Form 8-K

8-K — Constellation Energy Corp

Accession: 0001868275-26-000097

Filed: 2026-08-06

Period: 2026-08-06

CIK: 0001868275

SIC: 4911 (ELECTRIC SERVICES)

Item: Results of Operations and Financial Condition

Item: Regulation FD Disclosure

Item: Financial Statements and Exhibits

Documents

8-K — ceg-20260806.htm (Primary)

EX-99.1 (ceg-20260806991.htm)

EX-99.2 (ceg-20260806992.htm)

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8-K

8-K (Primary)

Filename: ceg-20260806.htm · Sequence: 1

ceg-20260806

Pennsylvania1310 Point StreetBaltimoreMaryland21231-3380(833)883-0162Pennsylvania200 Energy WayKennett SquarePennsylvania19348-2473(833)883-0162Common Stock, without par valueCEGThe Nasdaq Stock Market LLC00018682750001168165False☐00018682752026-08-062026-08-060001868275ceg:ConstellationEnergyGenerationLLCMember2026-08-062026-08-06

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 8-K

CURRENT REPORT

Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

August 6, 2026

Date of Report (Date of earliest event reported)

Commission

File Number Name of Registrant; State or Other Jurisdiction of Incorporation; Address of Principal Executive Offices; and Telephone Number IRS Employer Identification Number

001-41137 CONSTELLATION ENERGY CORPORATION 87-1210716

(a Pennsylvania corporation)

1310 Point Street

Baltimore, Maryland 21231-3380

(833) 883-0162

333-85496 CONSTELLATION ENERGY GENERATION, LLC 23-3064219

(a Pennsylvania limited liability company)

200 Energy Way

Kennett Square, Pennsylvania 19348-2473

(833) 883-0162

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

☐ Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

☐ Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

☐ Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

☐ Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Securities registered pursuant to Section 12(b) of the Act:

Title of each class Trading Symbol(s) Name of each exchange on which registered

CONSTELLATION ENERGY CORPORATION:

Common Stock, without par value

CEG

The Nasdaq Stock Market LLC

Indicate by check mark whether any of the registrants are emerging growth companies as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).

Emerging growth company ☐

If an emerging growth company, indicate by check mark if any of the registrants have elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Section 2 - Financial Information

Item 2.02. Results of Operations and Financial Condition

Section 7 - Regulation FD

Item 7.01. Regulation FD Disclosure

On August 6, 2026, Constellation Energy Corporation (Nasdaq: CEG) announced via press release its results for the second quarter ended June 30, 2026. A copy of the press release and related attachments are attached hereto as Exhibit 99.1. Also attached as Exhibit 99.2 to this Current Report on Form 8-K are the presentation slides to be used during the second quarter 2026 earnings conference call. This Form 8-K and the attached exhibits are provided under Items 2.02, 7.01 and 9.01 of Form 8-K and are furnished to, but not filed with, the Securities and Exchange Commission.

We have scheduled the conference call for 10:00 AM ET on August 6, 2026. To access the call by phone, please follow the registration link available on the Investor Relations page of our website: https://investors.constellationenergy.com. The call will also be webcast and archived on the Investor Relations page of our website. Media representatives are invited to participate on a listen-only basis.

Section 9 - Financial Statements and Exhibits

Item 9.01. Financial Statements and Exhibits

(d)    Exhibits.

Exhibit No. Description

99.1

Press release and earnings release attachments

99.2

Earnings conference call presentation slides

101 Cover Page Interactive Data File - the cover page XBRL tags are embedded within the Inline XBRL document.

104 The cover page from the Current Report on Form 8-K, formatted as Inline XBRL.

* * * * *

This combined Current Report on Form 8-K is being furnished separately by Constellation Energy Corporation and Constellation Energy Generation, LLC, (collectively, the Registrants). Information contained herein relating to one of the Registrants has been furnished by the Registrant on its own behalf. Neither Registrant makes any representation as to information relating to the other Registrant.

This report contains certain forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995 that are subject to risks and uncertainties. Words such as “could,” “may,” “expects,” “anticipates,” “will,” “targets,” “goals,” “projects,” “intends,” “plans,” “believes,” “seeks,” “estimates,” “predicts,” and variations on such words, and similar expressions that reflect our current views with respect to future events and operational, economic, and financial performance, are intended to identify such forward-looking statements. These forward-looking statements include, but are not limited to, statements regarding the acquisition of Calpine Corporation, the pro forma combined company and its operations, strategies and plans, enhancements to investment-grade credit profile, synergies, opportunities and anticipated future performance and capital structure, and expected accretion to earnings per share and free cash flow. Information adjusted for the acquisition should not be considered a forecast of future results.

Forward-looking statements are based on current expectations, estimates and assumptions that involve a number of risks and uncertainties that could cause actual results to differ materially from those projected. The factors that could cause actual results to differ materially from the forward-looking statements made by the Registrants include those factors discussed herein, as well as the items discussed in (1) the Registrants' combined 2025 Annual Report on Form 10-K in (a) Part I, ITEM 1A. Risk Factors, (b) Part II, ITEM 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations, and (c) Part II, ITEM 8. Financial Statements and Supplementary Data: Note 18 — Commitments and Contingencies; (2) the Registrants' Second Quarter 2026 Quarterly Report on Form 10-Q (to be filed on August 6, 2026) in (a) Part II, ITEM 1A. Risk Factors, (b) Part I, ITEM 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations, and (c) Part I, ITEM 1. Financial Statements: Note 15 — Commitments and Contingencies; and (3) other factors discussed in filings with the SEC by the Registrants.

Investors are cautioned not to place undue reliance on these forward-looking statements, whether written or oral, which apply only as of the date of this report. Neither Registrant undertakes any obligation to publicly release any revision to its forward-looking statements to reflect events or circumstances after the date of this report.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, each Registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

CONSTELLATION ENERGY CORPORATION

/s/ Shane P. Smith

Shane P. Smith

Executive Vice President and Chief Financial Officer

Constellation Energy Corporation

CONSTELLATION ENERGY GENERATION, LLC

/s/ Shane P. Smith

Shane P. Smith

Executive Vice President and Chief Financial Officer

Constellation Energy Generation, LLC

August 6, 2026

EXHIBIT INDEX

Exhibit No. Description

99.1

Press release and earnings release attachments

99.2

Earnings conference call presentation slides

101 Cover Page Interactive Data File - the cover page XBRL tags are embedded within the Inline XBRL document.

104 The cover page from the Current Report on Form 8-K, formatted as Inline XBRL.

EX-99.1

EX-99.1

Filename: ceg-20260806991.htm · Sequence: 2

Document

Exhibit 99.1

News Release

Contact:

Linsey Wisniewski

Corporate Communications

667-218-7700

Tim Flottemesch

Investor Relations

833-447-2783

CONSTELLATION REPORTS SECOND QUARTER 2026 RESULTS

Earnings Release Highlights

•GAAP Net Income of $1.42 per share and Adjusted (non-GAAP) Operating Earnings of $2.55 per share for the second quarter of 2026

•Raising full-year Adjusted (non-GAAP) Operating Earnings guidance range to $11.50 – $12.50 per share

•FERC grants waiver allowing the transfer of existing Capacity Interconnection Rights (CIR) to Crane Clean Energy Center, and NRC approves Crane Clean Energy Center's fuel license

•Signed an additional 920 megawatts of long-term power purchase agreements for clean, reliable generation

•Entered into agreement to divest the Brazos Valley Energy Center (f/k/a Jack A. Fusco Energy Center)

•Filed license renewal applications for two New York Nuclear units

•Recertified as a Great Place to Work for the fourth straight year, named to The Civic 50 by Points of Light for the second consecutive year, and received DisabilityIN World's Top Disability Inclusive Business recognition

Baltimore (Aug 6, 2026) — Constellation Energy Corporation (Nasdaq: CEG) today reported its financial results for the second quarter of 2026.

“This quarter's accomplishments reflect the momentum we're building across our business,” said Joe Dominguez, president and CEO of Constellation. “From advancing the restart of the Crane Clean Energy Center, to executing long-term agreements with our corporate customers and extending the lives of two critical New York assets, we’re strengthening the nation's energy infrastructure and helping meet growing demand for reliable power.”

“Our second-quarter results and increased full-year EPS guidance demonstrate the earnings power of our expanded platform, strong operational and commercial performance, and the disciplined execution of our capital allocation strategy,” said Shane Smith, executive vice president and chief financial officer of Constellation. “We remain focused on integrating Calpine, capturing the value of our expanded fleet and investing in opportunities that generate attractive returns. With a strong balance sheet, a differentiated customer facing business, and a generation portfolio well positioned to serve increasing demand for

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reliable energy, we are well positioned to deliver on our growth commitments and create sustained value for our owners.”

Second Quarter 2026

Our GAAP Net Income for the second quarter of 2026 decreased to $1.42 per share from $2.67 per share in the second quarter of 2025. Adjusted (non-GAAP) Operating Earnings for the second quarter of 2026 increased to $2.55 per share from $1.91 per share in the second quarter of 2025. For the reconciliations of GAAP Net Income (Loss) to Adjusted (non-GAAP) Operating Earnings, refer to the GAAP/Adjusted (non-GAAP) Operating Earnings Reconciliation section below.

Adjusted (non-GAAP) Operating Earnings in the second quarter of 2026 primarily reflects:

•The addition of Calpine and favorable market and portfolio conditions, partially offset by unfavorable nuclear outages

Recent Developments and Second Quarter Highlights

•Progress continues at Crane Clean Energy Center paving way for restart: FERC approved our waiver request to transfer CIRs from the dual fuel Eddystone Units 3 and 4 in Pennsylvania to the Crane Clean Energy Center. This decision clears a critical regulatory hurdle for the plant restart, we expect the transfer to expedite its ability to deliver reliable emissions-free power to the grid. Additionally, the NRC has approved a fuel license amendment request for the Crane Clean Energy Center — a major milestone moving us closer to restarting operations in 2027.

•Helping our customers meet their evolving energy needs: We have signed an additional 920 megawatts (MW) of long-term power purchase agreements (PPA) for clean, reliable nuclear generation with a diverse set of investment grade customers. These agreements are for 15-20 years in duration and are set to begin in 2029 through 2032. Among these PPAs, our 176 MW agreement with Walmart will enable a 30 MW capacity expansion at our Dresden Clean Energy Center in Illinois and facilitate additional investments to strengthen the local community by supporting jobs and enabling continued expansion of operations and workforce.

•Agreement to divest the Brazos Valley Energy Center: In August 2026, we entered into an agreement with LS Power to divest the Brazos Valley Energy Center (f/k/a Jack A. Fusco Energy Center), a 606 MW natural gas-fired plant in ERCOT for $860 million before closing adjustments, a key step in satisfying regulatory commitments related to our acquisition of Calpine earlier this year. This marks the last asset sale required by our regulatory commitments under the acquisition. Closing of the sale is subject to the receipt of approval by the DOJ, and other customary closing conditions. We expect the transaction to close by the end of this year.

•License renewal applications for two New York nuclear units: We have filed license renewal applications with the NRC to extend the operations of the Ginna Clean Energy Center and the Nine Mile Point Unit 1 reactor in upstate New York to 2049. If approved, the units' operating licenses would be extended 20 years, to 2049. Nine Mile Point Unit 2 is currently licensed to operate until 2046.

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•Recognized for our culture: For the fourth year in a row we were Certified™ by Great Place to Work®. The designation is based on how our employees rate their experience working at Constellation. In a survey of about 5,000 of our employees, 83% of those who responded said it is a great place to work – about 26 points higher than the average U.S. company. Great Place to Work® is acknowledged worldwide as a global benchmark for workplace culture, employee experience and the leadership behaviors proven to deliver strong market performance, employee retention and increased innovation.

For the second year in a row we were recognized as one of the Civic 50® and as the energy sector leader by Points of Light. The Civic 50® is a well-respected standard for corporate social impact, recognizing the most community-minded companies in the U.S. for how they show up through employee volunteerism, community investment and broader social impact efforts.

We were recognized as a World’s Top Disability Inclusive Business based on our performance on the Disability Index®, the leading benchmark for disability inclusion. This recognition signifies that we’re a leading performer in disability inclusion, accessibility and workplace practices. It's also a reflection of our commitment to fostering an environment where all employees can do their best work, advance their careers and feel a true sense of belonging.

•Nuclear Operations: Our nuclear fleet, including our owned output from the Salem and South Texas Project (STP) Generating Stations, produced 44,160 gigawatt-hours (GWhs) in the second quarter of 2026, compared with 45,170 GWhs in the second quarter of 2025. Excluding Salem and STP, our nuclear plants at ownership achieved a 93.0% capacity factor for the second quarter of 2026, compared with 94.8% for the second quarter of 2025. There were 86 planned refueling outage days in the second quarter of 2026 and 41 in the second quarter of 2025 for sites we operate. There were 20 non-refueling outage days in the second quarter of 2026 and 22 in the second quarter of 2025 for sites we operate.

•Natural Gas, Oil, and Renewables Operations: As a result of our expanded fleet following the acquisition of Calpine in January 2026, we now consider Equivalent Forced Outage Factor (EFOF) to be a key operational metric beginning in 2026. EFOF represents the percentage for which a generating unit is not available due to forced outages and forced deratings in a given period. The EFOF of our natural gas, oil, and pumped-storage hydro fleet for the second quarter of 2026 is 6.2%. Renewable energy capture for our wind, solar and run-of-river hydro fleet was 96.0% in the second quarter of 2026, compared with 96.1% in the second quarter of 2025.

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GAAP/Adjusted (non-GAAP) Operating Earnings Reconciliation

The table below provides a reconciliation of GAAP Net Income to Adjusted (non-GAAP) Operating Earnings. Adjusted (non-GAAP) Operating Earnings is not a standardized financial measure and may not be comparable to other companies’ presentations of similarly titled measures.

Unless otherwise noted, the income tax impact of each reconciling adjustment between GAAP Net Income (Loss) Attributable to Common Shareholders and Adjusted (non-GAAP) Operating Earnings is based on the marginal statutory federal and state income tax rates, taking into account whether the income or expense item is taxable or deductible, respectively, in whole or in part, which may result in an effective tax rate that differs from the marginal rate. The marginal statutory income tax rate was 25.5% for the three months ended June 30, 2026 and 2025. The following table provides a reconciliation between GAAP Net Income (Loss) Attributable to Common Shareholders and Adjusted (non-GAAP) Operating Earnings for the three months ended June 30, 2026 compared to the same period in 2025.

Three Months Ended June 30,

2026 2025

(In millions, except per share data)

Earnings

Per Share(a)

Earnings

Per Share(a)

GAAP Net Income (Loss) Attributable to Common Shareholders $ 513  $ 1.42  $ 839  $ 2.67

Unrealized (Gain) Loss on Fair Value Adjustments (net of taxes of $116 and $37, respectively)(b)

340  0.94  (121) (0.38)

Decommissioning-Related Activities (net of taxes of $298 and $208, respectively)(c)

(221) (0.61) (144) (0.46)

Amortization of Acquired Commodity Contracts (net of taxes of $51 and $—, respectively)(d)

149  0.41  —  —

Calpine Merger and Integration Costs (net of taxes of $17 and $3, respectively)(e)

84  0.23  9  0.03

Plant Retirements and Divestitures (net of taxes of $— and $2, respectively)

—  —  7  0.02

Pension & OPEB Non-Service (Credits) Costs (net of taxes of $7 and $3, respectively)

20  0.06  9  0.03

Change in Legal and Environmental Liabilities (net of taxes of $12 and $—, respectively)

35  0.10  —  —

Adjusted (non-GAAP) Operating Earnings $ 920  $ 2.55  $ 599  $ 1.91

_______

(a)Amounts may not sum due to rounding. Earnings per share amount is based on average diluted common shares outstanding of 360 million and 314 million for the three months ended June 30, 2026 and 2025, respectively.

(b)Includes unrealized gains and losses on economic hedges, interest rate swaps, and fair value adjustments related to gas imbalances and equity investments.

(c)Reflects all gains and losses associated with NDTs, ARO accretion, ARC depreciation, ARO remeasurement, and impacts of contractual offset for Regulatory Agreement Units. The tax effects of Regulatory Agreement Units result in a 100% effective tax rate under contractual offset accounting. Additionally, the tax effects of NDT investment returns result in different effective tax rates depending on whether the underlying funds are held within qualified or non-qualified trusts.

(d)In 2026, reflects the non-cash impacts of the amortization of certain commodity contracts recorded at fair value associated with the Calpine acquisition.

(e)Reflects costs associated with the completion of the Calpine merger and subsequent integration of its operations. Certain of these transaction-related expenses are not tax deductible.

Webcast Information

We will discuss second quarter 2026 earnings in a conference call scheduled for today at 10:00 a.m. Eastern Time. The webcast and associated materials can be accessed at https://investors.constellationenergy.com.

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About Constellation

Constellation Energy Corporation (Nasdaq: CEG), a Fortune 200 company headquartered in Baltimore, is the largest private-sector power producer in the world and the nation’s largest producer of clean and reliable energy. With 55 gigawatts of capacity from nuclear, natural gas, oil, geothermal, hydro, wind and solar facilities, our fleet has the generating capacity to power the equivalent of 27 million homes, providing about 10% of the nation’s clean energy and delivering the around-the-clock reliability needed to power America’s growing economy. We are also the largest nuclear energy company in the U.S. and a leading competitive retail supplier, serving approximately 2.5 million customer accounts nationwide, including 80% of the Fortune 100. We are committed to investing in innovation and new technologies to drive the transition to a reliable, sustainable and secure energy future. Follow Constellation on LinkedIn and X.

Non-GAAP Financial Measures

We utilize Adjusted (non-GAAP) Operating Earnings (and/or its per share equivalent) in our internal analysis, and in communications with investors and analysts, as a consistent measure for comparing our financial performance and discussing the factors and trends affecting our business. The presentation of Adjusted (non-GAAP) Operating Earnings is intended to complement and should not be considered an alternative to, nor more useful than, the presentation of GAAP Net Income (Loss).

The tables above provide a reconciliation of GAAP Net Income (Loss) to Adjusted (non-GAAP) Operating Earnings. Adjusted (non-GAAP) Operating Earnings is not a standardized financial measure and may not be comparable to other companies’ presentations of similarly titled measures.

Due to the forward-looking nature of our Adjusted (non-GAAP) Operating Earnings guidance, we are unable to reconcile this non-GAAP financial measure to GAAP Net Income (Loss) given the inherent uncertainty required in projecting gains and losses associated with the various fair value adjustments required by GAAP. These adjustments include future changes in fair value impacting the derivative instruments utilized in our current business operations, as well as the debt and equity securities held within our nuclear decommissioning trusts, which may have a material impact on our future GAAP results.

Cautionary Statements Regarding Forward-Looking Information

This press release contains certain forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995 that are subject to risks and uncertainties. Words such as “could,” “may,” “expects,” “anticipates,” “will,” “targets,” “goals,” “projects,” “intends,” “plans,” “believes,” “seeks,” “estimates,” “predicts,” and variations on such words, and similar expressions that reflect our current views with respect to future events and operational, economic, and financial performance, are intended to identify such forward-looking statements. These forward-looking statements include, but are not limited to, statements regarding the acquisition of Calpine Corporation, the pro forma combined company and its operations, strategies and plans, enhancements to investment-grade credit profile, synergies, opportunities and anticipated future performance and capital structure, and expected accretion to earnings per share and free cash flow. Information adjusted for the acquisition should not be considered a forecast of future results.

Forward-looking statements are based on current expectations, estimates and assumptions that involve a number of risks and uncertainties that could cause actual results to differ materially from those projected. The factors that could cause actual results to differ materially from the forward-looking statements made by Constellation Energy Corporation and Constellation Energy Generation, LLC, (the Registrants) include those factors discussed herein, as well as the items discussed in (1) the Registrants' 2025 Annual Report on Form 10-K in (a) Part I, ITEM 1A. Risk Factors, (b) Part II, ITEM 7. Management’s Discussion and

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Analysis of Financial Condition and Results of Operations, and (c) Part II, ITEM 8. Financial Statements and Supplementary Data: Note 18 — Commitments and Contingencies; (2) the Registrants' Second Quarter 2026 Quarterly Report on Form 10-Q (to be filed on August 6, 2026) in (a) Part II, ITEM 1A. Risk Factors, (b) Part I, ITEM 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations, and (c) Part I, ITEM 1. Financial Statements: Note 15 — Commitments and Contingencies; and (3) other factors discussed in filings with the SEC by the Registrants.

Investors are cautioned not to place undue reliance on these forward-looking statements, whether written or oral, which apply only as of the date of this press release. Neither Registrant undertakes any obligation to publicly release any revision to its forward-looking statements to reflect events or circumstances after the date of this press release.

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Table of Contents

Earnings Release Attachments

Table of Contents

Consolidated Statements of Operations

1

Consolidated Balance Sheets

2

Consolidated Statements of Cash Flows

3

GAAP Consolidated Statements of Operations and Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments

4

Statistics

6

Table of Contents

Constellation Energy Corporation and Subsidiary Companies

Consolidated Statements of Operations

(unaudited)

(in millions)

Three Months Ended June 30, 2026 Six Months Ended June 30, 2026

Operating revenues $ 7,504  $ 18,626

Operating expenses

Purchased power and fuel 4,023  10,375

Operating and maintenance 2,253  4,033

Depreciation and amortization 443  886

Taxes other than income taxes 207  436

Total operating expenses 6,926  15,730

Gain (loss) on sales of assets

2  16

Operating income (loss)

580  2,912

Other income and (deductions)

Interest expense, net (283) (536)

Other, net 603  649

Total other income and (deductions) 320  113

Income (loss) before income taxes

900  3,025

Income tax (benefit) expense

398  928

Equity in income (losses) of unconsolidated affiliates

6  14

Net income (loss)

508  2,111

Net income (loss) attributable to noncontrolling interests

(5) 8

Net income (loss) attributable to common shareholders

$ 513  $ 2,103

Three Months Ended June 30, 2025 Six Months Ended June 30, 2025

Operating revenues $ 6,101  $ 12,889

Operating expenses

Purchased power and fuel 3,132  7,516

Operating and maintenance 1,617  3,162

Depreciation and amortization 254  502

Taxes other than income taxes 147  307

Total operating expenses 5,150  11,487

Operating income (loss)

951  1,402

Other income and (deductions)

Interest expense, net (118) (264)

Other, net 440  286

Total other income and (deductions) 322  22

Income (loss) before income taxes

1,273  1,424

Income tax (benefit) expense

440  462

Net income (loss)

833  962

Net income (loss) attributable to noncontrolling interests

(6) 5

Net income (loss) attributable to common shareholders

$ 839  $ 957

Change in Net income (loss) attributable to common shareholders from 2025 to 2026 $ (326) $ 1,146

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Table of Contents

Constellation Energy Corporation and Subsidiary Companies

Consolidated Balance Sheets

(unaudited)

(in millions)

June 30, 2026 December 31, 2025

Assets

Current assets

Cash and cash equivalents $ 697  $ 3,641

Restricted cash and cash equivalents 380  107

Accounts receivable 4,661  4,266

Derivative assets

2,167  945

Inventories, net 3,368  1,736

Renewable energy credits 784  789

Assets held for sale 5,743  126

Other 1,165  509

Total current assets 18,965  12,119

Property, plant, and equipment, net 41,228  22,474

Deferred debits and other assets

Nuclear decommissioning trust funds 20,492  19,336

Goodwill 11,527  420

Derivative assets

1,741  450

Other 4,300  2,450

Total deferred debits and other assets 38,060  22,656

Total assets $ 98,253  $ 57,249

Liabilities and shareholders’ equity

Current liabilities

Short-term borrowings $ 5,226  $ 1,650

Long-term debt due within one year 363  92

Accounts payable and accrued expenses

4,432  4,294

Derivative liabilities

716  467

Renewable energy credit obligation 927  1,075

Other 1,368  366

Total current liabilities 13,032  7,944

Long-term debt 19,111  7,250

Deferred credits and other liabilities

Deferred income taxes and unamortized ITCs

8,513  3,544

Asset retirement obligations 12,612  13,193

Pension and non-pension postretirement benefit obligations

1,844  1,977

Payable related to Regulatory Agreement Units 5,914  5,334

Derivative liabilities

601  414

Other 4,304  2,740

Total deferred credits and other liabilities 33,788  27,202

Total liabilities 65,931  42,396

Commitments and contingencies

Shareholders’ equity

Common stock 26,683  11,043

Retained earnings (deficit) 7,692  5,899

Accumulated other comprehensive income (loss), net

(2,398) (2,425)

Total shareholders’ equity 31,977  14,517

Noncontrolling interests 345  336

Total equity 32,322  14,853

Total liabilities and shareholders’ equity $ 98,253  $ 57,249

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Table of Contents

Constellation Energy Corporation and Subsidiary Companies

Consolidated Statements of Cash Flows

(unaudited)

(in millions)

Six Months Ended June 30,

2026 2025

Cash flows from operating activities

Net income (loss) $ 2,111  $ 962

Adjustments to reconcile net income (loss) to net cash flows provided by (used in) operating activities

Depreciation, amortization, and accretion, including nuclear fuel and contract amortization 2,368  1,300

Deferred income taxes and amortization of ITCs 740  14

Net fair value changes related to derivatives (589) 188

Net realized and unrealized (gains) losses on NDT funds (419) (336)

Net realized and unrealized (gains) losses on equity investments 24  275

Other non-cash operating activities (240) (21)

Changes in assets and liabilities:

Accounts receivable 307  208

Inventories (63) 17

Accounts payable and accrued expenses (1,277) (229)

Option premiums received (paid), net (52) 18

Collateral received (posted), net (357) (242)

Income taxes 13  209

Pension and non-pension postretirement benefit contributions (200) (181)

Other assets and liabilities (813) (598)

Net cash flows provided by (used in) operating activities 1,553  1,584

Cash flows from investing activities

Capital expenditures (2,521) (1,573)

Proceeds from NDT fund sales 4,737  3,830

Investment in NDT funds (4,911) (3,999)

Acquisition of Calpine, net of cash and restricted cash acquired (2,537) —

Other investing activities 131  (16)

Net cash flows provided by (used in) investing activities (5,101) (1,758)

Cash flows from financing activities

Change in short-term borrowings 2,586  —

Proceeds from short-term borrowings with maturities greater than 90 days 4,500  900

Repayments of short-term borrowings with maturities greater than 90 days (3,500) —

Issuance of long-term debt 5,001  —

Retirement of long-term debt (5,352) (1,008)

Dividends paid on common stock (309) (244)

Repurchases of common stock (1,971) (400)

Other financing activities (78) (141)

Net cash flows provided by (used in) financing activities 877  (893)

Increase (decrease) in cash, restricted cash, and cash equivalents (2,671) (1,067)

Cash, restricted cash, and cash equivalents at beginning of period 3,748  3,129

Cash, restricted cash, and cash equivalents at end of period $ 1,077  $ 2,062

3

Table of Contents

Constellation Energy Corporation

GAAP Consolidated Statements of Operations and

Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments

(unaudited)

(in millions, except per share data)

Three Months Ended June 30, 2026 Three Months Ended June 30, 2025

GAAP (a)

Non-GAAP Adjustments

GAAP (a)

Non-GAAP Adjustments

Operating revenues $ 7,504  $ 525  (b),(c),(d) $ 6,101  $ (87) (b),(c)

Operating expenses

Purchased power and fuel 4,023  (114) (b),(d) 3,132  77  (b)

Operating and maintenance 2,253  (214) (c),(e),(h) 1,617  (76)

(c),(e)

Depreciation and amortization 443  (14) (c),(e) 254  (32)

(c),(g)

Taxes other than income taxes 207  (3) (e) 147  —

Total operating expenses 6,926  5,150

Gain (loss) on sales of assets

2  —  —  —

Operating income (loss)

580  951

Other income and (deductions)

Interest expense, net (283) 16  (b),(e) (118) (2) (b)

Other, net 603  (574)

(b),(c),(f)

440  (418)

(b),(c),(f)

Total other income and (deductions) 320  322

Income (loss) before income taxes 900  1,273

Income tax (benefit) expense

398  (95) (b),(c),(d),(e),(f),(h) 440  (237)

(b),(c),(e),(f),(g)

Equity in losses of unconsolidated affiliates 6  —  —  —

Net income (loss) 508  833

Net income (loss) attributable to noncontrolling interests

(5) —  (6) 1

(i)

Net income (loss) attributable to common shareholders $ 513  $ 839

Effective tax rate 44.2  % 34.6  %

Earnings per average common share

Basic $ 1.42  $ 2.67

Diluted $ 1.42  $ 2.67

Average common shares outstanding

Basic 360  314

Diluted 360  314

__________

(a)Results reported in accordance with GAAP.

(b)Adjustment for unrealized gains and losses on economic hedges, interest rate swaps, and fair value adjustments related to gas imbalances and equity investments.

(c)Adjustment for all gains and losses associated with Nuclear Decommissioning Trusts (NDT), Asset Retirement Obligation (ARO) accretion, Asset Retirement Cost (ARC) Depreciation, ARO remeasurement, and any earnings neutral impacts of contractual offset for Regulatory Agreement Units.

(d)In 2026, reflects the non-cash impacts of the amortization of certain commodity contracts at fair value associated with the Calpine acquisition.

(e)Adjustment for costs associated with the completion of the Calpine merger and subsequent integration of its operations.

(f)Adjustment for Pension and Other Postretirement Employee Benefits (OPEB) Non-Service credits.

(g)Adjustments related to plant retirements and divestitures.

(h)Adjustment for changes in legal and environmental liabilities.

(i)Adjustment for elimination of the noncontrolling interest related to certain adjustments.

4

Table of Contents

Constellation Energy Corporation

GAAP Consolidated Statements of Operations and

Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments

(unaudited)

(in millions, except per share data)

Six Months Ended June 30, 2026 Six Months Ended June 30, 2025

GAAP (a)

Non-GAAP Adjustments

GAAP (a)

Non-GAAP Adjustments

Operating revenues $ 18,626  $ (586) (b),(c),(d) $ 12,889  $ 199  (b),(c)

Operating expenses

Purchased power and fuel 10,375  (416) (b),(d) 7,516  (7) (b)

Operating and maintenance 4,033  (145) (c),(e),(i) 3,162  (154) (c),(e),(i)

Depreciation and amortization 886  (34) (c),(e) 502  (69)

(c),(g)

Taxes other than income taxes 436  (5) (e) 307  —

Total operating expenses 15,730  11,487

Gain (loss) on sales of assets

16  —  —  —

Operating income (loss)

2,912  1,402

Other income and (deductions)

Interest expense, net (536) 32  (b),(e) (264) 32

(b)

Other, net 649  (580)

(b),(c),(f)

286  (231) (b),(c),(f)

Total other income and (deductions) 113  22

Income (loss) before income taxes 3,025  1,424

Income tax (benefit) expense

928  (327) (b),(c),(d),(e),(f),(h),(i) 462  (88) (b),(c),(e),(f),(g)

Equity in income (losses) of unconsolidated affiliates

14  —  —  —

Net income (loss) 2,111  962

Net income (loss) attributable to noncontrolling interests

8  3

(j)

5  3  (j)

Net income (loss) attributable to common shareholders $ 2,103  $ 957

Effective tax rate 30.7  % 32.4  %

Earnings per average common share

Basic $ 5.89  $ 3.05

Diluted $ 5.88  $ 3.05

Average common shares outstanding

Basic 357  314

Diluted 357  314

__________

(a)Results reported in accordance with GAAP.

(b)Adjustment for unrealized gains and losses on economic hedges interest rate swaps, and fair value adjustments related to gas imbalances and equity investments.

(c)Adjustment for all gains and losses associated with NDTs, ARO accretion, ARC Depreciation, ARO remeasurement, and any earnings neutral impacts of contractual offset for Regulatory Agreement Units.

(d)In 2026, reflects the non-cash impacts of the amortization of certain commodity contracts at fair value associated with the Calpine acquisition.

(e)Adjustment for costs associated with the completion of the Calpine merger and subsequent integration of its operations.

(f)Adjustment for Pension and OPEB Non-Service credits.

(g)Adjustments related to plant retirements and divestitures.

(h)Adjustment to deferred income taxes due to changes in forecasted apportionment.

(i)Adjustment for changes in legal and environmental liabilities.

(j)Adjustment for elimination of the noncontrolling interest related to certain adjustments.

5

Table of Contents

Statistics

Three Months Ended June 30, Six Months Ended June 30,

(GWhs)

2026 2025 2026 2025

Nuclear Generation(a)

Mid-Atlantic 12,676  12,263  26,002  25,440

Midwest 23,112  23,760  46,086  47,356

New York 6,336  6,632  12,351  12,913

ERCOT 2,036  2,515  4,388  5,044

Total Nuclear Generation 44,160  45,170  88,827  90,753

Natural Gas, Oil, and Renewables(a)

Mid-Atlantic 611  810  1,351  1,442

Midwest 273  258  617  643

ERCOT

3,742  3,206  6,480  6,290

Other Power Regions

1,109  1,286  2,852  3,090

Calpine

24,914  —  51,411  —

Total Natural Gas, Oil, and Renewables 30,649  5,560  62,711  11,465

Purchased Power

Mid-Atlantic 3,063  3,750  7,157  8,544

Midwest 394  475  811  963

ERCOT 640  837  1,326  1,495

Other Power Regions

8,181  9,849  17,496  20,844

Calpine

2,728  —  4,817  —

Total Purchased Power 15,006  14,911  31,607  31,846

Total Supply/Sales by Region

Mid-Atlantic 16,350  16,823  34,510  35,426

Midwest 23,779  24,493  47,514  48,962

New York 6,336  6,632  12,351  12,913

ERCOT

6,418  6,558  12,194  12,829

Other Power Regions

9,290  11,135  20,348  23,934

Calpine

27,642  —  56,228  —

Total Supply/Sales by Region 89,815  65,641  183,145  134,064

Three Months Ended June 30, Six Months Ended June 30,

2026 2025 2026 2025

Outage Days(b)

Refueling 86  41  185  129

Non-refueling 20  22  20  22

Total Outage Days 106  63  205  151

__________

(a)Includes the proportionate share of output where we have an undivided ownership interest in jointly-owned generating plants.

(b)Outage days exclude Salem and STP.

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Table of Contents

Electricity Reference Prices(a)

Three Months Ended June 30, Six Months Ended June 30,

ISO/RTO

2026 2025 2026 2025

PJM - PJM West $ 51.40  $ 42.43  $ 74.28  $ 48.06

PJM - ComEd 29.32  31.09  40.01  33.20

NYISO - Central 40.51  37.40  76.37  56.36

ERCOT - North 29.58  32.75  35.12  32.07

ERCOT - Houston 32.62  36.95  35.59  34.34

ISO-NE - Southeast Massachusetts 48.18  40.31  83.50  72.53

CAISO - NP15

17.28  26.62  23.14  33.79

Capacity Reference Prices

Three Months Ended June 30, Six Months Ended June 30,

ISO/RTO 2026 2025 2026 2025

PJM - Eastern Mid-Atlantic Area Council $ 289.67  $ 125.71  $ 279.80  $ 89.65

PJM - ComEd 289.67  109.25  279.80  69.09

NYISO - Rest of State 195.67  132.89  154.00  109.61

ISO-NE - Rest of Pool(b)

84.99  83.17  84.68  82.87

ZEC Reference Prices(a)

Three Months Ended June 30, Six Months Ended June 30,

State (Segment)

2026 2025 2026 2025

New Jersey (Mid-Atlantic)(c)(d)

$ —  $ 10.00  $ —  $ 10.00

Illinois (Midwest) 1.12  6.64  1.15  8.01

New York (New York)(c)

14.76  14.76  14.76  16.52

Natural Gas Prices(a)

Three Months Ended June 30, Six Months Ended June 30,

Location

2026 2025 2026 2025

Henry Hub $ 2.93  $ 3.16  $ 3.91  $ 3.71

Transco Zone 6(e)

2.13  2.40  5.78  4.22

Houston Ship Channel(f)

2.45  2.74  2.85  3.10

PG&E Citygate(g)

1.55  2.81  1.81  3.26

Algonquin Citygate(h)

2.37  2.86  8.19  7.32

__________

(a)Reference prices may not necessarily reflect prices we ultimately realized.

(b)We did not have significant activity at this zone for the three months ended June 30, 2025.

(c)The NY and NJ state-sponsored programs providing compensation for the emissions-free attributes of generation from certain of our nuclear units include contractual provisions that require us to refund that compensation up to the amount of the nuclear PTC received.

(d)The New Jersey ZEC program concluded in May 2025.

(e)Transcontinental Gas pipeline located in Mid-Atlantic region.

(f)Houston-area pipeline and industrial network located in ERCOT region.

(g)Pacific Gas & Electric Company virtual trading point located in West region.

(h)Algonquin Gas Transmission physical delivery point located in New England region.

7

EX-99.2

EX-99.2

Filename: ceg-20260806992.htm · Sequence: 3

ceg-20260806992

Earnings Conference Call Second Quarter 2026 August 6, 2026

This presentation contains certain forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995 that are subject to risks and uncertainties. Words such as “could,” “may,” “expects,” “anticipates,” “will,” “targets,” “goals,” “projects,” “intends,” “plans,” “believes,” “seeks,” “estimates,” “predicts,” and variations on such words, and similar expressions that reflect our current views with respect to future events and operational, economic, and financial performance, are intended to identify such forward-looking statements. These forward-looking statements include, but are not limited to, statements regarding the acquisition of Calpine Corporation, the pro forma combined company and its operations, strategies and plans, enhancements to investment-grade credit profile, synergies, opportunities and anticipated future performance and capital structure, and expected accretion to earnings per share and free cash flow. Information adjusted for the acquisition should not be considered a forecast of future results. Forward-looking statements are based on current expectations, estimates and assumptions that involve a number of risks and uncertainties that could cause actual results to differ materially from those projected. The factors that could cause actual results to differ materially from the forward-looking statements made by Constellation Energy Corporation and Constellation Energy Generation, LLC, (the Registrants) include those factors discussed herein, as well as the items discussed in (1) the Registrants’ 2025 Annual Report on Form 10-K in (a) Part I, ITEM 1A. Risk Factors, (b) Part II, ITEM 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations, and (c) Part II, ITEM 8. Financial Statements and Supplementary Data: Note 18 — Commitments and Contingencies; (2) the Registrants’ Second Quarter 2026 Quarterly Report on Form 10-Q (to be filed on August 6, 2026) in (a) Part II, ITEM 1A. Risk Factors, (b) Part I, ITEM 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations, and (c) Part I, ITEM 1. Financial Statements: Note 15 — Commitments and Contingencies; and (3) other factors discussed in filings with the SEC by the Registrants. Investors are cautioned not to place undue reliance on these forward-looking statements, whether written or oral, which apply only as of the date of this presentation. Neither Registrant undertakes any obligation to publicly release any revision to its forward-looking statements to reflect events or circumstances after the date of this presentation. Cautionary Statements Regarding Forward-Looking Information 2

The Registrants report their financial results in accordance with accounting principles generally accepted in the United States (GAAP). Constellation supplements the reporting of financial information determined in accordance with GAAP with certain non-GAAP financial measures, including: • Adjusted Operating Earnings (and/or its per share equivalent) exclude certain costs, expenses, gains and losses and other specified items, including adjustments for unrealized gains or losses on economic hedges, interest rate swaps, and fair value adjustments related to gas imbalances and equity investments, decommissioning related activity, asset impairments, certain amounts associated with plant retirements and divestitures, pension and other post-employment benefits (OPEB) non-service credits, and other items as set forth in the Appendix • Free cash flows before growth (FCFbG) is cash flows from operations less capital expenditures under GAAP for maintenance and nuclear fuel, equity investments, and adjusted for changes in collateral and non-recurring costs-to-achieve (CTA) • Adjusted gross margin is defined as adjusted operating revenues less adjusted purchased power and fuel expense, excluding revenue related to decommissioning, gross receipts tax, variable interest entities, and net of direct cost of sales for certain end-user businesses – Adjusted operating revenues excludes the unrealized gains or losses on economic hedging activities due to the volatility and unpredictability of the future changes in commodity prices – Adjusted purchased power and fuel excludes the unrealized gains or losses on economic hedging activities and fair value adjustments related to gas imbalances due to the volatility and unpredictability of the future changes in commodity prices • Adjusted operating and maintenance (O&M) excludes direct cost of sales for certain end-user businesses, Asset Retirement Obligation (ARO) accretion expense from unregulated units and decommissioning costs that do not affect profit and loss, the impact from operating and maintenance expense related to variable interest entities at Constellation, and other items as set forth in the reconciliation in the Appendix Due to the forward-looking nature of our Adjusted Operating Earnings guidance, Projected Adjusted Gross Margin, and Projected Free Cash Flow Before Growth, we are unable to reconcile these non-GAAP financial measures to the comparable GAAP measures given the inherent uncertainty required in projecting gains and losses associated with the various fair value adjustments required by GAAP. These adjustments include future changes in fair value impacting the derivative instruments utilized in our current business operations, as well as the debt and equity securities held within our nuclear decommissioning trusts, which may have a material impact on our future GAAP results. Non-GAAP Financial Measures 3

This information is intended to enhance an investor’s overall understanding of period over period financial results and provide an indication of Constellation’s operating performance by excluding items that are considered by management to be not directly related to the ongoing operations of the business. In addition, this information is among the primary indicators management uses as a basis for evaluating performance, allocating resources, setting incentive compensation targets and planning and forecasting of future periods. These non-GAAP financial measures are not a presentation defined under GAAP and may not be comparable to other companies’ presentations of similarly titled financial measures. Constellation has provided these non-GAAP financial measures as supplemental information and in addition to the financial measures that are calculated and presented in accordance with GAAP. These non-GAAP measures should not be deemed more useful than, a substitute for, or an alternative to the most comparable GAAP measures provided in the materials presented. Non-GAAP financial measures are identified by the phrase “non-GAAP” or an asterisk (*). Reconciliations of these non-GAAP measures to the most comparable GAAP measures are provided in the appendices and attachments to this presentation. Non-GAAP Financial Measures Continued 4

Key Highlights 5 License renewals filed for Ginna and Nine Mile Point Clean Energy Centers Great Place To Work® Certified , DisabilityIN World’s Top Disability Inclusive Business recognition, and Civic 50® honoree Q2 GAAP earnings of $1.42 per share (1) Q2 Adjusted Operating Earnings* of $2.55 per share (1) Raising full-year Adjusted Operating Earnings* guidance range to $11.50 - $12.50 per share (1) Signed ~920 MWs of long-term nuclear PPAs Note: GAAP to Non-GAAP reconciliations for Adjusted Operating Earnings* can be found on page 30 of the Appendix (1) Q2 2026 earnings per share is based on average diluted common shares outstanding of 360 million and revised full-year 2026 earnings guidance is based on expected average diluted common shares outstanding of 357 million Nine Mile Point Clean Energy Center ~$2.2B deployed YTD for accretive share repurchases Key FERC and NRC approvals received for Crane Clean Energy Center On path to regulatory clarity in PJM in 2H 2026 Brazos Valley Energy Center sale will satisfy final DOJ condition of Calpine acquisition

Secured ~920 MWs of New Long-Term Premium Nuclear Contracts (1) ~30% of Expected Baseload Clean Generation MWhs under Long-Term Agreement by 2032 (1) 6 Average contract duration of 18.5 years 890 MWs of existing generation Diverse, investment grade customers Dresden Clean Energy Center Customer commitment enables 30 MW uprate at Dresden Clean Energy Center Contracts begin 2029-2031 and are fully ramped by 2032 (1) Includes long-term agreement for 176 MWs announced on June 23, 2026 (2) Baseload clean generation includes nuclear and geothermal. Long-term agreements include contracted generation and New York ZEC.

FERC is committed to quickly resolving remaining uncertainty across regional grids FERC is focused on a transparent framework for connecting large load efficiently PJM’s proposed rules for Reliability Backstop Procurement (RBP) and Interim Resource Adequacy Service (IRAS), formerly Connect and Manage Existing generation will provide speed to power with load interconnection reforms Regulatory Progress is Improving Clarity for Large Load Customers 7 Clarity to Come By Year’s EndClarity Already Achieved Bilateral matching is ongoing and will reduce capacity procured through the RBP FERC to rule on PJM’s request to run the RBP this fall for remaining capacity needs with results known by year-end PJM will file revised tariffs for new transmission services and interconnection of large loads FERC to rule on IRAS curtailment proposal, which should resolve an area of uncertainty among stakeholders PJM Cycle 1 interconnection studies will increase visibility into the timing of new generation supply

• Partnering with customers to drive new investment • Additional investment amplifies benefit of existing Clean Energy Centers • Supports relicensing that can preserve community benefits for decades Crane Clean Energy Restart Provides Model for Responsible Economic Development 8 70% of Pennsylvanians Support the Crane Restart (1) Tax Generation Job Creation Philanthropy $3.6B in state and federal tax revenue adds $16B to PA GDP (2,3) ~3,400 in-state direct and indirect jobs created (2) Supporting Local Businesses $373M+ of contracts and purchase orders sourced from PA based companies $425K in annual charitable giving to support local education, workforce development, and community needs Fleet Positioned to Add ~1,100 MWs of Uprates (4) (1) Polling conducted by Susquehanna Polling & Research (2) Murphy, D., Berkman, M., & Chang, W. (2024, September 20). Economic impacts of establishing the Crane Clean Energy Center (CCEC). The Brattle Group. (3) Impacts from 20 years of operations (4) Includes previously announced uprates and 900 MWs of uprates possible with customer support * Left picture: Crane fundraiser to raise money for the Londonderry Township Volunteer Fire Department; right picture: Constellation donated to the Lower Dauphin Communities That Care Bookmobile

(1) Q2 2025 earnings per share is based on average diluted common shares outstanding of 314 million (2) Q2 2026 earnings per share is based on average diluted common shares outstanding of 360 million Q2 2026 Results 9 Year-over-Year Adj. Operating Earnings* Drivers $2.67 $1.42 $1.91 $2.55 GAAP Net Income Q2 2025 (1) GAAP Net Income Q2 2026 (2) Adjusted Operating Earnings* Q2 2025 (1) Adjusted Operating Earnings* Q2 2026 (2) • Contribution from Calpine • Higher capacity revenue • Strong commercial performance through portfolio optimization and higher realized customer margins • Lower revenue recognition from banked IL ZECs • Higher number of planned nuclear refueling outage days Note: GAAP to Non-GAAP reconciliations for Adjusted Operating Earnings* can be found on page 30 of the Appendix $/share

Best-in-Class Nuclear Operations in a High Planned Refueling Outage Year 10 75% 80% 85% 90% 95% 100% 30 35 40 45 T W h s C ap acity F acto r Q2 24 Q3 24 Q4 24 Q1 25 Q2 25 Q3 25 Q4 25 Q1 26 Q2 26 TWhs Capacity Factor Nuclear Refueling Outages Completed Faster than Industry Average Even with Uprate 2026 Quarterly Capacity Factors Represent Execution of Planned Refueling Outages (1,2) Included successful implementation of the turbine uprate at Byron Clean Energy Center’s Unit 1 Beat industry average of 38 days by 40% (3) (1) Salem and STP are not included in operational metrics (outage days, capacity factor and generation) (2) Capacity factors reflect net monthly mean methodology. Capacity factors for periods in prior years may not tie to previous earnings presentations due to change in methodology for comparison purposes, however full-year reported capacity factors are not impacted. (3) 2025 industry average refueling outage was 38 days based on CEG annual industry benchmarking • Two fewer unplanned outage days in Q2 compared to prior year • Additional planned outage days reduced Q2 capacity factor by ~1.8% vs. Q2 2025 Q2 average nuclear refueling outage duration: 23 days

(1) Initial full-year 2026 earnings guidance was based on expected average diluted common shares outstanding of 361 million (2) Revised full-year 2026 earnings guidance is based on expected diluted common shares outstanding of 357 million Raising Full-Year Adjusted Operating Earnings* Guidance Range to $11.50 - $12.50 Per Share 11 • Commercial business outperforming plan in a dynamic market – Higher realized customer margins – Successful portfolio optimization • Accretive deployment of capital through share repurchases • Partially offset by higher O&M due to performance related compensation expenses $/share Initial Guidance (1) Revised Guidance (2) $12.00 $12.50 $11.00 $11.50 $11.50 $12.00

Constellation’s BBB+/Baa1 Balance Sheet is a Competitive Advantage Current Credit Ratings (1)Returning Capital to Shareholders through Share Repurchases 12 On-Track to Satisfy all DOJ Divestitures Requirements (1) Reflects senior unsecured rating for Constellation Energy Generation, LLC and Calpine LLC, respectively. Ratings shown have Stable outlook. Share Repurchase Allocation YTD ~$2.2B Remaining Authorization Cumulatively, we have deployed ~$4.6B to repurchase ~25.5 million shares since separation ~$2.8B CalpineConstellation Baa1Baa1Moody’s BBB+BBB+S&P BBBN/RFitch Brazos Valley Energy Center sold for $860M, ~$1,419/kW, pending regulatory approval $5.9B in total gross proceeds for required divestitures reflects premium to $960/kW implied purchase price

Opportunities Create Meaningful Upside to Adj. EPS* and Free Cashflow before Growth* in 2029 (1) 13 Earnings and FCFbG Opportunities in 2029Additional Optionality for 2029 Adj. EPS (1) Opportunities may not be additive (2) Illustrative (3) Excludes after-tax proceeds from asset sales (4) Assumes 1% - 2% change in capacity factor calculated at $20 average base spark spread 30% - 35% $11.40 – $11.90 Enhanced Base 2029 2029 (2) $11.5 - $13.0B of FCFbG in 2028 - 2029 with Additional Upside 2026 – 2027 (3) 2028 - 2029 2028 – 2029 (2) $8.4B $11.5 - $13.0B FCFbG Upside Earnings Upside Description Enhanced Opportunity $150M - $450M $0.45 - $1.35 $1 - $3 power price and spark spread increase Power Prices and Spark Spreads FCFbG Upside Earnings Upside Description Base Opportunity $125M - $325M $0.40 - $1.00 $20-$50/MWh premium to PTC floor 1 GW Nuclear PPA $75M - $175M $0.20 - $0.50 $10-$25/MWh premium for long-term agreement 1 GW Natural Gas Powered Land $25M - $75M$0.10 - $0.20 1% - 2% increased utilization driven by higher spark spreads (4) Natural Gas Capacity Factor $50M - $100M $0.10 - $0.30 $0.25 - $0.50 increase to average margins Commercial Margin $100M$0.30 PTC inflation at 3% vs 2% Increase to PTC Floor Specific to Investment $0.20 - $0.75+ Growth investments, share repurchases, etc. Capital Allocation

Positioned for Growth and Powering American Prosperity 14 Strong 20%+ Growth through 2029 • Base EPS* growth of 20%+ from 2026-2029 • Growth outlook excludes potential upside from: – Capturing premium value for 147 million MWhs of annual and available nuclear generation in 2029 – Securing additional natural gas contracts – Accretive capital allocation • Targeting long-term rolling three-year Base EPS* growth of 10%+ Assets that Cannot be Replicated • Largest fleets of nuclear, natural gas and geothermal generation in the U.S. • Coast-to-coast fleet to support economic growth, electric system reliability and national security • New build cost of our ~55 GW fleet would be more than 3x our current enterprise value Driving Value through Capital Allocation • Strong investment grade balance sheet and growing free cash flow* enables our value-enhancing capital allocation framework: – Share buyback authorization of $5.0B underscoring confidence in our outlook and executing on our future optionality – $3.9B of growth capital in projects at compelling returns – Scale that positions us to potentially bring natural gas, storage capacity and new nuclear uprates to the grid in the near term

Additional Disclosures 15

20 25 30 35 40 45 50 55 60 20 25 30 35 40 45 50 55 60 Market Revenues ($/MWh) M ar ke t R ev en u es + P T C ( $ / M W h ) 16 PTC Provides Support for Nuclear Units When Revenues Fall Below $44.75/MWh (1) Illustrative Payoff Dynamics for Non-State-Supported Units in 2026 • The PTC provides support of up to $15.00/MWh for units when revenues are between $26.00/MWh and $44.75/MWh while preserving the ability of the unit to participate in upside from commodity markets • The green line assumes revenues of $47.00/MWh. Since it is above the $44.75/MWh PTC phase out, units would not receive PTC value. • When revenues fall below the $44.75/MWh phase out, the PTC will provide revenue support for the units, bringing effective realized revenues back to $44.75/MWh • Assuming revenues of $35.00/MWh, the orange line, we would expect units to receive $7.80/MWh PTC, bringing the total value the unit would receive to $42.80/MWh and $45.40/MWh (2) on a tax adjusted basis Competitive Unit Payoff $35/MWh $47/MWh PTC provides support from $26/MWh - $44.75/MWh (1) See H.R. 5376 for additional details; all numbers assume that prevailing wage requirements are satisfied (2) Grossed up assuming 25% tax rate

• In 2026, the maximum PTC and gross receipts threshold are subject to an inflation adjustment based on the GDP price deflator for the preceding calendar year: • Maximum PTC is rounded to nearest $2.50/MWh and gross receipts threshold is rounded to nearest $1.00/MWh Inflation of Nuclear Production Tax Credit (1) 17 (1) See H.R. 537 for additional details; all numbers assume that prevailing wage requirements are satisfied (2) Annual inflation adjustment is consistent with past published guidance for renewable energy credits, published annually. Assumes noted inflation adjustment carries through 2026-2032. (3) March PTC Outlook as included in the 2026 Business and Earnings Outlook preceding publication of 2025 inflation adjustments (4) August 2026 PTC Outlook reflects published inflation adjustment for 2025 of 2.8% (5) Assumes expected average shares outstanding of 357 million and effective tax rate of 26% across all years PTC Inflation AdjustmentPTC Overview Inflation Adjustment= GDP price deflator in preceeding year GDP price deflator in 2024 • The PTC is in effect through 12/31/32 • In 2025, Constellation qualified for the nuclear PTC up to $15.00/MWh; the PTC amount is reduced by 80% of gross receipts exceeding $26.00/MWh, phasing out completely after $44.75/MWh • The nuclear PTC can be credited against taxes or monetized through sale to an unrelated taxpayer Example Inflation Adjustments (2) Maximum PTC Price Threshold Price At Which PTC=$0 Maximum PTC Price Threshold Price At Which PTC=$0 Maximum PTC Price Threshold Price At Which PTC=$0 Maximum PTC Price Threshold Price At Which PTC=$0 2.0% 2.5% 3.0% 2026 15.00$ 26.00$ 44.75$ 15.00$ 26.00$ 44.75$ 15.00$ 26.00$ 44.75$ 15.00$ 26.00$ 44.75$ -$ -$ -$ 2027 15.00$ 27.00$ 45.75$ 15.00$ 27.00$ 45.75$ 15.00$ 27.00$ 45.75$ 17.50$ 27.00$ 48.88$ -$ -$ 0.85$ 2028 17.50$ 27.00$ 48.88$ 17.50$ 27.00$ 48.88$ 17.50$ 28.00$ 49.88$ 17.50$ 28.00$ 49.88$ -$ 0.30$ 0.30$ 2029 17.50$ 28.00$ 49.88$ 17.50$ 28.00$ 49.88$ 17.50$ 28.00$ 49.88$ 17.50$ 29.00$ 50.88$ -$ -$ 0.30$ 2030 17.50$ 29.00$ 49.88$ 17.50$ 29.00$ 50.88$ 17.50$ 29.00$ 50.88$ 17.50$ 30.00$ 51.88$ 0.30$ 0.30$ 0.60$ 2031 17.50$ 29.00$ 50.88$ 17.50$ 29.00$ 50.88$ 17.50$ 30.00$ 51.88$ 17.50$ 31.00$ 52.88$ -$ 0.30$ 0.60$ 2032 17.50$ 29.00$ 50.88$ 17.50$ 30.00$ 51.88$ 17.50$ 31.00$ 52.88$ 20.00$ 31.00$ 56.00$ 0.30$ 0.60$ 1.55$ Base EPS (5) Impacts vs. March PTC Outlook August 2026 PTC Outlook (4) Revised Inflation Adjustments (4) 2.0% 3.0% March 2026 PTC Outlook (3) 2.0% 2.5%

18 $600 $900 $334 2 0 2 8 $1,397 $79 2 0 2 6 2 0 3 0 $2,393 $105 2 0 3 1 $600 2 0 3 2 2 0 2 9 2 0 3 3 $500 2 0 3 4 2 0 3 5 $850 2 0 3 6 2 0 3 7 2 0 3 8 $900 2 0 3 9 2 0 4 0 $350 2 0 4 1 $788 2 0 4 2 2 0 4 3 2 0 4 4 2 0 4 5 2 0 4 6 2 0 4 7 2 0 4 8 2 0 4 9 2 0 5 0 2 0 5 1 2 0 5 2 2 0 2 7 2 0 5 3 $900 $1,950 2 0 5 5 2 0 5 6 2 0 5 7 2 0 5 8 2 0 5 9 2 0 6 0 2 0 5 4 2 0 6 2 2 0 6 3 2 0 6 4 2 0 6 5 $800 2 0 6 6 2 0 6 1 CEG Sr. Notes CEG Tax-Exempt Bonds (3) CPN Sr. Notes (4) As of 6/30/2026 Long-Term Debt Maturity Profile (1) Long-Term Debt Balances ($B) (2) TotalCPNCEG $13.4$0.1$13.3Corporate Long-Term Debt $6.1$4.9$1.2Subsidiary Debt $19.6$5.0$14.6Total Long-Term Debt ($M) Note: Items may not sum due to rounding (1) Maturity profile excludes subsidiary debt, corporate term loans, P-cap facility, securitized debt, energy efficiency project financing, capital leases, unamortized debt issuance costs and unamortized discount/premium (2) Long-term debt balances reflect financials as of 6/30/26. Balances include instruments reflected in the maturity profile, as well as subsidiary debt and energy efficiency project financings. (3) Maturity profile reflects mandatory purchase dates for tax-exempt notes (4) Remaining “stub” balance relates to the 3.75% Calpine senior notes following the obligor exchange completed in January and is expected to remain at Calpine given the attractive coupon Corporate Long-Term Debt

• The Zero Emission Standard, passed in December 2016, requires the Illinois Power Agency (IPA) to procure contracts with zero emission facilities for ZECs • The program has a 10-year duration that commenced with the 2017/2018 planning year and runs through May 2027 • The IPA calculates the ZEC price for each planning year based on the Social Cost of Carbon and a market price index relative to a baseline market price index – The social cost of carbon was set at $16.50/MWh for the first six years of the program and then increases at $1/MWh per year beginning in the 2023/2024 planning period – The market price index resets each year (1), while the baseline reference price was set at $31.40 • Total compensation is limited by an annual cap designed to limit the cost of ZECs to each utility’s customers – There is a “banking” mechanism, where, for ZECs delivered that exceed the annual cap each year they may be paid in subsequent years if the payments would not exceed the annual cap in the year paid – For the first six planning years, the cost of delivered ZECs exceeded the annual compensation cap. • For the June 1, 2026 to May 31, 2027 planning year the ZEC price has been established at $1.02 per ZEC, subject to an annual cap of $228 million. ZECs generated and delivered during this planning year will not exceed the annual cap, providing available funds to compensate for ZECs delivered but not paid in prior planning years. Illinois Zero Emission Credit (ZEC) Overview Social Cost of Carbon Amount that market price index exceeds the reference price of $31.40/MWh ZEC Price (1) Based on the energy forward prices for each month of the applicable delivery year averaged for each trade date during the preceding calendar year19 ZEC Price ($/MWh)Planning Year $16.502017/2018 $16.502018/2019 $16.502019/2020 $16.502020/2021 $16.502021/2022 $12.012022/2023 $0.302023/2024 $9.382024/2025 $1.172025/2026 $1.022026/2027

Modeling Slides 20

Base Earnings Give Visibility into Constellation’s Stability and Growth 21 Enhanced Earnings (30-40% of Total) Base Earnings (60-70% of Total) Earnings that reflect additional value above base earnings Earnings that are consistent, visible and easy to calculate that will grow over time through long- term contracting, returns on contracted organic growth, PTC inflation adjustment and share repurchases • Forward power prices above base assumptions • Commercial margins above 10-year average • Capturing outsized value from volatility • Long-term contracts on generation fleet • Available nuclear generation at PTC floor (assuming 2% inflation) • Minimum expected earnings for fossil generation anchored by historical results • 10-year historical and forward weighted average commercial margins and volume

~20% Adjusted Operating Earnings* Growth on 2026 Base Earnings through 2029 (1) 22 $6.65 - $6.75 ~40% of Total 2026 $7.60 - $7.70 35% - 40% of Total 2027 $11.40 - $11.90 30% - 35% of Total 2029 Original Guidance Range $11.00 - $12.00 (1) EPS guidance as shown in the 2026 Business and Earnings Outlook presentation (2) Forward looking market prices as of 12/31/2025 2029 Projection Includes: 2029 Projection Does Not Include: • Incremental long-term deals • Higher gas plant utilization • Expanding Commercial margins • Higher return growth investments • Announced nuclear and gas long-term offtakes • Nuclear PTC at 2% inflation • Average Commercial margins • Current expectations (2) for forward looking market prices Enhanced Base

Base Gross Margin Modeling Tool Definitions 23 DetailsBase Gross Margin • Carbon-free contracted generation for more than 5 years • Includes nuclear, solar, wind, storage and geothermal • Contracts that include energy, capacity, attributes, infrastructure and/or state program revenue Contracted Clean • CMC units • Remaining units (PTC) Available Nuclear • Contracted fossil/other generation for more than 5 years • Non-contracted fossil/other volume and spark spreads Natural Gas and Oil • Carbon-free generation contracted for less than 5 years and merchant carbon-free generation Wind/Solar/Hydro • Cleared and bilaterally sold capacity volumes with minimum expected priceNon-Nuclear Capacity • Average historical/forward 10-year unit margin and forecasted volume • Other non-commodity customer margin • Other commercial margins (~$475M/yr) Commercial Margin

Constellation Modeling Tools for Base Earnings 24 Note: Revised 2026 earnings guidance based on expected average shares outstanding of 357 million. 2027 assumes average shares outstanding are held flat and is not reflective of capital allocation plans. (1) Reflected at ownership share; includes Salem and STP (2) Reflects calendar year price based on weighted average CMC price for 2024/2025, 2025/2026, and 2026/2027 planning years (3) To the extent we receive nuclear PTCs, the value will be reflected in revenues on the GAAP financial statements (4) Includes NY ZEC which reflects the total of energy, capacity, and ZEC consistent with the rate-setting mechanism (5) 2026 disclosures include earnings contribution from assets to be divested in 2H 2026 20272026 PricesQuantityPricesQuantityAdjusted Gross Margin* (Base Only) (1) Available Nuclear $34.50 /MWh23 million MWhs$34.09 /MWh53 million MWhsIllinois CMC Units (2) $45.75 /MWh127 million MWhs$44.75 /MWh101 million MWhsRemaining Units – PTC w/ 2% Inflation (3) $70.00 /MWh45 million MWhs$70.00 /MWh36 million MWhsContracted Clean (4) Natural Gas/Other Energy (5) $22 spark spread68 million MWhs$21 spark spread71 million MWhsERCOT $25 spark spread25 million MWhs$25 spark spread25 million MWhsWest $16 spark spread26 million MWhs$15 spark spread31 million MWhsOther $50.00 /MWh4 million MWhs$50.00 /MWh4 million MWhsWind/Solar/Hydro Non-Nuclear Capacity (5) $165 /MWd5,400 MWs$165 /MWd5,400 MWsWest (RA) $200 /MWd3,000 MWs$200 /MWd4,600 MWsMid-Atlantic/Midwest $85 /MWd2,500 MWs$85 /MWd2,500 MWsNew England Average MarginProjected VolumesAverage MarginProjected VolumesCommercial $4.25 - $4.35 /MWh245 million MWhs$4.25 - $4.35 /MWh245 million MWhsPower Margins $0.40 - $0.45 /dth850 million dth$0.40 - $0.45 /dth835 million dthGas Margins ~$175M~$150MNon-Commodity Customer Margin ~$475M~$475MOther Commercial Margin ($6.45 - $6.50) /MWh184 million MWhs($5.75 - $5.80) /MWh179 million MWhsNuclear Fuel Amortization 2026 2027

Constellation Additional Modeling Inputs and Information 25 (1) 2026 disclosures include earnings contribution from assets to be divested in 2H 2026 (2) Adjusted O&M* excludes impact from performance O&M associated with higher enhanced earnings. Total adjusted O&M* is $7,025 million and $7,075 million for 2026 and 2027, respectively. (3) TOTI excludes gross receipts tax (4) Base interest expense excludes portion of interest attributable to re-levering following Calpine acquisition and is not reflective of capital allocation. Includes interest income from cash on hand. (5) Reflects effective tax rate including/ excluding impact of forecasted PTC revenues as of 12/31/2025. To the extent we receive nuclear PTCs, the value will be reflected in revenues on the GAAP financial statements. (6) Reflects additional O&M for compensation expense related to overperformance 20272026 (1) Other Base Modeling Inputs ($7,025)($6,900)Adjusted O&M* (Excl. Performance Incentive Adj.) (2) ($675)($675)TOTI (3) --Other, Net ($2,000)($1,825)Depreciation and Amortization ($700)Base Interest Expense, Net (4) 25% / 26%26% / 26%Effective Tax Rate including / excluding PTC (5) Enhanced Modeling Tools $2,150 – $2,550$2,825 - $3,025Adjusted Gross Margin* (Enhanced Only) ($50)($125) Performance Incentive Adjustment (Applied Against Enhanced Earnings) (6) ($250)Enhanced Interest Expense, Net Additional Information For Enhanced Tools as of 6/30/2026 --Power Margins Above Average 5%5%Percentage of Nuclear Fleet in PTC Zone Reference Prices as of 6/30/2026 $40.68$42.66NIHub ATC ($/MWh) $66.94$72.75PJM – W ATC ($/MWh) $59.26$63.21New York Zone A ATC ($/MWh) $21.85$16.16ERCOT – N ATC Spark Spread ($/MWh) $24.62$18.23ERCOT – N Peak Spark Spread ($/MWh) Note: Revised 2026 earnings guidance based on expected average shares outstanding of 357 million. 2027 assumes average shares outstanding are held flat and is not reflective of capital allocation plans.

Detailed Modeling Inputs for Base Earnings 26 (1) Reflects calendar year price based on weighted average CMC prices across planning years (2) PTC with 2% inflation reflects published inflation adjustment for 2025 of 2.8% (3) Values include NY ZEC which is total of energy, capacity and ZEC consistent with rate-setting mechanism. Contracted clean volumes and prices updated annually and do not include PPAs signed in 2026. (4) Includes Salem and STP Detailed Base Earnings Modeling Inputs Available Nuclear 2026 2027 2028 2029 2030 Illinois CMC million MWhs 53 23 Illinois CMC $/MWhs (1) $34.09 $34.50 Remaining Units million MWhs 101 127 148 146 147 Remaining Units - PTC w/2% Inflation $/MWh (2) $44.75 $45.75 $48.88 $49.88 $50.88 Contracted Clean (3) Contracted Clean million MWhs 36 45 53 54 53 Contracted Clean $/MWhs $70.00 $70.00 $77.00 $85.00 $88.00 Total Nuclear Volumes (million MWhs) 179 184 190 188 189 Number of Planned Refueling Outages (4) 15 15 13 15 14

Constellation Cleared/Committed Capacity Detail (1) 27 (1) Volumes are rounded and reflect Constellation’s ownership share of partially owned units. See 2028/2029 PJM Capacity Auction results on slide 28. (2) Revenues above the CMC value are returned to customers (3) Capacity revenue for nuclear units are included in the gross receipts calculation for the PTC and therefore should not be incorporated separately into Base Earnings calculations (4) Assets to be divested in 2026 are reflected in planning years 2025/2026 and 2026/2027 (5) Other PJM includes ~400 MWs committed in bilateral agreement that will be available for future capacity auctions (6) Base earnings for fossil/other capacity assumes a clearing price of $200/MWd (7) NEMA: Northeastern Massachusetts and Boston; SEMA: Southeastern Massachusetts (8) Net Qualifying Capacity excludes batteries and storage and includes ~700 MWs for Geysers that are included in Clean Contracted and therefore should not be incorporated separately into Base earnings calculations Volumes and prices for cleared/committed capacity differ from Base Earnings capacity assumptions and are not additive to Base Earnings PJM Volume (MW) Price ($/MWd) Volume (MW) Price ($/MWd) Volume (MW) Price ($/MWd) Nuclear ComEd (CMC units) (2) 6,200 n/a 6,200 n/a Other PJM 9,350 $270 9,350 $329 15,525 $333 Total Nuclear (3) 15,550 15,550 15,525 Fossil/Other (4) BGE 325 $466 375 $329 375 $333 Other PJM (5) 5,825 $270 6,225 $329 2,575 $333 Total Fossil/Other (6) 6,150 6,600 2,950 MISO Volume (MW) Price ($/MWd) Volume (MW) Price ($/MWd) Total Nuclear (3) 1,100 $217 1,100 $126 ISO-NE Volume (MW) Price ($/MWd) Volume (MW) Price ($/MWd) Volume (MW) Price ($/MWd) Fossil/Other NEMA/SEMA (7) 1,075 $87 1,025 $85 875 $118 NH/ME 1,150 $83 1,250 $85 1,200 $118 Total ISO-NE 2,225 2,275 2,075 CAISO Sold (MW) % Sold Sold (MW) % Sold Sold (MW) % Sold Net Qualifying Capacity (8) 5,925 95% 5,875 95% 5,275 85% 2025/2026 2026/2027 2027/2028 2026 2027 2028

2028/2029 PJM Capacity Auction Results 28 2028/2029 Price ($/MW-day) Cleared Volumes (MW) (1)Zone $3259,800Nuclear $325400Fossil/Others 10,200ComEd $3254,325Nuclear $3252,225Fossil/Others 6,550EMAAC $3251,575Nuclear $325150Fossil/Others 1,725MAAC $325375Fossil/Others 375BGE $32525Fossil/Others 25RTO 15,700Total Nuclear 3,175Total Fossil/Others 18,875PJM Portfolio (1) Volumes are rounded and reflect Constellation’s cleared volumes at ownership. Cleared capacity volumes for generation assets held for sale are excluded. Interactions with PTC Capacity is included in the PTC gross receipts calculation. The impact of higher capacity prices will depend on where updated gross receipts land around the PTC zone (and if above the floor price)

Appendix Reconciliation of Non-GAAP Measures 29

Three Months Ended June 30, 20252026 Earnings Per Share Earnings Per Share Adjusted Operating Earnings* reconciliation ($M except per share data) $2.67$839$1.42$513 GAAP Net Income (Loss) Attributable to Common Shareholders ($0.38)($121)$0.94$340Unrealized (Gain) Loss on Fair Value (1) ($0.46)($144)($0.61)($221)Decommissioning-Related Activities (2) --$0.41$149Amortization of Acquired Commodity Contracts (3) $0.03$9$0.23$84Calpine Merger and Integration Costs (4) $0.02$7--Plant Retirements & Divestitures $0.03$9$0.06$20Pension & OPEB Non-Service (Credits) Costs --$0.10$35Change in Legal and Environmental Liabilities $1.91$599$2.55$920Adjusted Non-GAAP Operating Earnings* GAAP to Non-GAAP Reconciliation – Adjusted Operating Earnings* 30 Note: Items may not sum due to rounding. Earnings are reflected on an after-tax basis. Earnings per share amount is based on average diluted common shares outstanding of 360 million and 314 million for the three months ended June 30, 2026 and 2025, respectively. (1) Includes unrealized gains and losses on economic hedges, interest rate swaps, and fair value adjustments related to gas imbalances and equity investments (2) Reflects all gains and losses associated with NDTs, ARO accretion, ARC depreciation, ARO remeasurement, and impacts of contractual offset for Regulatory Agreement Units (3) In 2026, reflects the non-cash impacts of the amortization of certain commodity contracts recorded at fair value associated with the Calpine acquisition (4) Reflects costs associated with the completion of the Calpine merger and subsequent integration of its operations

GAAP to Non-GAAP Reconciliation – Adjusted O&M* 31 20272026Adjusted O&M* Reconciliation ($M) $7,775$7,775GAAP O&M ($275)$25Decommissioning-Related Activities (1) ($300)($250) Direct cost of sales incurred to generate revenues for certain Commercial and Power businesses (2) ($125)($475)Calpine Merger and Integration Costs (3) -($50)CCEC Settlement $7,075$7,025Adjusted O&M* Note: Items may not sum due to rounding. All amounts rounded to the nearest $25M. (1) Reflects all gains and losses associated with ARO accretion, ARO remeasurement, and any earnings neutral impacts of contractual offset for Regulatory Agreement Units (2) Reflects the direct cost of sales of certain businesses, which are included in gross margin (3) Reflects costs associated with the completion of the Calpine merger and subsequent integration of its operations

32 Contact Information InvestorRelations@constellation.com Links Events and Presentations Reports & SEC Filings Constellation Sustainability Report Nuclear 101

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For the EDGAR submission types of Form 8-K: the date of the report, the date of the earliest event reported; for the EDGAR submission types of Form N-1A: the filing date; for all other submission types: the end of the reporting or transition period. The format of the date is YYYY-MM-DD.

+ References

No definition available.

+ Details

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dei_DocumentPeriodEndDate

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xbrli:dateItemType

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na

Period Type:

duration

X

- Definition

The type of document being provided (such as 10-K, 10-Q, 485BPOS, etc). The document type is limited to the same value as the supporting SEC submission type, or the word 'Other'.

+ References

No definition available.

+ Details

Name:

dei_DocumentType

Namespace Prefix:

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Data Type:

dei:submissionTypeItemType

Balance Type:

na

Period Type:

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- Definition

Address Line 1 such as Attn, Building Name, Street Name

+ References

No definition available.

+ Details

Name:

dei_EntityAddressAddressLine1

Namespace Prefix:

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Data Type:

xbrli:normalizedStringItemType

Balance Type:

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Period Type:

duration

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- Definition

Name of the City or Town

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No definition available.

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Name:

dei_EntityAddressCityOrTown

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Data Type:

xbrli:normalizedStringItemType

Balance Type:

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- Definition

Code for the postal or zip code

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No definition available.

+ Details

Name:

dei_EntityAddressPostalZipCode

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Data Type:

xbrli:normalizedStringItemType

Balance Type:

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- Definition

Name of the state or province.

+ References

No definition available.

+ Details

Name:

dei_EntityAddressStateOrProvince

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Data Type:

dei:stateOrProvinceItemType

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- Definition

A unique 10-digit SEC-issued value to identify entities that have filed disclosures with the SEC. It is commonly abbreviated as CIK.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b-2

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Name:

dei_EntityCentralIndexKey

Namespace Prefix:

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Data Type:

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Balance Type:

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Period Type:

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- Definition

Indicate if registrant meets the emerging growth company criteria.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b-2

+ Details

Name:

dei_EntityEmergingGrowthCompany

Namespace Prefix:

dei_

Data Type:

xbrli:booleanItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Commission file number. The field allows up to 17 characters. The prefix may contain 1-3 digits, the sequence number may contain 1-8 digits, the optional suffix may contain 1-4 characters, and the fields are separated with a hyphen.

+ References

No definition available.

+ Details

Name:

dei_EntityFileNumber

Namespace Prefix:

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Data Type:

dei:fileNumberItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Two-character EDGAR code representing the state or country of incorporation.

+ References

No definition available.

+ Details

Name:

dei_EntityIncorporationStateCountryCode

Namespace Prefix:

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Data Type:

dei:edgarStateCountryItemType

Balance Type:

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Period Type:

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X

- Definition

The exact name of the entity filing the report as specified in its charter, which is required by forms filed with the SEC.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b-2

+ Details

Name:

dei_EntityRegistrantName

Namespace Prefix:

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- Definition

The Tax Identification Number (TIN), also known as an Employer Identification Number (EIN), is a unique 9-digit value assigned by the IRS.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b-2

+ Details

Name:

dei_EntityTaxIdentificationNumber

Namespace Prefix:

dei_

Data Type:

dei:employerIdItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Local phone number for entity.

+ References

No definition available.

+ Details

Name:

dei_LocalPhoneNumber

Namespace Prefix:

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Data Type:

xbrli:normalizedStringItemType

Balance Type:

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Period Type:

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- Definition

Boolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 13e

-Subsection 4c

+ Details

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dei_PreCommencementIssuerTenderOffer

Namespace Prefix:

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Data Type:

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Balance Type:

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Period Type:

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- Definition

Boolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 14d

-Subsection 2b

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dei_PreCommencementTenderOffer

Namespace Prefix:

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Data Type:

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Balance Type:

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- Definition

Title of a 12(b) registered security.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection b

+ Details

Name:

dei_Security12bTitle

Namespace Prefix:

dei_

Data Type:

dei:securityTitleItemType

Balance Type:

na

Period Type:

duration

X

- Definition

Name of the Exchange on which a security is registered.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 12

-Subsection d1-1

+ Details

Name:

dei_SecurityExchangeName

Namespace Prefix:

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Data Type:

dei:edgarExchangeCodeItemType

Balance Type:

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Period Type:

duration

X

- Definition

Boolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as soliciting material pursuant to Rule 14a-12 under the Exchange Act.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Exchange Act

-Number 240

-Section 14a

-Subsection 12

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Name:

dei_SolicitingMaterial

Namespace Prefix:

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Data Type:

xbrli:booleanItemType

Balance Type:

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Period Type:

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X

- Definition

Trading symbol of an instrument as listed on an exchange.

+ References

No definition available.

+ Details

Name:

dei_TradingSymbol

Namespace Prefix:

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Data Type:

dei:tradingSymbolItemType

Balance Type:

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Period Type:

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X

- Definition

Boolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as written communications pursuant to Rule 425 under the Securities Act.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef

-Publisher SEC

-Name Securities Act

-Number 230

-Section 425

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dei_WrittenCommunications

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Data Type:

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Period Type:

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- Details

Name:

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