This page ranks regulated utilities that own nuclear plants or host large power loads where nuclear license extensions, uprates, reliability work, grid upgrades, or new generation can enter regulated earnings. Recovery means the utility spends capital, a regulator decides what enters rates and what return is allowed, and customers pay through base rates, riders, special tariffs, fuel clauses, capacity payments, or large-load customer contributions. The tournament-ranked basket is PEG, SO, ETR, DUK, and D: PEG ranks first on relative value and nuclear/PJM optionality; SO has the clearest regulated nuclear mechanism; ETR has the best current host-load evidence; DUK has scale but thinner current nuclear-load proof; D is a real Virginia nuclear host whose stock is now shaped by the pending NextEra transaction.
What the stack is: regulated nuclear recovery is the utility collection layer around nuclear plants, host service territories, substations, transmission corridors, large-load interconnections, billing systems, and commission-approved cost recovery.
What it does: it turns nuclear availability, license extensions, uprates, plant reliability work, generation additions, transmission upgrades, and customer-specific infrastructure into revenue only when regulators or contracted customers approve payment.
Main operating pieces: nuclear units, refueling and outage programs, transmission lines, substations, distribution feeders, interconnection equipment, meters, customer contracts, fuel clauses, riders, rate cases, special tariffs, and utility treasury funding.
Where it sits: the assets sit inside the utility service territory, at nuclear sites, at substations and large-load interconnection points, in PJM or state capacity/reliability mechanisms, and in the rate base after commission approval.
How the theme uses it: AI data centers, industrial customers, and reliability planners need firm power; host utilities build or keep nuclear and grid assets available, then seek collection through customer bills, customer contributions, capacity revenue, or approved financing structures.
Terms used later: rate base is approved utility investment that can earn an allowed return; recovery is the authorized collection route; tariff is the approved customer rate schedule; rider or tracker updates bills outside a full rate case; FFO/debt tests whether cash flow supports the debt used to fund the buildout; PJM is the Mid-Atlantic power market where capacity and transmission rules affect PEG and other exposed utilities.
Report boundary: this node is a tactical report layer. It ranks the current value-chain basket, setup labels, confirmation triggers, invalidation levels, and chart provenance. Durable company research stays in the linked knowledge pages. Price and volume context comes from read-only discovery daily_ohlc through 2026-06-12.
Current Setup
Regulated nuclear recovery gateNuclear value counts when output, grid spend, and host-load capex become approved collection.
Utilities can own valuable nuclear plants and high-growth service territories, but shareholders need rate orders, capacity revenue, customer-backed infrastructure, financing access, and EPS after debt or equity funding.
Positive proofPEG, SO, and ETR carry the clearest current evidence.
PEG has relative value plus nuclear/PJM optionality; SO has the cleanest regulated nuclear route; ETR has the strongest Gulf South host-load evidence.
Conversion gateRate orders, tariffs, capacity rules, and funding decide per-share conversion.
Watch BPU, FERC, PJM, state commissions, customer contributions, FFO/debt, and EPS guidance after financing.
Primary constraintBill pressure, nuclear outages, and financing can absorb the load benefit.
Cost disallowance, forward equity, debt coupons, merger terms, or weak customer backing would lower the quality of the setup.
Demand sourceAI load, industry, reliability
Utility actionNuclear + grid investment
Collection routeRates, riders, tariffs, PJM
Proof pointEPS, FFO/debt, orders
Regulated nuclear recovery matters because existing nuclear plants and host-utility service territories can support clean-firm power before most new reactors are licensed, financed, built, and fueled. Equity value appears only when nuclear output, uprates, license extensions, large-load interconnections, generation, transmission, and distribution spend become approved rate base or contracted cash flow. The useful proof is concrete: signed MW, customer deposits, minimum bills, stranded-cost protection, state or FERC orders, allowed return, nuclear capacity factor, EPS guidance, operating cash flow, FFO/debt, and share count after financing.
The strongest evidence is split across the basket. PEG has the best relative-value mix because PSE&G rate-base growth sits next to PSEG Power nuclear output and PJM capacity exposure. SO has the clearest regulated nuclear route through Vogtle, Southeast load, state-regulated capex, and DOE/FFB financing support. ETR has the best near-term host-load evidence from Gulf South industrial and hyperscale demand. DUK has broad Carolinas, Florida, and Midwest regulated scale plus Brookfield Florida funding. D has Virginia data-center load and North Anna/Surry nuclear exposure, but the NEE exchange ratio and approvals now shape the security. AEP stays on the watch list because contracted load evidence is strong, while the nuclear link is less central.
The setup fails when utilities spend before collection is secure. Regulators can delay riders, reduce allowed ROE, disallow costs, require customer credits, or force a fight over whether large-load customers or ordinary customers pay. Nuclear adds outage, refueling, NRC, uprate, license-extension, PTC, ZEC, and PJM capacity-market risk. Funding is the live constraint: SO, ETR, DUK, and D all need credit metrics to hold after capex, debt, minority capital, forward equity, or merger terms; PEG needs BPU/FERC/PJM outcomes and no-common-equity funding to remain credible. Watch rate orders, customer-funded infrastructure, nuclear availability, FFO/debt, and weekly setup levels together.
Right-rail setup labels use weekly bars aggregated from discovery daily_ohlc through 2026-06-12. Fundamental claims route to the parent nuclear-power theme, the power-scarcity theme, the utilities sector lane, linked security lanes, and the official sources listed below.
Basket
The basket is inherited from the parent nuclear-power value-chain map and reranked by relative value, node-specific recovery evidence, value drivers, financing burden, and current technical setup. Chart timing only breaks ties after the business evidence is scored. AEP is retained as a watch tail because it has the strongest large-load tariff and capex evidence outside the core basket, but its nuclear specificity is weaker than the five ranked names.
Best relative-value blend of New Jersey regulated recovery, Salem and Hope Creek nuclear output, and PJM capacity optionality.
Market cap$38.4B
Next earningsAug 4, 2026 est.
Latest qtr revenue$3.848B
Role in stack
PSE&G customers fund New Jersey transmission, electric distribution, and gas investment through BPU and FERC rates, while PSEG Power sells nuclear output and capacity into PJM. The conversion gate is BPU/FERC recovery, PJM capacity and production tax credit treatment, plant availability, debt funding, and the no-common-equity plan.
Revenue mix
Q1 2026 segment revenue before eliminations was PSE&G $3.085B and PSEG Power & Other $1.416B. PSE&G is the regulated core; PSEG Power provides the nuclear/PJM upside and variability.
Latest qtr revenue
Q1 2026 total operating revenue was $3.848B in the PSEG Q1 2026 release. The same source reported GAAP net income of $741M, non-GAAP operating EPS of $1.55, and about 8 TWh of nuclear generation at a 95.5% capacity factor.
Clearest regulated nuclear recovery route through Vogtle, Southeast load growth, state utility capex, and DOE/FFB support.
Market cap$103.5B
Next earningsJul 30, 2026 est.
Latest qtr revenue$8.397B
Role in stack
Georgia Power, Alabama Power, Mississippi Power, and the gas utility platform convert nuclear reliability, generation, grid work, and Southeast large-load demand into state-regulated earnings. The gate is recovery orders, cost allocation, customer contribution detail, DOE/FFB draw terms, bill impact, and credit metrics after funding.
Revenue mix
Q1 2026 revenue was led by traditional electric operating companies at $5.482B, Southern Company Gas at $2.191B, and Southern Power at $681M. Company materials frame about 95% of 2026-2030 capex as state-regulated utility capex.
Latest qtr revenue
Q1 2026 operating revenue was $8.397B in Southern's Q1 2026 materials. The same source reported adjusted EPS of $1.32 and 2026 adjusted EPS guidance of $4.50-$4.60.
Best current host-load evidence from Gulf South industrial and hyperscale demand, with visible financing pressure.
Market cap$51.1B
Next earningsJul 29, 2026 est.
Latest qtr revenue$3.188B
Role in stack
Entergy serves Arkansas, Louisiana, Mississippi, New Orleans/Louisiana mechanisms, and Texas. Gulf South industrial and hyperscale customers create demand for generation, transmission, distribution, resilience, customer-specific infrastructure, and nuclear-fleet reliability; conversion depends on state and FERC recovery, CWIP, riders, formula mechanisms, customer contributions, and credit metrics.
Revenue mix
Almost all consolidated revenue is regulated electric utility revenue. Q1 2026 electric utility revenue was $3.170B of $3.188B consolidated revenue, about 99.5%; Parent & Other is mainly financing and residual drag.
Latest qtr revenue
Q1 2026 operating revenue was $3.187626B in Entergy's latest security lane and Q1 release. The same source reported Q1 industrial volume up 14.9%, weather-adjusted retail sales up 6.0%, and adjusted EPS of $0.86.
Scaled Carolinas, Florida, and Midwest regulated nuclear host that still needs fresher nuclear/load-contract proof.
Market cap$96.8B
Next earningsAug 4, 2026 est.
Latest qtr revenue$9.178B
Role in stack
Duke serves regulated electric and gas customers across the Carolinas, Florida, the Midwest, and other state jurisdictions. Electric load and nuclear-host exposure can justify generation and grid capex; conversion is controlled by state rate cases, riders, storm and fuel mechanisms, Brookfield Florida funding, interconnection evidence, and credit metrics.
Revenue mix
Regulated electric utilities dominate the setup, with gas utilities and holding-company funding mattering for consolidated credit. Q1 2026 Electric Utilities and Infrastructure adjusted segment income was about $1.404B and Gas Utilities and Infrastructure was about $361M.
Latest qtr revenue
Q1 2026 operating revenue was about $9.178B in the Duke security lane and Q1 2026 earnings source. The same lane reports 2026 adjusted EPS guidance of $6.25-$6.45 and an $87B five-year capital plan.
Virginia nuclear and data-center host whose stock is now partly a NextEra exchange-ratio and approval-probability security.
Market cap$54.4B
Next earningsNot confirmed
Latest qtr revenue$5.019B
Role in stack
Dominion Energy Virginia, North Anna, Surry, grid investment, generation, CVOW, and large-load infrastructure make D a real Virginia host-utility route. Recovery runs through Virginia SCC, South Carolina, FERC, NRC, large-load tariff design, and merger approvals; the stock also depends on the NEE exchange ratio and approval conditions.
Revenue mix
Q1 2026 total operating revenue was $5.019B; the Q1 10-Q revenue note shows regulated electric sales as the main component, including residential, commercial, high-load, industrial, government/other retail, and wholesale revenue. Virginia Power operating revenue was $3.696B.
Latest qtr revenue
Q1 2026 total operating revenue was $5.019B in Dominion's Q1 2026 10-Q article. Dominion's lane also reports Q1 operating EPS of $0.95, 2026 operating EPS guidance of $3.45-$3.69, and planned 2026 debt issuance of $6.0B-$9.5B.
Market caps use read-only discovery instruments.market_cap queried on 2026-06-13. Next-earnings dates for PEG, SO, ETR, and DUK come from Nasdaq/Zacks algorithmic estimates checked on 2026-06-13 and are labeled est.; Nasdaq had no provided Dominion date and Dominion's IR events page did not list an upcoming event, so D is marked Not confirmed. Latest-quarter revenue uses the linked security lanes and company Q1 2026 releases or 10-Q article routes.
What Confirms Or Weakens
AreaWhat confirmsWhat weakens or invalidatesWatch next
01Node thesis
Nuclear and host load become payable
What confirms
Approved rate orders, riders, CWIP, special tariffs, capacity revenue, and customer contributions convert nuclear and large-load spending into earned rate base, EPS, cash flow, and stable credit metrics.
What weakens or invalidates
Pipeline demand stays non-binding, customers delay or self-supply, regulators shift costs away from large-load customers, or earnings growth requires more debt and equity than planned.
State and federal orders approve cost recovery, allowed ROE, equity layer, rider timing, customer prepayments, and stranded-cost protection without major disallowance.
What weakens or invalidates
Lower allowed returns, refunds, disallowances, deferred recovery, bill credits, rate caps, or regulatory assets rising faster than cash recovery reduce conversion quality.
High capacity factors, license extensions, uprates, recoverable life-extension work, capacity payments, PTC treatment, and NRC progress support cash flow.
What weakens or invalidates
Forced outages, refueling slips, NRC delays, uprate cost inflation, adverse PJM/PTC/ZEC treatment, or capex disallowance cuts available MWh or recovery.
Watch next
PEG nuclear output
PJM capacity revenue
NRC/license updates
Plant reliability disclosures
04Customer and cost allocation
Large loads protect ratepayers
What confirms
Signed service agreements include deposits, minimum bills, credit support, termination payments, customer-funded interconnection, and protection for non-participating customers.
What weakens or invalidates
Load queues remain speculative, cost shifts to residential customers, large users cancel or renegotiate, or infrastructure spend precedes enforceable customer backing.
Watch next
Customer-backed filings
Special tariff updates
Energization schedules
Bill-impact tables
05Funding and credit
Per-share economics hold
What confirms
FFO/debt, debt-to-capital, rating outlooks, interest expense, and EPS per share hold after capex, DOE/FFB borrowing, minority capital, forward equity, and debt issuance.
What weakens or invalidates
Equity issuance expands beyond plan, rating outlooks worsen, debt cost rises, or operating cash flow trails capex and dividends without a visible rate-recovery bridge.
Watch next
SO forward shares and DOE/FFB
ETR forward equity
DUK Brookfield closing
D debt issuance
PEG no-common-equity plan
06Policy and Stale condition
Refresh trigger
What confirms
Discovery daily_ohlc remains current through 2026-06-12, chart packages still load from the report API, and no material earnings, rate order, merger, financing, credit, tariff, or nuclear availability update has arrived since the cited sources.
What weakens or invalidates
A new trading session, earnings release, rate-case order, financing announcement, credit action, merger filing, large-load disclosure, or nuclear outage arrives before the page is refreshed.
Power Scarcity And Grid Load for the demand-to-cash conversion frame, utility recovery tests, and large-load evidence route.
AI Capex Cycle for the demand-origin route; it does not prove utility cost recovery by itself.
Utilities sector lane for rate-case, capex, load, affordability, fuel, storm, and credit constraints.
Security Lanes
PEG security lane for PSE&G recovery, PSEG Power nuclear output, PJM capacity revenue, guidance, capex, and funding constraints.
SO security lane for Vogtle, Southeast load, state-regulated capex, DOE/FFB financing support, guidance, debt, and forward-share exposure.
ETR security lane for Gulf South industrial and hyperscale load, revenue concentration, FFO/debt, forward equity, and rate-recovery proof burden.
DUK security lane for regulated scale, capex, guidance, Brookfield Florida funding, debt, and source gaps around current nuclear/load-contract detail.
D security lane for Virginia host load, North Anna/Surry, capex, debt issuance, CVOW, and the pending NEE transaction.
AEP security lane is a watch route because AEP has strong large-load recovery evidence and Cook nuclear exposure, but the nuclear component is not central enough for this core basket.
Next-earnings estimates for PEG, SO, ETR, and DUK were checked on 2026-06-13 through Nasdaq API endpoints /api/analyst/PEG/earnings-date, /api/analyst/SO/earnings-date, /api/analyst/ETR/earnings-date, and /api/analyst/DUK/earnings-date. Nasdaq states these are algorithmic estimates from historical reporting dates and Zacks Investment Research, so the Basket labels them est..
Estimated next earnings: PEG Aug 4, 2026; SO Jul 30, 2026; ETR Jul 29, 2026; DUK Aug 4, 2026. Nasdaq's /api/analyst/D/earnings-date response said Zacks had not provided an upcoming date for D; Dominion's IR events page showed no listed upcoming event when checked on 2026-06-13, so D is marked Not confirmed.
Latest-quarter revenue sources: PEG Q1 2026 total operating revenue $3.848B from the PSEG Q1 2026 release; SO Q1 2026 operating revenue $8.397B from Southern's Q1 2026 release and lane; ETR Q1 2026 operating revenue $3.187626B from Entergy's Q1 release and lane; DUK Q1 2026 operating revenue about $9.178B from Duke's Q1 release and lane; D Q1 2026 total operating revenue $5.019B from the local clipped Dominion Q1 2026 10-Q article 10-Q (sec.gov 12).
Dominion's company release URL returned HTTP 403 to direct command-line fetch during this worker pass, so Dominion revenue was verified from the already-clipped local 10-Q article and source lane rather than re-fetched from the press-release page.
Discovery And Chart Provenance
Chart/setup provenance uses read-only daily_ohlc from ../discovery/data/discovery.duckdb for PEG, SO, ETR, DUK, and D 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.
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. The local API at 127.0.0.1:8765 was unavailable during validation, so live chart rendering remains unverified.
discovery status showed 1,278 daily bars and daily_ohlc through 2026-06-12 for PEG, SO, ETR, DUK, and D. Read-only DuckDB market-cap query on 2026-06-13 returned PEG $38.4B, SO $103.5B, ETR $51.1B, DUK $96.8B, and D $54.4B. Representative per-ticker lineage checks surfaced May 2026 backfills, while grouped daily market updates extend local rows through 2026-06-12.
The former body setup table was removed. Static setup labels and thresholds remain in the selected-security rail metadata and prior sidecar chart assumptions; if live API chart data moves beyond the 2026-06-12 static thresholds, refresh setup levels before using them as current trading evidence.
Known Gaps
DUK needs fresher plant-level nuclear, load-contract, rate-case, debt, and Brookfield detail before it can outrank the top three.
ETR needs current Investor Day and plant-level nuclear evidence before the load thesis can be treated as fully de-risked.
D should be read as a special situation until the NEE transaction, Virginia SCC, CVOW, NRC/FERC, and debt issuance paths are clearer.
PNW and DTE have local OHLC coverage and nuclear assets, but no durable local security lanes were found for this page; keep them out of the ranked basket until source routing is built.