revenue references, and local daily_ohlc remain synchronized after material updates.
What weakens or invalidates
A new trading session, earnings release, PPA disclosure, PJM/FERC order, NRC update, rating action, or acquisition update arrives before this page is refreshed.
Power Scarcity And Grid Load for the demand-to-cash conversion frame, merchant power evidence, and capacity-market evidence needed to underwrite the node.
AI Capex Cycle for the data-center demand origin; it does not prove contract margin by itself.
CEG security lane for nuclear output, Calpine, 147M MWh contracting opportunity, Microsoft/Crane, CyrusOne/Freestone, guidance, debt, FCF, and valuation evidence.
VST security lane for Energy Harbor nuclear exposure, Meta nuclear agreements, hedge coverage, Cogentrix, retail-generation integration, liquidity, and FCFbG.
TLN security lane for Susquehanna, AWS PPA, PJM concentration, Cornerstone, debt, adjusted FCF, and stale-source caveats.
NRG security lane for retail load, LS Power, CPower VPP, data-center agreements, TEF projects, debt, FCFbG, and the historical South Texas Project sale context.
PEG security lane is a related tail route because PSEG has nuclear/PJM optionality inside a regulated utility wrapper. It stays out of the ranked basket until direct above-market contract economics become the main value driver.
Constellation Crane/Microsoft release for the 20-year PPA, TMI Unit 1 restart, approximately 835 MW of carbon-free power, and 2028 target subject to approvals.
NRG/LS Power release for the 13 GW gas generation acquisition, CPower VPP platform, and large-load demand positioning.
Earnings Dates, Market Caps, And Revenue Sources
Next-earnings estimates were checked on 2026-06-13 through Nasdaq API endpoints /api/analyst/CEG/earnings-date, /api/analyst/VST/earnings-date, /api/analyst/TLN/earnings-date, and /api/analyst/NRG/earnings-date. Nasdaq states these dates are algorithmic estimates based on historical reporting dates and its Zacks Investment Research vendor, so the Basket labels them as estimates.
Estimated next earnings: CEG Aug. 6, 2026; VST Aug. 6, 2026; TLN Aug. 6, 2026; NRG Aug. 5, 2026. No company-confirmed Q2 2026 earnings dates were found in this bounded pass.
Market caps use read-only local discovery data queried on 2026-06-13: latest 2026-06-12 close multiplied by instruments.weighted_shares_outstanding. Results: CEG $91.9B, VST $49.9B, TLN $16.4B, and NRG $26.5B.
Latest-quarter revenue references come from linked security lanes and their SEC Q1 2026 source routes: CEG Q1 2026 revenue $11.122B; VST Q1 2026 operating revenues $5.640B; TLN Q1 2026 operating revenue $1.129B; NRG Q1 2026 revenue $10.256B.
Discovery And Chart Provenance
Read-only discovery checks used discovery status, discovery lineage-status --dataset daily_ohlc, and a DuckDB read-only market-cap query against ../discovery/data/discovery.duckdb. No discovery ingestion or backfill was run.
Chart setup metadata uses read-only daily_ohlc for CEG, VST, TLN, and NRG through 2026-06-12.
Weekly OHLC is derived from daily rows by calendar week: first open, maximum high, minimum low, final close, and summed volume. Setup levels use 20-week EMA, 100-week EMA, recent range highs and lows, and weekly volume context.
Right-rail chart artifacts use a three-year visible horizon, 20-week EMA, 100-week EMA where enough history exists, weekly volume bars, and a 20-week average-volume line. Chart order follows the Basket ranking: CEG, VST, TLN, NRG.
TLN local daily coverage starts on 2024-07-10 and has 101 weekly bars through 2026-06-12, so its 100W EMA is just over the minimum history threshold. CEG, VST, and NRG have longer weekly histories.
The selected-security right rail uses /api/securities/{ticker}/chart?frequency=weekly&window=3y&as_of=latest. Static HTML renders without the API; live charts require the local report API.
discovery status showed daily bars through 2026-06-12 for all four tickers. Per-ticker lineage returned May 2026 adjusted daily backfills, while grouped daily market updates extend local rows through 2026-06-12.