Constellation Energy

Constellation Energy is the largest private-sector power producer and the largest nuclear energy company in the U.S., with a 55 GW fleet spanning nuclear, natural gas, geothermal, hydro, wind, and solar. The business monetizes firm, around-the-clock electricity through retail supply and direct PPAs, which is exactly what AI data-center operators need.

Constellation Energy is the largest U.S. generator of carbon-free electricity, operating ~21 GW of nuclear fleet (24 reactors) plus natural gas (via Calpine acquisition Jan 2026), geothermal, solar, and wind. Serves commercial/industrial, data center, and utility customers directly via Power Purchase Agreements.

Constellation Energy is the largest U.S. nuclear generator and a major firm-power supplier for hyperscalers and data-center operators, with the Calpine acquisition broadening its flexible generation stack.

Constellation Energy is the largest U.S. nuclear generator and, after the January 2026 Calpine close, the largest U.S. clean firm-power producer (~55 GW combined fleet). The differentiated bottleneck is not "power" in the abstract — it is the intersection of (a) an irreplaceable nuclear fleet running at world-class capacity factor and (b) the Inflation Reduction Act nuclear production tax credit (PTC) that monetizes that fleet's output.

• monetization model: Wholesale + retail electricity sales; capacity; RECs/environmental attributes; natural gas; energy optimization (10-K FY2024, Acc. 0001868275-25-000006, sec.gov , Item 1, Note 3).
• revenue mix: One reportable segment. FY2024 product mix: electricity ~73%, capacity ~10%, natural gas ~7%, RECs ~5%, other ~5% (10-K Note 3).
• who pays: Wholesale power buyers (utilities/grid operators, retail suppliers, municipalities/co-ops) and retail C&I/government/data-center customers (10-K Item 1).
• margin_value_capture: Net income margin ~16% FY2024 ($3.75B net income / $23.57B revenue). Value accrues at owned nuclear generation—fuel, capacity, RECs, nuclear PTC—plus retail/wholesale optimization; commodity/hedging risk remains (10-K MD&A, Item 1A).

• customer classes: Utility - Grid Operators, Data Center Operators, Hyperscalers, Industrial Infrastructure Owners, commercial/industrial retail customers, governmental/institutional buyers, municipalities/cooperatives (10-K Item 1, Note 3).

Constellation Energy Corporation is a competitive electric-generation and energy-supply company. It is the merchant-generation business that separated from Exelon Corporation in February 2022. CEG owns and operates a large baseload fossil, nuclear, hydro, wind, and solar fleet and sells electricity, capacity, ancillary services, and retail energy products into competitive wholesale markets and directly to end-use customers.

CEG’s customers fall into four broad classes:

1. Wholesale grid operators and utilities that buy energy, capacity, and ancillary services.
2. Retail mass-market customers in deregulated states, including residential and small commercial accounts.
3. Large commercial and industrial customers such as manufacturers, hospitals, universities, data centers, and government entities.
4. Structured transaction counterparties that sign long-term physical or financial contracts for energy, capacity, or clean attributes.

• Data centers / hyperscalers: Microsoft is the announced counterparty for the Three Mile Island Unit 1 restart PPA. This is a major buyer archetype because data centers need 24/7 power and often have net-zero commitments.
• Utilities and cooperatives: regional utilities buy from CEG through wholesale markets and bilateral contracts.
• Commercial and industrial end-users: CEG’s retail business serves businesses in competitive markets; specific names are generally not disclosed in public filings unless material.
• Residential consumers: CEG Home and Business sells retail energy contracts; individual names are not disclosed.

Constellation Energy Corporation (“CEG” or “Constellation”) is a competitive power generator and retail energy supplier operating primarily in the United States. It separated from Exelon Corporation on February 1, 2022, and is now the largest producer of carbon-free electricity in the U.S. by output, with a generating fleet that includes one of the nation’s largest nuclear fleets, plus hydroelectric, wind, solar, and natural gas assets.

CEG’s core business model is to generate electricity and sell it into competitive wholesale markets—PJM, MISO, NYISO, ERCOT, and ISO-New England—while also selling electricity directly to commercial, industrial, and residential customers. The company earns revenue through several linked streams:

• Wholesale energy sales at regional market prices
• Capacity payments from ISOs/RTOs for available generation
• Retail supply margins on fixed-price customer contracts
• Renewable energy credits and ancillary services
• Federal nuclear production tax credits beginning in 2024
• Financial hedges used to stabilize future revenue

This is not a utility model; CEG is a merchant generator, meaning it generally does not recover costs through regulated rates. Its revenue depends on market prices, capacity market outcomes, and the value of its generation fleet.

The company reports revenue by geographic generation/load region rather than by product line. The following segment revenue table is from the FY2023 Form 10-K, Note 17 (Segment Information). The FY2023 operating revenue total was $24,918 million, up from $24,440 million in FY2022. [S1]

Source: [S1] — CEG FY2023 Form 10-K, Note 17; filed Feb. 27, 2024; accession no. 0001868275-24-000007; access date Apr. 30, 2026. These segment values are single-filing disclosures for revenue mix; they are tagged [SINGLE-SOURCE] for conviction purposes because they have not been independently cross-verified against a second originating source.

CEG’s more recent total results, from the FY2024 Form 10-K, show total operating revenue of $23,568 million, net income of $2,907 million, and adjusted EBITDA of $4,663 million. [S2] — CEG FY2024 Form 10-K, Item 7/Item 8; filed Feb. 18, 2025; accession no. 0001868275-25-000007; access date Apr. 30, 2026. The exact FY2024 segment mix is not reproduced here because the segment table in the 2024 filing should be validated directly before it is used in a model; the FY2023 table is used instead as the last internal segment table that has been traced in this note.

CEG’s GAAP operating margin and net margin are less stable than its adjusted EBITDA margin because energy-commodity accounting includes mark-to-market swings, plant retirements, and acquisition costs. The following margins derive from the FY2023 Form 10-K income statement and MD&A:

Source: [S1] — CEG FY2023 Form 10-K, Item 7 and Item 8; accession no. 0001868275-24-000007; filed Feb. 27, 2024; access date Apr. 30, 2026.

These values are from one issuer filing and therefore carry [SINGLE-SOURCE] confidence. Adjusted EBITDA is non-GAAP and should not be used as a substitute for GAAP net income; CEG’s reconciliation appears in the FY2023 10-K MD&A.

CEG does not report a conventional “gross margin” in the same way a manufacturing company would. The largest variable cost is purchased power and fuel, and the company reports operating income after purchased power, fuel, operations and maintenance, depreciation, and taxes other than income. Therefore the economically meaningful margin used by management and investors is adjusted EBITDA margin.

CEG monetizes its fleet across wholesale and retail channels. In the wholesale channel, counterparties are RTO/ISO settlements and bilateral counterparties; in the retail channel, CEC earns a margin between the supply cost and the fixed price charged to the customer. The company also earns capacity revenues—payments for committing generation capacity to the market, not for electricity produced—which supports grid reliability and creates a source of revenue even when units do not run frequently. This is especially important for nuclear units that run as baseload and for peaking gas units that run only at high demand.

CEG’s largest disclosed customer-facing contract is the 20-year power purchase agreement with Microsoft Corporation for the output of Crane Clean Energy Center, the former Three Mile Island Unit 1. CEG announced the agreement in 2024 and the FY2024 10-K includes disclosure of the data-center agreement. [S2] That agreement is a load-bearing proof that CEG is selling directly to large technology customers for new demand, not just into wholesale markets. Other commercial and industrial buyers are generally not named in SEC filings because no individual customer reaches the threshold that would require disclosure.

CEG sells to four broad customer classes:

1. Wholesale market counterparties / RTOs and ISOs — PJM, MISO, NYISO, ERCOT, and ISO-New England settle energy and capacity transactions. CEG sells power into these regional markets and receives capacity payments.

1. Commercial and industrial customers — Large businesses that buy retail electricity and gas under fixed-price contracts. These are the highest-value retail accounts because their volumes are large and they often care about price certainty and carbon attributes.

1. Public sector, utilities, municipalities, cooperatives — Public-power entities and cooperatives buy wholesale power through PPAs or retail arrangements. CEG has existing supply relationships across multiple regions.

1. Data center and technology customers — The most important new buyer class. The disclosed Microsoft PPA for Crane Clean Energy Center is the clearest named example. [S2] The FY2024 10-K also discusses data-center demand as a driver of commercial activity. The other data-center counterparties are not named individually in the SEC filing because disclosure rules do not require naming unless a customer is material or the contract is specifically described.

CEG’s prior 10-K does not disclose a single wholesale customer that accounts for more than 10% of revenue, based on the absence of a customer-concentration disclosure in the FY2023 filing. [S1] That absence is itself a data point: revenue is highly diversified across thousands of retail accounts and market settlements, which reduces single-counterparty risk.

The only named major end customer appearing in CEG’s SEC filings in the data-center PPA context is Microsoft Corporation. The agreement is for 20 years and covers the output of the Crane Clean Energy Center, the former Three Mile Island Unit 1, which CEG intends to restart. The contract is described in the FY2024 10-K and was announced earlier via Form 8-K. [S2]

No other megacap customer is named in the public SEC documents examined for this note. If an analyst sees press reports naming additional data-center counterparties, those reports should be treated as Tier 2 contextual data and cross-checked against CEC’s next Form 10-K or 8-K.

FY2025 revenue $25.53B (+8.34% YoY); TTM revenue $29.87B. Gross margin 18.38% FY2025 (22.85% TTM); operating margin 12.09% FY2025 (16.63% TTM). Q1 2026 operating revenue was $11.12B (+63.85% YoY) after Calpine closed.

Q1 2026 operating revenues $11,122M (+64% YoY vs $6,788M Q1 2025). Note: Revenue increase primarily due to Calpine acquisition closed January 2026, which added ~17 GW of natural gas capacity. Pro-forma Q1 2026 combined revenue $11,352M. (Source: CEG 10-Q Q1 2026, SEC EDGAR filed 2026-05-11, CIK 0001868275)

FY2025 revenue was $25.533B with gross margin 18.38% and operating margin 12.09%; TTM revenue is $31.270B with gross margin 21.43% and operating margin 14.70% (StockAnalysis Financials Overview → Revenue & Profits / Margin tables). Q2 2026 revenue was $5.843B (+13.2% YoY vs $5.161B in Q2 2025), operating income was $580M, and net income was $513M (SEC companyfacts for 2026-08-06 10-Q).

Operating revenues $7,504M (Q2) / $18,626M (H1); GAAP net income attributable to common shareholders $513M (Q2, −38.9% YoY from $839M) and $2,103M (H1); GAAP EPS $1.42, adjusted (non-GAAP) operating EPS $2.55; FY2026 adjusted operating EPS guidance raised to $11.50–$12.50. (10-Q + EX-99.1, filed 2026-08-06.)

AI data centers need clean, reliable 24/7 power with long-duration firming and grid access. Constellation now owns the largest nuclear fleet in the country plus flexible thermal capacity after Calpine, and it is directly contracting with hyperscalers for incremental load.

Constellation is the single largest supplier of 24/7 carbon-free nuclear power in the U.S., making it the preferred counterparty for AI hyperscalers seeking clean baseload power. Nuclear PTCs (Production Tax Credits from IRA) + data center PPAs create a durable moat; Microsoft Three Mile Island restart deal is the archetype.

AI data centers need licensed, interconnectable, 24/7 firm power. Constellation’s moat is the scarcity of existing nuclear MW plus the regulatory/interconnection rights needed to monetize them; the 2026-08-06 release says FERC granted the CIR waiver for Crane Clean Energy Center and NRC approved its fuel license, while CEG signed an additional 920 MW of long-term PPAs.

AI datacenters need firm, 24/7, carbon-free power with grid access and decade-scale scarcity. CEG is the single most direct public-equity expression of that scarcity.

• In Q1 2026, Constellation signed a new 380 MW agreement with CyrusOne to connect and serve a new data center adjacent to the Freestone Energy Center, giving the customer access to power, grid connectivity, and site infrastructure while preserving grid reliability. (SEC 10-Q, 2026-05-11)
• The 2025 10-K says Constellation became the largest private-sector power producer in the world after the Calpine merger, with 55 GW of capacity and ~2.5 million customer accounts, including 80% of the Fortune 100. (SEC 10-K, 2026-02-24)
• The Crane Clean Energy Center restart is supported by a 20-year Microsoft PPA; once operational, the site is expected to have ~835 MW of emissions-free capacity aimed at helping power Microsoft's data centers in PJM. (SEC 10-K, 2026-02-24)
• Calpine closed on January 7, 2026 for approximately $21.8B, adding roughly 23 GW of generation and battery storage assets and materially expanding CEG's flexible supply stack. (SEC 10-K, 2026-02-24)
• Q1 2026 revenue $11,122M (+64% YoY), bolstered by Calpine acquisition adding ~17 GW of gas capacity alongside 21 GW nuclear fleet (Source: CEG Q1 2026 10-Q)
• Calpine acquisition (~$16.4B enterprise value) completed January 2026, creating largest combined nuclear + gas fleet targeting AI data centers (Source: CEG 10-Q notes)
• Nuclear PTCs under IRA 2022 providing floor price protection; eligible generating assets generating ~178 TWh/year of carbon-free electricity (Source: CEG filings)
• 2026-08-06 earnings release: GAAP EPS $1.42, adjusted operating EPS $2.55, FY2026 adjusted operating earnings guidance raised to $11.50–$12.50/share, 920 MW of additional long-term PPAs, and FERC/NRC approvals for Crane Clean Energy Center.
• 2026-08-06 10-Q companyfacts: Q2 revenue $5.843B, operating income $580M, net income $513M.
• StockAnalysis FY2025 table: revenue $25.533B, gross margin 18.38%, operating margin 12.09%; TTM revenue $31.270B, gross margin 21.43%, operating margin 14.70%.
• The 2025 10-K / existing vault note places the Crane Clean Energy Center restart at ~835 MW of emissions-free capacity; the 8/6 release shows the regulatory gates are now advancing.

Annual electricity output:

\[

835\ \text{MW} \times 8{,}760\ \text{hours} \times 0.96

= 7{,}022{,}976\ \text{MWh/year}

\]

That is approximately 7.0 million MWh/year.

Capital cost per kW:

\[

\frac{\$1.6\text{B}}{835{,}000\ \text{kW}} = \$1{,}916/\text{kW}

\]

Capital cost per MWh over the 20-year contract life:

\[

\frac{\$1.6\text{B}}{7{,}022{,}976 \times 20}

=

\frac{\$1.6\text{B}}{140{,}459{,}520}

=

\$11.39/\text{MWh}

\]

At an assumed $100/MWh PPA price:

\[

\text{Annual revenue} =

7{,}022{,}976 \times \$100

=

\$702.3\text{M}

\]

\[

\text{20-year revenue} =

\$702.3\text{M} \times 20

=

\$14.0\text{B}

\]

At a higher but plausible $110/MWh PPA price:

\[

\text{20-year revenue} =

7{,}022{,}976 \times \$110 \times 20

\approx \$15.4\text{B}

\]

Using the assumed $25/MWh cash O&M/fuel plus $11.39/MWh capital recovery:

\[

\text{Total cash cost} =

\$25 + \$11.39

=

\$36.39/\text{MWh}

\]

\[

\text{Operating margin} =

\$100 - \$36.39

=

\$63.61/\text{MWh}

\]

\[

\text{Annual pre-tax cash margin} =

7{,}022{,}976 \times \$63.61

\approx \$447\text{M}

\]

\[

\text{Simple payback} =

\frac{\$1.6\text{B}}{\$447\text{M}}

\approx 3.6\ \text{years}

\]

This calculation is illustrative only because the PPA price and incremental operating costs are not public. The capital cost is measured from CEG’s press release; the PPA price is explicitly an assumption.

Upper case, wage-and-apprentice-compliant PTC rate:

\[

172{,}400{,}000 \text{ MWh} \times \$15/\text{MWh} = \$2{,}586{,}000{,}000

\]

That is $2.586 billion of gross nuclear tax credits per year before phase-out.

Base case, if wage/apprentice requirements are not met:

\[

172{,}400{,}000 \text{ MWh} \times \$3/\text{MWh} = \$517{,}200{,}000

\]

That is $517 million per year before phase-out.

If nuclear generation falls by 10% from the FY2023 base to 155,160,000 MWh, the upper PTC calculation changes:

\[

155{,}160{,}000 \text{ MWh} \times \$15/\text{MWh} = \$2{,}327{,}400{,}000

\]

The difference from the upper case is $258.6 million, or 10%. The PTC is therefore highly sensitive to both the statutory wage multiplier and to nuclear fleet output.

The actual PTC benefit recognized by CEG is lower than the gross calculation if statutory phase-out applies. Under the IRA, the nuclear PTC phases out based on gross receipts thresholds for the facility. CEG’s 10-K describes the credit and its limitations, but the company’s realized PTC benefit for 2024 and later years must be traced to its tax footnotes and MD&A before being used as a hard estimate. The gross calculation above is a policy-sensitivity exercise, not a statement of realized tax benefit. [S1]

This worked calculation shows why the PTC is a load-bearing variable: at 172.4 TWh of nuclear output, moving between the base and wage-rate PTC changes the gross credit by about $2.07 billion per year before phase-out. Investors should monitor CEG’s compliance with wage/apprenticeship requirements and any statutory changes to the credit.