Exhibit 99.1 News Release Contact: James Gherardi Corporate Communications 312-394-7417 Andrew Plenge Investor Relations 312-394-2345 EXELON REPORTS FOURTH QUARTER AND FULL YEAR 2024 RESULTS AND INITIATES 2025 FINANCIAL OUTLOOK Earnings Release Highlights • GAAP net income of $0.64 per share and Adjusted (non-GAAP) operating earnings of $0.64 per share for the fourth quarter of 2024, resulting in full-year GAAP net income of $2.45 per share and Adjusted (non-GAAP) operating earnings of $2.50 per share • Introducing 2025 Adjusted (non-GAAP) operating earnings guidance range of $2.64-$2.74 per share • Declaring quarterly dividend of $0.40 per share for the first quarter of 2025, implying an expected total 2025 dividend that represents an approximate 60% payout of Adjusted (non-GAAP) operating earnings per share • Projecting to invest $38 billion of capital expenditures over the next four years, an increase of 10% versus the prior plan to support customer needs and grid reliability, resulting in expected rate base growth of 7.4% and operating EPS compounded annual growth of 5-7% from 2024 to 2028 • Updating 4-year financing plan to include $1.4 billion of additional equity to fund approximately 40% of $3.5 billion of incremental capital expenditures, in line with a balanced funding strategy and resulting in implied total annual equity needs of $700 million per year from 2025 through 2028 • All utilities sustained top quartile or better performance in reliability and safety, and all gas utilities sustained top decile performance in gas odor response • Close to 90% of Exelon’s rate base is now covered by established mechanisms outlining cost recovery through 2026 or 2027, with final orders issued in the fourth quarter for Pepco’s multi-year rate plan in DC, PECO’s electric and gas rate cases, and ComEd’s Refiled Grid Plan CHICAGO (Feb. 12, 2025) — Exelon Corporation (Nasdaq: EXC) today reported its financial results for the fourth quarter and full year 2024. "I am pleased to announce Exelon has delivered against our financial goals for the third straight year since becoming a transmission and delivery-only company, and we delivered top quartile performance across all our local energy companies, with ComEd and Pepco Holdings in the top decile," said Exelon President and Chief Executive Officer Calvin Butler. "Our commitment to our customers, grid reliability, community investment and being an economic engine in the regions we serve has positioned us as a leader 1 in the energy transformation. As we celebrate Exelon's 25th anniversary in 2025, we are excited to continue our journey of innovation and excellence, ensuring that we meet and exceed the evolving needs of our customers and communities." "Exelon's financial performance in 2024 exceeded expectations, with earnings of $0.64 per share (GAAP and non-GAAP) in the last quarter of 2024 and full-earnings of $2.45 per share on a GAAP basis and $2.50 per share on a non-GAAP basis," said Exelon Chief Financial Officer Jeanne Jones. "With growth in our four-year capital plan driven by investment needs across our regions, we continue to expect 5-7% annualized earning growth through 2028. Our focus on industry-leading operations, cost management, a broad suite of customer saving solutions, and advocacy for fair and equitable energy policies will ensure our customers are receiving premium value for the investments we make." Fourth Quarter 2024 Exelon's GAAP net income for the fourth quarter of 2024 increased to $0.64 per share from $0.62 per share in the fourth quarter of 2023. Adjusted (non-GAAP) operating earnings for the fourth quarter of 2024 increased to $0.64 per share from $0.60 per share in the fourth quarter of 2023. For the reconciliations of GAAP net income to Adjusted (non-GAAP) operating earnings, refer to the tables beginning on page 5. GAAP net income and Adjusted (non-GAAP) operating earnings in the fourth quarter of 2024 primarily reflect: • Higher utility earnings primarily due to distribution rates at BGE, distribution and transmission rate increases at PHI, a tax repairs deduction at PECO, lower contracting costs at PHI, lower storm costs at PECO and PHI, and a higher distribution rate base as well as a higher return on regulatory assets primarily due to an increase in asset balances at ComEd. This was partially offset by MYP reconciliation impacts at BGE; timing of distribution earnings, lower allowed ROE, the absence of a return on the pension asset within distribution earnings, and lower carrying costs related to the CMC regulatory asset at ComEd; and higher depreciation and amortization and interest expense at BGE and PHI. Note that rate increases are associated with updated recovery rates for costs and investments to serve customers. • Lower costs at the Exelon holding company primarily due an absence of realized losses from hedging activity. Full Year 2024 Exelon's GAAP net income for 2024 increased to $2.45 per share from $2.34 per share in 2023. Adjusted (non-GAAP) operating earnings for 2024 increased to $2.50 per share from $2.38 per share in 2023. GAAP net income and Adjusted (non-GAAP) operating earnings for the full year 2024 primarily reflect: • Higher utility earnings primarily due to distribution rates at BGE, distribution and transmission rate increases at PHI, less unfavorable weather at PECO, a higher return on regulatory assets primarily due to an increase in asset balances and higher transmission peak load at ComEd, lower contracting costs at PHI, a tax repairs deduction at PECO, and favorable impacts of the multi-year plan reconciliations at Pepco. This was partially offset by higher interest expense at PECO, BGE, and PHI; lower impacts of the MYP reconciliations at BGE; higher depreciation and amortization expense at PECO, BGE, and PHI; lower allowed ROE, the absence of a return on the pension asset within distribution earnings, and lower carrying costs related to the CMC regulatory asset at ComEd; and higher credit loss expense at PECO and BGE. Note that rate increases are associated with updated recovery rates for costs and investments to serve customers. 2 • Higher costs at the Exelon holding company due to higher interest expense. This was partially offset by an absence of realized losses from hedging activity. Operating Company Results 1 ComEd ComEd's fourth quarter of 2024 GAAP net income decreased to $243 million from $268 million in the fourth quarter of 2023. ComEd's Adjusted (non-GAAP) operating earnings for the fourth quarter of 2024 decreased to $243 million from $269 million in the fourth quarter of 2023, primarily due to timing of distribution earnings, lower allowed distribution ROE, the absence of a return on the pension asset within distribution earnings, and lower carrying cost recovery related to the CMC regulatory asset, partially offset by higher distribution rate base, and higher return on regulatory assets primarily due to an increase in asset balances. Due to revenue decoupling, ComEd's distribution earnings are not intended to be affected by actual weather or customer usage patterns. PECO PECO’s fourth quarter of 2024 GAAP net income increased to $195 million from $153 million in the fourth quarter of 2023. PECO's Adjusted (non-GAAP) operating earnings for the fourth quarter of 2024 increased to $196 million from $154 million in the fourth quarter of 2023, primarily due to higher tax repair deductions and lower storm costs. BGE BGE’s fourth quarter of 2024 GAAP net income decreased to $175 million from $199 million in the fourth quarter of 2023. BGE's Adjusted (non-GAAP) operating earnings for the fourth quarter of 2024 decreased to $175 million from $199 million in the fourth quarter of 2023, primarily due to lower impacts of multi-year plans reconciliations, higher depreciation and amortization expense, and higher interest expense, partially offset by distribution rates. Due to revenue decoupling, BGE's distribution earnings are not intended to be affected by actual weather or customer usage patterns. PHI PHI’s fourth quarter of 2024 GAAP net income increased to $138 million from $101 million in the fourth quarter of 2023. PHI’s Adjusted (non-GAAP) operating earnings for the fourth quarter of 2024 increased to $132 million from $102 million in the fourth quarter of 2023, primarily due to distribution and transmission rate increases and a decrease in contracting and storm costs, partially offset by increases depreciation and amortization and interest expense. Due to revenue decoupling, PHI's distribution earnings related to Pepco Maryland, DPL Maryland, Pepco District of Columbia, and ACE are not intended to be affected by actual weather or customer usage patterns. ___________ 1 Exelon’s four business units include ComEd, which consists of electricity transmission and distribution operations in northern Illinois; PECO, which consists of electricity transmission and distribution operations and retail natural gas distribution operations in southeastern Pennsylvania; BGE, which consists of electricity transmission and distribution operations and retail natural gas distribution operations in central Maryland; and PHI, which consists of electricity transmission and distribution operations in the District of Columbia and portions of Maryland, Delaware, and New Jersey and retail natural gas distribution operations in northern Delaware. 3 Initiates Annual Guidance for 2025 Exelon introduced a guidance range for 2025 Adjusted (non-GAAP) operating earnings of $2.64-$2.74 per share. There are no adjustments between 2025 projected GAAP earnings and Adjusted (non-GAAP) operating earnings currently. Recent Developments and Fourth Quarter Highlights • Dividend: On February 12, 2025, Exelon’s Board of Directors declared a regular quarterly dividend of $0.40 per share on Exelon’s common stock. The dividend is payable on March 14, 2025, Exelon shareholders of record as of the close of business on February 24, 2025. • Rate Case Developments: ◦ ComEd Distribution Formula Rate Reconciliation: On October 31, 2024, the Illinois Commerce Commission (ICC) issued a final order under Rider Delivery Service Pricing Reconciliation. The ICC approved a total requested revenue requirement increase of $623 million, reflecting an ROE of 9.89%. The 2024 filing reconciled the delivery service rates in effect in 2023 with the actual delivery service costs incurred in 2023. ◦ ComEd Refiled Grid Plan and Multi-Year Rate Plan (MRP): On December 19, 2024, the ICC approved the Refiled Grid Plan and adjusted the approved MRP with rates effective on January 1, 2025. The final order is inclusive of rate increases of approximately $752 million in 2024, $80 million in 2025, $102 million in 2026, and $111 million in 2027, reflecting an ROE of 8.905%. ◦ Pepco District of Columbia Electric Distribution Base Rate Case: On November 26, 2024, the Public Service Commission of the District of Columbia (DCPSC) approved Pepco’s multi-year plan for January 1, 2025 through December 31, 2026. The DCPSC awarded Pepco electric incremental revenue requirement increases of $99 million and $24 million for 2025 and 2026, respectively, reflecting an ROE of 9.5%. ◦ PECO Pennsylvania Electric Distribution Rate Cases: On December 12, 2024 the Pennsylvania Public Utility Commission (PAPUC) issued a final order approving a $354 million increase in PECO's annual electric rates. The rate increase was resolved through a settlement agreement, which did not specify an approved ROE. The rates are effective on January 1, 2025. ◦ PECO Pennsylvania Natural Gas Distribution Rate Case: On December 12, 2024 the PAPUC issued a final order approving a $78 million increase in PECO's annual natural gas rates. The rate increase was resolved through a settlement agreement, which did not specify an approved ROE. The rates are effective on January 1, 2025. • Financing Activities: ◦ There were no financing activities in the fourth quarter. 4 Adjusted (non-GAAP) Operating Earnings Reconciliation Adjusted (non-GAAP) operating earnings for the fourth quarter of 2024 do not include the following items (after tax) that were included in reported GAAP net income: (in millions, except per share amounts) Exelon Earnings per Diluted Share Exelon ComEd PECO BGE PHI 2024 GAAP net income $ 0.64 $ 647 $ 243 $ 195 $ 175 $ 138 Environmental costs (net of taxes of $5) (0.01) (12) — — — (12) Asset retirement obligation (net of taxes of $3) 0.01 8 — — — 8 Cost management charge (net of taxes of $1, $0, and $1, respectively) — 2 — 1 — 1 Income tax-related adjustments (entire amount represents tax expense) — (3) — — — (3) 2024 Adjusted (non-GAAP) operating earnings $ 0.64 $ 642 $ 243 $ 196 $ 175 $ 132 Adjusted (non-GAAP) operating earnings for the fourth quarter of 2023 do not include the following items (after tax) that were included in reported GAAP net income: (in millions, except per share amounts) Exelon Earnings per Diluted Share Exelon ComEd PECO BGE PHI 2023 GAAP net income $ 0.62 $ 617 $ 268 $ 153 $ 199 $ 101 Mark-to-market impact of economic hedging activities (net of taxes of $6) (0.02) (17) — — — — Separation costs (net of taxes of $1, $1, $0, $0, and $0, respectively) — 3 1 1 1 1 2023 Adjusted (non-GAAP) operating earnings $ 0.60 $ 603 $ 269 $ 154 $ 199 $ 102 Adjusted (non-GAAP) operating earnings for the full year of 2024 do not include the following items (after tax) that were included in reported GAAP net income: (in millions, except per share amounts) Exelon Earnings per Diluted Share Exelon ComEd PECO BGE PHI 2024 GAAP net income $ 2.45 $ 2,460 $ 1,066 $ 551 $ 527 $ 741 Environmental costs (net of taxes of $5) (0.01) (13) — — — (13) Asset retirement obligations (net of taxes of $3) 0.01 8 — — — 8 Change in FERC audit liability (net of taxes of $13) 0.04 42 40 — — — Cost management charge (net of taxes of $4, $0, $2, $0, and $2, respectively) 0.01 13 — 5 1 6 Income tax-related adjustments (entire amount represents tax expense) — (3) — — — (3) 2024 Adjusted (non-GAAP) operating earnings $ 2.50 $ 2,507 $ 1,106 $ 556 $ 529 $ 739 5 Adjusted (non-GAAP) operating earnings for the full year of 2023 do not include the following items (after tax) that were included in reported GAAP net income: (in millions, except per share amounts) Exelon Earnings per Diluted Share Exelon ComEd PECO BGE PHI 2023 GAAP net income $ 2.34 $ 2,328 $ 1,090 $ 563 $ 485 $ 590 Mark-to-market impact of economic hedging activities (net of taxes of $1) — (4) — — — — Environmental costs (net of taxes of $8) 0.03 29 — — — 29 Asset retirement obligations (net of taxes of $1) — (1) — — — (1) SEC matter loss contingency (net of taxes of $0) 0.05 46 — — — — Separation costs (net of taxes of $7, $3, $1, $1, and $2, respectively) 0.02 22 8 4 4 6 Change in FERC audit liability (net of taxes of $4) 0.01 11 11 — — — Income tax-related adjustments (entire amount represents tax expense) (0.05) (54) — — — — 2023 Adjusted (non-GAAP) operating earnings $ 2.38 $ 2,377 $ 1,108 $ 566 $ 489 $ 624 __________ Note: Amounts may not sum due to rounding. Unless otherwise noted, the income tax impact of each reconciling item between GAAP net income and Adjusted (non-GAAP) operating earnings is based on the marginal statutory federal and state income tax rates for each Registrant, taking into account whether the income or expense item is taxable or deductible, respectively, in whole or in part. For all items, the marginal statutory income tax rates for 2024 and 2023 ranged from 24.0% to 29.0%. Webcast Information Exelon will discuss fourth quarter 2024 earnings in a conference call scheduled for today at 9 a.m. Central Time (10 a.m. Eastern Time). The webcast and associated materials can be accessed at www.exeloncorp.com/investor-relations. About Exelon Exelon (Nasdaq: EXC) is a Fortune 200 company and the nation’s largest utility company, serving more than 10.7 million customers through six fully regulated transmission and distribution utilities — Atlantic City Electric (ACE), Baltimore Gas and Electric (BGE), Commonwealth Edison (ComEd), Delmarva Power & Light (DPL), PECO Energy Company (PECO), and Potomac Electric Power Company (Pepco). Exelon's 20,000 employees dedicate their time and expertise to supporting our communities through reliable, affordable and efficient energy delivery, workforce development, equity, economic development and volunteerism. Follow @Exelon on Twitter | X. Non-GAAP Financial Measures In addition to net income as determined under generally accepted accounting principles in the United States (GAAP), Exelon evaluates its operating performance using the measure of Adjusted (non-GAAP) operating earnings because management believes it represents earnings directly related to the ongoing operations of the business. Adjusted (non-GAAP) operating earnings exclude certain costs, expenses, gains and losses, and other specified items. This measure is intended to enhance an investor’s overall understanding of period over period operating results and provide an indication of Exelon’s baseline operating performance excluding items that are considered by management to be not directly related to the ongoing operations of the business. In addition, this measure is among the primary indicators management uses as a basis for evaluating performance, allocating resources, setting incentive compensation targets, 6 and planning and forecasting of future periods. Adjusted (non-GAAP) operating earnings is not a presentation defined under GAAP and may not be comparable to other companies’ presentation. Exelon has provided the non-GAAP financial measure as supplemental information and in addition to the financial measures that are calculated and presented in accordance with GAAP. Adjusted (non-GAAP) operating earnings should not be deemed more useful than, a substitute for, or an alternative to the most comparable GAAP net income measures provided in this earnings release and attachments. This press release and earnings release attachments provide reconciliations of Adjusted (non-GAAP) operating earnings to the most directly comparable financial measures calculated and presented in accordance with GAAP, are posted on Exelon’s website: https://investors.exeloncorp.com , and have been furnished to the Securities and Exchange Commission on Form 8-K on Feb. 12, 2025. Cautionary Statements Regarding Forward-Looking Information This press release contains certain forward-looking statements within the meaning of federal securities laws that are subject to risks and uncertainties. Words such as “could,” “may,” “expects,” “anticipates,” “will,” “targets,” “goals,” “projects,” “intends,” “plans,” “believes,” “seeks,” “estimates,” “predicts,” “should,” 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. Accordingly, any such statements are qualified in their entirety by reference to, and are accompanied by, the following important factors that may cause our actual results or outcomes to differ materially from those contained in our forward-looking statements, including, but not limited to: unfavorable legislative and/or regulatory actions; uncertainty as to outcomes and timing of regulatory approval proceedings and/or negotiated settlements thereof; environmental liabilities and remediation costs; state and federal legislation requiring use of low-emission, renewable, and/or alternate fuel sources and/or mandating implementation of energy conservation programs requiring implementation of new technologies; challenges to tax positions taken, tax law changes, and difficulty in quantifying potential tax effects of business decisions; negative outcomes in legal proceedings; adverse impact of the activities associated with the past deferred prosecution agreement (DPA) and now-resolved SEC investigation on Exelon’s and ComEd’s reputation and relationships with legislators, regulators, and customers; physical security and cybersecurity risks; extreme weather events, natural disasters, operational accidents such as wildfires or natural, gas explosions, war, acts and threats of terrorism, public health crises, epidemics, pandemics, or other significant events; lack of sufficient capacity to meet actual or forecasted demand or disruptions at power generation facilities owned by third parties; emerging technologies that could affect or transform the energy industry; instability in capital and credit markets; a downgrade of any Registrant’s credit ratings or other failure to satisfy the credit standards in the Registrants’ agreements or regulatory financial requirements; significant economic downturns or increases in customer rates; impacts of climate change and weather on energy usage and maintenance and capital costs; and impairment of long-lived assets, goodwill, and other assets. New factors emerge from time to time, and it is impossible for us to predict all of such factors, nor can we assess the impact of each such factor on the business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statements. For more information, see those factors discussed with respect to Exelon Corporation, Commonwealth Edison Company, PECO Energy Company, Baltimore Gas and Electric Company, Pepco Holdings LLC, Potomac Electric Power Company, Delmarva Power & Light Company, and Atlantic City Electric Company (Registrants) in the Registrants' most recent Annual Report on Form 10-K, including in Part I, ITEM 1A, any subsequent Quarterly Reports on Form 10-Q, and in other reports filed by the Registrants from time to time with the SEC. 7 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. None of the Registrants 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. Exelon uses its corporate website, www.exeloncorp.com, investor relations website, investors.exeloncorp.com, and social media channels to communicate with Exelon's investors and the public about the Registrants and other matters. Exelon's posts through these channels may be deemed material. Accordingly, Exelon encourages investors and others interested in the Registrants to routinely monitor these channels, in addition to following the Registrants' press releases, Securities and Exchange Commission filings and public conference calls and webcasts. The contents of Exelon's websites and social media channels are not, however, incorporated by reference into this press release. 8 Table of Contents Earnings Release Attachments Table of Contents Consolidating Statement of Operations 1 Consolidated Balance Sheets 3 Consolidated Statements of Cash Flows 5 Reconciliation of GAAP Net Income (Loss) to Adjusted (non-GAAP) Operating Earnings and Analysis of Earnings 6 Statistics ComEd 10 PECO 11 BGE 13 Pepco 15 DPL 16 ACE 18 Table of Contents Consolidating Statements of Operations (unaudited) (in millions) ComEd PECO BGE PHI Other (a) Exelon Three Months Ended December 31, 2024 Operating revenues $ 1,816 $ 998 $ 1,157 $ 1,509 $ (9) $ 5,471 Operating expenses Purchased power and fuel 538 363 423 574 1 1,899 Operating and maintenance 426 245 240 322 (49) 1,184 Depreciation and amortization 390 110 164 232 17 913 Taxes other than income taxes 89 54 91 133 10 377 Total operating expenses 1,443 772 918 1,261 (21) 4,373 Gain on sales of assets — — — (1) — (1) Operating income 373 226 239 247 12 1,097 Other income and (deductions) Interest expense, net (126) (62) (56) (97) (126) (467) Other, net 27 10 10 19 — 66 Total other income and (deductions) (99) (52) (46) (78) (126) (401) Income (loss) before income taxes 274 174 193 169 (114) 696 Income taxes 31 (21) 18 31 (10) 49 Net income (loss) attributable to common shareholders $ 243 $ 195 $ 175 $ 138 $ (104) $ 647 Three Months Ended December 31, 2023 Operating revenues $ 2,008 $ 917 $ 1,041 $ 1,411 $ (9) $ 5,368 Operating expenses Purchased power and fuel 748 347 387 544 — 2,026 Operating and maintenance 373 217 109 336 (11) 1,024 Depreciation and amortization 358 100 167 249 16 890 Taxes other than income taxes 87 46 80 121 11 345 Total operating expenses 1,566 710 743 1,250 16 4,285 Gain on sale of assets — — — 9 — 9 Operating income (loss) 442 207 298 170 (25) 1,092 Other income and (deductions) Interest expense, net (120) (53) (47) (84) (148) (452) Other, net 24 10 5 28 10 77 Total other income and (deductions) (96) (43) (42) (56) (138) (375) Income (loss) before income taxes 346 164 256 114 (163) 717 Income taxes 78 11 57 13 (59) 100 Net income (loss) attributable to common shareholders $ 268 $ 153 $ 199 $ 101 $ (104) $ 617 Change in net income (loss) from 2023 to 2024 $ (25) $ 42 $ (24) $ 37 $ — $ 30 1 Table of Contents Consolidating Statements of Operations (unaudited) (in millions) ComEd PECO BGE PHI Other (a) Exelon Twelve Months Ended December 31, 2024 Operating revenues $ 8,219 $ 3,973 $ 4,426 $ 6,448 $ (38) $ 23,028 Operating expenses Purchased power and fuel 3,042 1,477 1,651 2,513 — 8,683 Operating and maintenance 1,703 1,120 1,036 1,250 (169) 4,940 Depreciation and amortization 1,514 428 638 947 67 3,594 Taxes other than income taxes 376 218 345 528 37 1,504 Total operating expenses 6,635 3,243 3,670 5,238 (65) 18,721 Gain on sales of assets 5 4 — (1) 4 12 Operating income 1,589 734 756 1,209 31 4,319 Other income and (deductions) Interest expense, net (501) (232) (216) (376) (589) (1,914) Other, net 94 37 36 97 (2) 262 Total other income and (deductions) (407) (195) (180) (279) (591) (1,652) Income (loss) before income taxes 1,182 539 576 930 (560) 2,667 Income taxes 116 (12) 49 189 (135) 207 Net income (loss) attributable to common shareholders $ 1,066 $ 551 $ 527 $ 741 $ (425) $ 2,460 Twelve Months Ended December 31, 2023 Operating revenues $ 7,844 $ 3,894 $ 4,027 $ 6,026 $ (64) $ 21,727 Operating expenses Purchased power and fuel 2,816 1,544 1,531 2,348 2 8,241 Operating and maintenance 1,450 1,003 741 1,289 76 4,559 Depreciation and amortization 1,403 397 654 990 62 3,506 Taxes other than income taxes 369 202 319 487 31 1,408 Total operating expenses 6,038 3,146 3,245 5,114 171 17,714 Gain on sales of assets — — — 9 1 10 Operating income (loss) 1,806 748 782 921 (234) 4,023 Other income and (deductions) Interest expense, net (477) (201) (182) (323) (546) (1,729) Other, net 75 36 18 108 171 408 Total other income and (deductions) (402) (165) (164) (215) (375) (1,321) Income (loss) before income taxes 1,404 583 618 706 (609) 2,702 Income taxes 314 20 133 116 (209) 374 Net income (loss) attributable to common shareholders $ 1,090 $ 563 $ 485 $ 590 $ (400) $ 2,328 Change in net income (loss) 2023 to 2024 $ (24) $ (12) $ 42 $ 151 $ (25) $ 132 __________ (a) Other primarily includes eliminating and consolidating adjustments, Exelon’s corporate operations, shared service entities, and other financing and investment activities. 2 Table of Contents Exelon Consolidated Balance Sheets (unaudited) (in millions) December 31, 2024 December 31, 2023 Assets Current assets Cash and cash equivalents $ 357 $ 445 Restricted cash and cash equivalents 541 482 Accounts receivable Customer accounts receivable 3,144 2,659 Customer allowance for credit losses (406) (317) Customer accounts receivable, net 2,738 2,342 Other accounts receivable 1,123 1,101 Other allowance for credit losses (107) (82) Other accounts receivable, net 1,016 1,019 Inventories, net Fossil fuel 72 94 Materials and supplies 781 707 Regulatory assets 1,940 2,215 Prepaid renewable energy credits 494 413 Other 445 370 Total current assets 8,384 8,087 Property, plant, and equipment, net 78,182 73,593 Deferred debits and other assets Regulatory assets 8,710 8,698 Goodwill 6,630 6,630 Receivable related to Regulatory Agreement Units 4,026 3,232 Investments 290 251 Other 1,562 1,365 Total deferred debits and other assets 21,218 20,176 Total assets $ 107,784 $ 101,856 3 Table of Contents December 31, 2024 December 31, 2023 Liabilities and Shareholders' Equity Current liabilities Short-term borrowings $ 1,859 $ 2,523 Long-term debt due within one year 1,453 1,403 Accounts payable 2,994 2,846 Accrued expenses 1,468 1,375 Payables to affiliates 5 5 Customer deposits 446 411 Regulatory liabilities 411 389 Mark-to-market derivative liabilities 29 74 Unamortized energy contract liabilities 5 8 Renewable energy credit obligations 429 348 Other 512 519 Total current liabilities 9,611 9,901 Long-term debt 42,947 39,692 Long-term debt to financing trusts 390 390 Deferred credits and other liabilities Deferred income taxes and unamortized investment tax credits 12,793 11,956 Regulatory liabilities 10,198 9,576 Pension obligations 1,745 1,571 Non-pension postretirement benefit obligations 472 527 Asset retirement obligations 301 267 Mark-to-market derivative liabilities 103 106 Unamortized energy contract liabilities 21 27 Other 2,282 2,088 Total deferred credits and other liabilities 27,915 26,118 Total liabilities 80,863 76,101 Commitments and contingencies Shareholders’ equity Common stock 21,338 21,114 Treasury stock, at cost (123) (123) Retained earnings 6,426 5,490 Accumulated other comprehensive loss, net (720) (726) Total shareholders’ equity 26,921 25,755 Total liabilities and shareholders' equity $ 107,784 $ 101,856 4 Table of Contents Exelon Consolidated Statements of Cash Flows (unaudited) (in millions) Twelve Months Ended December 31, 2024 2023 Cash flows from operating activities Net income $ 2,460 $ 2,328 Adjustments to reconcile net income to net cash flows provided by operating activities: Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization 3,596 3,506 Gain on sales of assets and businesses (12) (10) Deferred income taxes and amortization of investment tax credits 128 319 Net fair value changes related to derivatives — 22 Other non-cash operating activities 592 (335) Changes in assets and liabilities: Accounts receivable (644) (37) Inventories (56) (45) Accounts payable and accrued expenses (37) (191) Collateral received (paid), net 33 (146) Income taxes (4) 48 Regulatory assets and liabilities, net (50) (439) Pension and non-pension postretirement benefit contributions (180) (129) Other assets and liabilities (257) (188) Net cash flows provided by operating activities 5,569 4,703 Cash flows from investing activities Capital expenditures (7,097) (7,408) Proceeds from sales of assets and businesses 38 25 Other investing activities 17 8 Net cash flows used in investing activities (7,042) (7,375) Cash flows from financing activities Changes in short-term borrowings (265) (313) Proceeds from short-term borrowings with maturities greater than 90 days 150 400 Repayments on short-term borrowings with maturities greater than 90 days (549) (150) Issuance of long-term debt 4,974 5,825 Retirement of long-term debt (1,557) (1,713) Issuance of common stock 148 140 Dividends paid on common stock (1,524) (1,433) Proceeds from employee stock plans 43 41 Other financing activities (109) (114) Net cash flows provided by financing activities 1,311 2,683 (Decrease) increase in cash, restricted cash, and cash equivalents (162) 11 Cash, restricted cash, and cash equivalents at beginning of period 1,101 1,090 Cash, restricted cash, and cash equivalents at end of period $ 939 $ 1,101 5 Table of Contents Exelon Reconciliation of GAAP Net Income (Loss) to Adjusted (non-GAAP) Operating Earnings and Analysis of Earnings Three Months Ended December 31, 2024 and 2023 (unaudited) (in millions, except per share data) Exelon Earnings per Diluted Share ComEd PECO BGE PHI Other (a) Exelon 2023 GAAP net income (loss) $ 0.62 $ 268 $ 153 $ 199 $ 101 $ (104) $ 617 Mark-to-market impact of economic hedging activities (net of taxes of $6) (0.02) — — — — (17) (17) Separation costs (net of taxes of $1, $0, $0, $0, $0, and $1, respectively) (1) — 1 1 1 1 (1) 3 2023 Adjusted (non-GAAP) operating earnings (loss) $ 0.60 $ 269 $ 154 $ 199 $ 102 $ (121) $ 603 Year over year effects on Adjusted (non-GAAP) operating earnings: Weather $ — $ — (b) $ 5 $ — (b) $ (1) (b) $ — $ 4 Load — — (b) — — (b) 5 (b) — 5 Distribution and transmission rates (2) 0.13 (9) (c) 14 (c) 69 (c) 41 (c) 17 132 Other energy delivery (3) 0.08 49 (c) 31 (c) (4) (c) 2 (c) — 78 Operating and maintenance expense (4) (0.08) (36) (21) (71) 14 30 (84) Pension and non-pension postretirement benefits (0.01) (4) (2) — 1 (6) (11) Depreciation and amortization expense (5) (0.03) (23) (8) (6) 6 (2) (33) Interest expense and other (6) (0.05) (3) 23 (12) (38) (22) (52) Total year over year effects on Adjusted (non-GAAP) operating earnings $ 0.04 $ (26) $ 42 $ (24) $ 30 $ 17 $ 39 2024 GAAP net income (loss) $ 0.64 $ 243 $ 195 $ 175 $ 138 $ (104) $ 647 Environmental costs (net of taxes of $5) (0.01) — — — (12) — (12) Asset retirement obligation (net of taxes of $3) 0.01 — — — 8 — 8 Cost management charge (net of taxes of $0, $1, and $1, respectively) (7) — — 1 — 1 — 2 Income tax-related adjustments (entire amount represents tax expense) (8) — — — — (3) — (3) 2024 Adjusted (non-GAAP) operating earnings (loss) $ 0.64 $ 243 $ 196 $ 175 $ 132 $ (104) $ 642 Note: Amounts may not sum due to rounding. Unless otherwise noted, the income tax impact of each reconciling item between GAAP net income and Adjusted (non-GAAP) operating earnings is based on the marginal statutory federal and state income tax rates for each Registrant, taking into account whether the income or expense item is taxable or deductible, respectively, in whole or in part. For all items, the marginal statutory income tax rates for 2024 and 2023 ranged from 24.0% to 29.0%. (a) Other primarily includes eliminating and consolidating adjustments, Exelon’s corporate operations, shared service entities, and other financing and investment activities. (b) For ComEd, BGE, Pepco, DPL Maryland, and ACE, customer rates are adjusted to eliminate the impacts of weather and customer usage on distribution volumes. (c) ComEd's distribution rate revenues increase or decrease as fully recoverable costs fluctuate. For regulatory recovery mechanisms, including transmission formula rates and riders across the utilities, revenues increase and decrease i) as fully recoverable costs fluctuate (with no impact on net earnings), and ii) pursuant to changes in rate base, capital structure and ROE (which impact net earnings). (1) Represents costs related to the separation primarily comprised of system-related costs, third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the separation, and employee-related severance costs, which are recorded in Operating and maintenance expense. (2) For ComEd, reflects decreased electric distribution revenues due to lower allowed electric distribution ROE and absence of a return on the pension asset, partially offset by higher rate base. For PECO, reflects increased Distribution System Improvement Charges (DSIC) revenue due to higher electric DSIC rates. For BGE, reflects increased distribution revenue due to higher rates. For PHI, reflects increased distribution and transmission revenue primarily due to higher rates. For Corporate, reflects an absence of realized losses from hedging activity. (3) For ComEd, reflects increased electric distribution and energy efficiency revenues due to higher fully recoverable costs and higher return on regulatory assets, partially offset by lower carrying cost recovery related to the CMC regulatory asset. For PECO, reflects increased energy efficiency revenues due to required regulatory programs. (4) Represents Operating and maintenance expense, excluding pension and non-pension postretirement benefits. For ComEd, primarily reflects an updated rate of capitalization of certain overhead costs. For PECO, reflects increased program costs related to regulatory required programs, partially offset by favorable storm costs. For BGE, primarily reflects lower impacts from the multi-year plans reconciliations, partially offset by a decrease in credit loss expense. For PHI, primarily reflects an absence of contracting costs due to the ACE employee strike and a decrease in storm costs. For Corporate, reflects a decrease in Operating and maintenance expense with an offsetting decrease in other income for costs billed to Constellation for services provided by Exelon through the Transition Services Agreement (TSA). (5) Reflects ongoing capital expenditures across all utilities. (6) For PECO, primarily reflects lower income tax expense due to an increase in tax repairs deduction. For BGE, primarily reflects an increase in interest expense. For PHI, reflects higher income tax expense due to certain EDIT benefits being fully amortized and passed through to customers, with an offsetting increase in Other energy delivery. For Corporate, reflects an absence of other income for costs billed to Constellation for services provided by Exelon through the TSA with an offsetting decrease in Operating and maintenance expense and partially offset by a gain on open market repurchase of a portion of Exelon's Senior unsecured notes. 6 Table of Contents (7) Primarily represents severance and reorganization costs related to cost management. (8) Reflects the adjustment to state deferred income taxes due to change in DPL's Delaware net operating loss valuation allowance. 7 Table of Contents Exelon Reconciliation of GAAP Net Income (Loss) to Adjusted (non-GAAP) Operating Earnings and Analysis of Earnings Twelve Months Ended December 31, 2024 and 2023 (unaudited) (in millions, except per share data) Exelon Earnings per Diluted Share ComEd PECO BGE PHI Other (a) Exelon 2023 GAAP net income (loss) $ 2.34 $ 1,090 $ 563 $ 485 $ 590 $ (400) $ 2,328 Mark-to-market impact of economic hedging activities (net of taxes of $1) — — — — — (4) (4) Environmental costs (net of taxes of $8) 0.03 — — — 29 — 29 Asset retirement obligations (net of taxes of $1) — — — — (1) — (1) SEC matter loss contingency (net of taxes of $0) 0.05 — — — — 46 46 Separation costs (net of taxes of $3, $1, $1, $2, and $7, respectively) (1) 0.02 8 4 4 6 — 22 Change in FERC audit liability (net of taxes of $4) 0.01 11 — — — — 11 Income tax-related adjustments (entire amount represents tax expense) (2) (0.05) — — — — (54) (54) 2023 Adjusted (non-GAAP) operating earnings (loss) $ 2.38 $ 1,108 $ 566 $ 489 $ 624 $ (410) $ 2,377 Year over year effects on Adjusted (non-GAAP) operating earnings: Weather $ 0.06 $ — (b) $ 58 $ — (b) $ 6 (b) $ — $ 64 Load 0.01 — (b) 8 — (b) 6 (b) — 14 Distribution and transmission rates (3) 0.37 (46) (c) 23 (c) 237 (c) 136 (c) 21 371 Other energy delivery (4) 0.31 269 (c) 23 (c) (24) (c) 40 (c) — 308 Operating and maintenance expense (5) (0.18) (131) (82) (130) 27 133 (183) Pension and non-pension postretirement benefits (0.02) (17) (5) — 2 2 (18) Depreciation and amortization expense (6) (0.13) (80) (23) (22) (4) (3) (132) Interest expense and other (7) (0.29) 3 (12) (21) (98) (166) (294) Total year over year effects on Adjusted (non-GAAP) operating earnings $ 0.12 $ (2) $ (10) $ 40 $ 115 $ (13) $ 130 2024 GAAP net income (loss) $ 2.45 $ 1,066 $ 551 $ 527 $ 741 $ (425) $ 2,460 Environmental costs (net of taxes of $5) (0.01) — — — (13) — (13) Asset retirement obligations (net of taxes of $3) 0.01 — — — 8 — 8 Change in FERC audit liability (net of taxes of $13) 0.04 40 — — — 2 42 Cost management charge (net of taxes of $2, $0, $2, $0, and $4, respectively) (8) 0.01 — 5 1 6 1 13 Income tax-related adjustments (entire amount represents tax expense) (2) — — — — (3) — (3) 2024 Adjusted (non-GAAP) operating earnings (loss) $ 2.50 $ 1,106 $ 556 $ 529 $ 739 $ (423) $ 2,507 Note: Amounts may not sum due to rounding. Unless otherwise noted, the income tax impact of each reconciling item between GAAP net income and Adjusted (non-GAAP) operating earnings is based on the marginal statutory federal and state income tax rates for each Registrant, taking into account whether the income or expense item is taxable or deductible, respectively, in whole or in part. For all items, the marginal statutory income tax rates for 2024 and 2023 ranged from 24.0% to 29.0%. (a) Other primarily includes eliminating and consolidating adjustments, Exelon’s corporate operations, shared service entities, and other financing and investment activities. (b) For ComEd, BGE, Pepco, DPL Maryland, and ACE, customer rates are adjusted to eliminate the impacts of weather and customer usage on distribution volumes. (c) ComEd's distribution rate revenues increase or decrease as fully recoverable costs fluctuate. For regulatory recovery mechanisms, including transmission formula rates and riders across the utilities, revenues increase and decrease i) as fully recoverable costs fluctuate (with no impact on net earnings), and ii) pursuant to changes in rate base, capital structure and ROE (which impact net earnings). (1) Represents costs related to the separation primarily comprised of system-related costs, third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the separation, and employee-related severance costs, which are recorded in Operating and maintenance expense and Other, net. (2) In 2023, reflects the adjustment to state deferred income taxes due to changes in forecasted apportionment. In 2024, reflects the adjustment to state deferred income taxes due to change in DPL's Delaware net operating loss valuation allowance. (3) For ComEd, reflects decreased electric distribution revenues due to lower allowed electric distribution ROE and absence of a return on the pension asset, partially offset by higher rate base. For PECO, reflects increased DSIC revenue due to higher electric DSIC rates. For BGE, reflects increased distribution revenue due to higher rates. For PHI, reflects increased distribution and transmission revenue due to higher rates. For Corporate, reflects an absence of realized losses from hedging activity. (4) For ComEd, reflects increased electric distribution, transmission, and energy efficiency revenues due to higher fully recoverable costs, higher return on regulatory assets, and higher transmission peak load, partially offset by lower carrying cost recovery related to the CMC regulatory asset. For PECO, reflects increased energy efficiency revenues due to regulatory required programs. For PHI, reflects higher distribution and transmission revenues due to higher fully recoverable costs. (5) Represents Operating and maintenance expense, excluding pension and non-pension postretirement benefits. For ComEd, reflects an updated rate of capitalization of certain overhead costs. For PECO, primarily reflects increased credit loss expense and program costs related to regulatory required programs. For BGE, reflects lower impacts of the multi-year plans reconciliations and increased storm costs and credit loss expense. For PHI, primarily reflects an absence of contracting costs due to the ACE employee strike. For Corporate, reflects an absence of costs for DPA related matters 8 Table of Contents and a decrease in Operating and maintenance expense with an offsetting decrease in other income for costs billed to Constellation for services provided by Exelon through the TSA. (6) Reflects ongoing capital expenditures across all utilities. (7) For PECO, primarily reflects an increase in interest expense, partially offset by lower income tax expense due to an increase in tax repairs deduction. For BGE, primarily reflects an increase in interest expense. For PHI, reflects an increase in interest expense and an increase in taxes other than income. For Corporate, reflects an increase in interest expense partially offset by a gain on open market repurchase of a portion of Exelon's Senior unsecured notes, a decrease in other income from an absence of DPA related derivative claims, and an absence of other income for costs billed to Constellation for services provided by Exelon through the TSA with an offsetting decrease in Operating and maintenance expense. (8) Primarily represents severance and reorganization costs related to cost management. 9 Table of Contents ComEd Statistics Three Months Ended December 31, 2024 and 2023 Electric Deliveries (in GWhs) Revenue (in millions) 2024 2023 % Change Weather - Normal % Change 2024 2023 % Change Electric Deliveries and Revenues (a) Residential 5,656 5,806 (2.6) % (1.3) % $ 793 $ 821 (3.4) % Small commercial & industrial 6,780 6,852 (1.1) % (2.0) % 504 494 2.0 % Large commercial & industrial 7,293 6,607 10.4 % 9.1 % 270 271 (0.4) % Public authorities & electric railroads 233 233 — % (2.0) % 16 18 (11.1) % Other (b) — — n/a n/a 277 250 10.8 % Total electric revenues (c) 19,962 19,498 2.4 % 1.9 % 1,860 1,854 0.3 % Other Revenues (d) (44) 154 (128.6) % Total Electric Revenues $ 1,816 $ 2,008 (9.6) % Purchased Power $ 538 $ 748 (28.1) % % Change Heating and Cooling Degree-Days 2024 2023 Normal From 2023 From Normal Heating Degree-Days 1,767 1,747 2,139 1.1 % (17.4) % Cooling Degree-Days 39 56 14 (30.4) % 178.6 % Twelve Months Ended December 31, 2024 and 2023 Electric Deliveries (in GWhs) Revenue (in millions) 2024 2023 % Change Weather - Normal % Change 2024 2023 % Change Electric Deliveries and Revenues (a) Residential 27,274 26,023 4.8 % 2.1 % $ 3,809 $ 3,565 6.8 % Small commercial & industrial 28,367 28,706 (1.2) % (0.7) % 2,259 1,857 21.6 % Large commercial & industrial 27,870 26,708 4.4 % 4.1 % 1,145 824 39.0 % Public authorities & electric railroads 822 855 (3.9) % (4.6) % 60 51 17.6 % Other (b) — — n/a n/a 1,080 965 11.9 % Total electric revenues (c) 84,333 82,292 2.5 % 1.7 % 8,353 7,262 15.0 % Other Revenues (d) (134) 582 (123.0) % Total Electric Revenues $ 8,219 $ 7,844 4.8 % Purchased Power $ 3,042 $ 2,816 8.0 % % Change Heating and Cooling Degree-Days 2024 2023 Normal From 2023 From Normal Heating Degree-Days 4,795 5,014 5,968 (4.4) % (19.7) % Cooling Degree-Days 1,215 1,145 1,002 6.1 % 21.3 % Number of Electric Customers 2024 2023 Residential 3,727,097 3,744,213 Small commercial & industrial 396,797 391,675 Large commercial & industrial 2,283 1,877 Public authorities & electric railroads 5,775 4,807 Total 4,131,952 4,142,572 __________ (a) Reflects revenues from customers purchasing electricity directly from ComEd and customers purchasing electricity from a competitive electric generation supplier, as all customers are assessed delivery charges. For customers purchasing electricity from ComEd, revenues also reflect the cost of energy and transmission. (b) Includes transmission revenue from PJM, wholesale electric revenue, and mutual assistance revenue. (c) Includes operating revenues from affiliates totaling $2 million and $2 million for the three months ended December 31, 2024 and 2023, respectively, and $8 million and $16 million for the twelve months ended December 31, 2024 and 2023, respectively. (d) Includes alternative revenue programs and late payment charges. 10 Table of Contents PECO Statistics Three Months Ended December 31, 2024 and 2023 Electric and Natural Gas Deliveries Revenue (in millions) 2024 2023 % Change Weather- Normal % Change 2024 2023 % Change Electric (in GWhs) Electric Deliveries and Revenues (a) Residential 3,066 3,076 (0.3) % (1.7) % $ 486 $ 473 2.7 % Small commercial & industrial 1,807 1,751 3.2 % 0.6 % 140 111 26.1 % Large commercial & industrial 3,358 3,240 3.6 % 2.6 % 70 53 32.1 % Public authorities & electric railroads 143 142 0.7 % 1.2 % 8 7 14.3 % Other (b) — — n/a n/a 75 79 (5.1) % Total electric revenues (c) 8,374 8,209 2.0 % 0.5 % 779 723 7.7 % Other Revenues (d) 9 (5) (280.0) % Total Electric Revenues 788 718 9.7 % Natural Gas (in mmcfs) Natural Gas Deliveries and Revenues (e) Residential 12,549 12,145 3.3 % (0.9) % 145 138 5.1 % Small commercial & industrial 7,164 6,801 5.3 % 7.8 % 51 49 4.1 % Large commercial & industrial — 12 (100.0) % (15.7) % — — n/a Transportation 6,109 6,259 (2.4) % (1.5) % 8 7 14.3 % Other (f) — — n/a n/a 5 5 — % Total natural gas revenues (g) 25,822 25,217 2.4 % 1.1 % 209 199 5.0 % Other Revenues (d) 1 — n/a Total Natural Gas Revenues 210 199 5.5 % Total Electric and Natural Gas Revenues $ 998 $ 917 8.8 % Purchased Power and Fuel $ 363 $ 347 4.6 % % Change Heating and Cooling Degree-Days 2024 2023 Normal From 2023 From Normal Heating Degree-Days 1,345 1,351 1,528 (0.4) % (12.0) % Cooling Degree-Days 53 48 32 10.4 % 65.6 % 11 Table of Contents Twelve Months Ended December 31, 2024 and 2023 Electric and Natural Gas Deliveries Revenue (in millions) 2024 2023 % Change Weather- Normal % Change 2024 2023 % Change Electric (in GWhs) Electric Deliveries and Revenues (a) Residential 13,963 13,262 5.3 % 0.2 % $ 2,169 $ 2,090 3.8 % Small commercial & industrial 7,683 7,367 4.3 % 1.3 % 547 526 4.0 % Large commercial & industrial 13,889 13,638 1.8 % 0.6 % 261 249 4.8 % Public authorities & electric railroads 613 606 1.2 % 1.2 % 29 30 (3.3) % Other (b) — — n/a n/a 296 298 (0.7) % Total electric revenues (c) 36,148 34,873 3.7 % 0.6 % 3,302 3,193 3.4 % Other Revenues (d) 23 9 155.6 % Total Electric Revenues 3,325 3,202 3.8 % Natural Gas (in mmcfs) Natural Gas Deliveries and Revenues (e) Residential 38,328 35,842 6.9 % 0.7 % 445 473 (5.9) % Small commercial & industrial 21,906 21,182 3.4 % 0.1 % 157 172 (8.7) % Large commercial & industrial 17 51 (66.7) % (11.1) % — 1 (100.0) % Transportation 23,357 23,741 (1.6) % (2.6) % 28 27 3.7 % Other (f) — — n/a n/a 16 17 (5.9) % Total natural gas revenues (g) 83,608 80,816 3.5 % (0.4) % 646 690 (6.4) % Other Revenues (d) 2 2 — % Total Natural Gas Revenues 648 692 (6.4) % Total Electric and Natural Gas Revenues $ 3,973 $ 3,894 2.0 % Purchased Power and Fuel $ 1,477 $ 1,544 (4.3) % % Change Heating and Cooling Degree-Days 2024 2023 Normal From 2023 From Normal Heating Degree-Days 3,786 3,587 4,381 5.5 % (13.6) % Cooling Degree-Days 1,652 1,345 1,462 22.8 % 13.0 % Number of Electric Customers 2024 2023 Number of Natural Gas Customers 2024 2023 Residential 1,533,443 1,535,927 Residential 508,224 507,197 Small commercial & industrial 155,164 156,248 Small commercial & industrial 44,846 45,001 Large commercial & industrial 3,150 3,127 Large commercial & industrial 7 9 Public authorities & electric railroads 10,708 10,417 Transportation 644 627 Total 1,702,465 1,705,719 Total 553,721 552,834 __________ (a) Reflects delivery volumes and revenues from customers purchasing electricity directly from PECO and customers purchasing electricity from a competitive electric generation supplier as all customers are assessed distribution charges. For customers purchasing electricity from PECO, revenues also reflect the cost of energy and transmission. (b) Includes transmission revenue from PJM, wholesale electric revenue, and mutual assistance revenue. (c) Includes operating revenues from affiliates totaling $2 million and $3 million for the three months ended December 31, 2024 and 2023, respectively, and $7 million and $7 million for the twelve months ended December 31, 2024 and 2023, respectively. (d) Includes alternative revenue programs and late payment charges. (e) Reflects delivery volumes and revenues from customers purchasing natural gas directly from PECO and customers purchasing natural gas from a competitive natural gas supplier as all customers are assessed distribution charges. For customers purchasing natural gas from PECO, revenue also reflects the cost of natural gas. (f) Includes revenues primarily from off-system sales. (g) Includes operating revenues from affiliates totaling $1 million and less than $1 million for the three months ended December 31, 2024 and 2023, respectively, and $3 million and $2 million for the twelve months ended December 31, 2024 and 2023, respectively. 12 Table of Contents BGE Statistics Three Months Ended December 31, 2024 and 2023 Electric and Natural Gas Deliveries Revenue (in millions) 2024 2023 % Change Weather- Normal % Change 2024 2023 % Change Electric (in GWhs) Electric Deliveries and Revenues (a) Residential 2,927 2,864 2.2 % (1.9) % $ 482 $ 457 5.5 % Small commercial & industrial 638 633 0.8 % (0.4) % 85 79 7.6 % Large commercial & industrial 3,109 3,032 2.5 % 1.2 % 132 116 13.8 % Public authorities & electric railroads 48 51 (5.9) % (4.4) % 8 7 14.3 % Other (b) — — n/a n/a 112 98 14.3 % Total electric revenues (c) 6,722 6,580 2.2 % (0.4) % 819 757 8.2 % Other Revenues (d) 28 29 (3.4) % Total Electric Revenues 847 786 7.8 % Natural Gas (in mmcfs) Natural Gas Deliveries and Revenues (e) Residential 12,156 11,769 3.3 % (5.2) % 207 163 27.0 % Small commercial & industrial 2,689 2,571 4.6 % (2.8) % 34 27 25.9 % Large commercial & industrial 10,727 11,221 (4.4) % (7.1) % 61 43 41.9 % Other (f) 945 1,668 (43.3) % n/a 7 10 (30.0) % Total natural gas revenues (g) 26,517 27,229 (2.6) % (5.7) % 309 243 27.2 % Other Revenues (d) 1 12 (91.7) % Total Natural Gas Revenues 310 255 21.6 % Total Electric and Natural Gas Revenues $ 1,157 $ 1,041 11.1 % Purchased Power and Fuel $ 423 $ 387 9.3 % % Change Heating and Cooling Degree-Days 2024 2023 Normal From 2023 From Normal Heating Degree-Days 1,544 1,395 1,629 10.7 % (5.2) % Cooling Degree-Days 27 42 29 (35.7) % (6.9) % 13 Table of Contents Twelve Months Ended December 31, 2024 and 2023 Electric and Natural Gas Deliveries Revenue (in millions) 2024 2023 % Change Weather- Normal % Change 2024 2023 % Change Electric (in GWhs) Electric Deliveries and Revenues (a) Residential 12,682 12,026 5.5 % 0.3 % $ 2,038 $ 1,765 15.5 % Small commercial & industrial 2,716 2,638 3.0 % 0.3 % 360 331 8.8 % Large commercial & industrial 13,170 12,844 2.5 % 1.2 % 557 528 5.5 % Public authorities & electric railroads 198 204 (2.9) % (2.8) % 31 29 6.9 % Other (b) — — n/a n/a 414 402 3.0 % Total electric revenues (c) 28,766 27,712 3.8 % 0.7 % 3,400 3,055 11.3 % Other Revenues (d) 36 54 (33.3) % Total Electric Revenues 3,436 3,109 10.5 % Natural Gas (in mmcfs) Natural Gas Deliveries and Revenues (e) Residential 36,645 34,724 5.5 % (3.4) % 625 568 10.0 % Small commercial & industrial 8,682 8,276 4.9 % (2.5) % 110 100 10.0 % Large commercial & industrial 39,618 40,006 (1.0) % (3.8) % 204 161 26.7 % Other (f) 2,268 3,361 (32.5) % n/a 18 37 (51.4) % Total natural gas revenues (g) 87,213 86,367 1.0 % (3.5) % 957 866 10.5 % Other Revenues (d) 33 52 (36.5) % Total Natural Gas Revenues 990 918 7.8 % Total Electric and Natural Gas Revenues $ 4,426 $ 4,027 9.9 % Purchased Power and Fuel $ 1,651 $ 1,531 7.8 % % Change Heating and Cooling Degree-Days 2024 2023 Normal From 2023 From Normal Heating Degree-Days 3,973 3,590 4,538 10.7 % (12.5) % Cooling Degree-Days 1,066 960 914 11.0 % 16.6 % Number of Electric Customers 2024 2023 Number of Natural Gas Customers 2024 2023 Residential 1,216,614 1,211,889 Residential 658,776 657,823 Small commercial & industrial 115,010 115,787 Small commercial & industrial 37,874 37,993 Large commercial & industrial 13,266 13,072 Large commercial & industrial 6,369 6,309 Public authorities & electric railroads 260 261 Total 703,019 702,125 Total 1,345,150 1,341,009 __________ (a) Reflects revenues from customers purchasing electricity directly from BGE and customers purchasing electricity from a competitive electric generation supplier as all customers are assessed distribution charges. For customers purchasing electricity from BGE, revenues also reflect the cost of energy and transmission. (b) Includes transmission revenue from PJM, wholesale electric revenue, and mutual assistance revenue. (c) Includes operating revenues from affiliates totaling $1 million and $2 million for the three months ended December 31, 2024 and 2023, respectively, and $7 million and $6 million for the twelve months ended December 31, 2024 and 2023, respectively. (d) Includes alternative revenue programs and late payment charges. (e) Reflects delivery volumes and revenues from customers purchasing natural gas directly from BGE and customers purchasing natural gas from a competitive natural gas supplier as all customers are assessed distribution charges. For customers purchasing natural gas from BGE, revenue also reflects the cost of natural gas. (f) Includes revenues primarily from off-system sales. (g) Includes operating revenues from affiliates totaling $1 million and $1 million for the three months ended December 31, 2024 and 2023, respectively, and $3 million and $3 million for the twelve months ended December 31, 2024 and 2023. 14 Table of Contents Pepco Statistics Three Months Ended December 31, 2024 and 2023 Electric Deliveries (in GWhs) Revenue (in millions) 2024 2023 % Change Weather- Normal % Change 2024 2023 % Change Electric Deliveries and Revenues (a) Residential 1,808 1,535 17.8 % 8.2 % $ 328 $ 282 16.3 % Small commercial & industrial 263 240 9.6 % 6.4 % 44 42 4.8 % Large commercial & industrial 3,369 3,195 5.4 % 4.5 % 259 249 4.0 % Public authorities & electric railroads 168 186 (9.7) % (9.6) % 10 10 — % Other (b) — — n/a n/a 103 70 47.1 % Total electric revenues (c) 5,608 5,156 8.8 % 5.3 % 744 653 13.9 % Other Revenues (d) (24) (3) 700.0 % Total Electric Revenues $ 720 $ 650 10.8 % Purchased Power $ 247 $ 224 10.3 % % Change Heating and Cooling Degree-Days 2024 2023 Normal From 2022 From Normal Heating Degree-Days 1,144 1,190 1,317 (3.9) % (13.1) % Cooling Degree-Days 78 72 53 8.3 % 47.2 % Twelve Months Ended December 31, 2024 and 2023 Electric Deliveries (in GWhs) Revenue (in millions) 2024 2023 % Change Weather- Normal % Change 2024 2023 % Change Electric Deliveries and Revenues (a) Residential 8,108 7,625 6.3 % (0.5) % $ 1,413 1,236 14.3 % Small commercial & industrial 1,119 1,071 4.5 % 0.9 % 184 176 4.5 % Large commercial & industrial 13,904 13,494 3.0 % 0.9 % 1,053 1,087 (3.1) % Public authorities & electric railroads 622 628 (1.0) % (1.2) % 37 34 8.8 % Other (b) — — n/a n/a 327 258 26.7 % Total electric revenues (c) 23,753 22,818 4.1 % 0.4 % 3,014 2,791 8.0 % Other Revenues (d) 25 33 (24.2) % Total Electric Revenues $ 3,039 $ 2,824 7.6 % Purchased Power $ 1,055 $ 974 8.3 % % Change Heating and Cooling Degree-Days 2024 2023 Normal From 2023 From Normal Heating Degree-Days 3,150 3,030 3,700 4.0 % (14.9) % Cooling Degree-Days 1,957 1,643 1,762 19.1 % 11.1 % Number of Electric Customers 2024 2023 Residential 877,916 866,018 Small commercial & industrial 54,036 54,142 Large commercial & industrial 23,068 22,941 Public authorities & electric railroads 207 208 Total 955,227 943,309 __________ (a) Reflects revenues from customers purchasing electricity directly from Pepco and customers purchasing electricity from a competitive electric generation supplier as all customers are assessed distribution charges. For customers purchasing electricity from Pepco, revenues also reflect the cost of energy and transmission. (b) Includes transmission revenue from PJM, wholesale electric revenue, and mutual assistance revenue. (c) Includes operating revenues from affiliates totaling $2 million and $4 million for the three months ended December 31, 2024 and 2023, respectively, and $7 million and $9 million for the twelve months ended December 31, 2024 and 2023, respectively. (d) Includes alternative revenue programs and late payment charge revenues. 15 Table of Contents DPL Statistics Three Months Ended December 31, 2024 and 2023 Electric and Natural Gas Deliveries Revenue (in millions) 2024 2023 % Change Weather - Normal % Change 2024 2023 % Change Electric (in GWhs) Electric Deliveries and Revenues (a) Residential 1,183 1,139 3.9 % 3.5 % $ 218 $ 201 8.5 % Small commercial & industrial 566 526 7.6 % 6.4 % 62 57 8.8 % Large commercial & industrial 1,007 994 1.3 % 1.5 % 32 28 14.3 % Public authorities & electric railroads 13 13 — % 1.2 % 5 5 — % Other (b) — — n/a n/a 72 64 12.5 % Total electric revenues (c) 2,769 2,672 3.6 % 3.3 % 389 355 9.6 % Other Revenues (d) (2) 5 (140.0) % Total Electric Revenues 387 360 7.5 % Natural Gas (in mmcfs) Natural Gas Deliveries and Revenues (e) Residential 2,649 2,544 4.1 % 6.7 % 36 34 5.9 % Small commercial & industrial 1,212 1,168 3.8 % 6.6 % 14 13 7.7 % Large commercial & industrial 433 420 3.1 % 3.2 % 1 1 — % Transportation 1,715 1,654 3.7 % 4.9 % 5 5 — % Other (g) — — n/a n/a 1 2 (50.0) % Total natural gas revenues 6,009 5,786 3.9 % 5.9 % 57 55 3.6 % Other Revenues (f) — — n/a Total Natural Gas Revenues 57 55 3.6 % Total Electric and Natural Gas Revenues $ 444 $ 415 7.0 % Purchased Power and Fuel $ 187 $ 176 6.3 % Electric Service Territory % Change Heating and Cooling Degree-Days 2024 2023 Normal From 2023 From Normal Heating Degree-Days 1,451 1,451 1,533 — % (5.3) % Cooling Degree-Days 23 32 35 (28.1) % (34.3) % Natural Gas Service Territory % Change Heating Degree-Days 2024 2023 Normal From 2023 From Normal Heating Degree-Days 1,480 1,540 1,638 (3.9) % (9.6) % 16 Table of Contents Twelve Months Ended December 31, 2024 and 2023 Electric and Natural Gas Deliveries Revenue (in millions) 2024 2023 % Change Weather - Normal % Change 2024 2023 % Change Electric (in GWhs) Electric Deliveries and Revenues (a) Residential 5,371 5,132 4.7 % 2.2 % $ 943 $ 827 14.0 % Small commercial & industrial 2,359 2,291 3.0 % 1.9 % 253 246 2.8 % Large commercial & industrial 4,122 4,132 (0.2) % (0.5) % 123 126 (2.4) % Public authorities & electric railroads 43 44 (2.3) % (2.2) % 17 16 6.3 % Other (b) — — n/a n/a 270 250 8.0 % Total rate-regulated electric revenues (c) 11,895 11,599 2.6 % 1.2 % 1,606 1,465 9.6 % Other Revenues (d) 1 18 (94.4) % Total Electric Revenues 1,607 1,483 8.4 % Natural Gas (in mmcfs) Natural Gas Deliveries and Revenues (e) Residential 7,810 7,326 6.6 % 0.9 % 108 122 (11.5) % Small commercial & industrial 3,801 3,660 3.9 % (1.9) % 43 53 (18.9) % Large commercial & industrial 1,674 1,588 5.4 % 5.4 % 5 4 25.0 % Transportation 6,206 6,004 3.4 % 1.6 % 17 16 6.3 % Other (f) — — n/a n/a 7 10 (30.0) % Total rate-regulated natural gas revenues 19,491 18,578 4.9 % 0.9 % 180 205 (12.2) % Other Revenues (d) — — n/a Total Natural Gas Revenues 180 205 (12.2) % Total Electric and Natural Gas Revenues $ 1,787 $ 1,688 5.9 % Purchased Power and Fuel $ 760 $ 737 3.1 % Electric Service Territory % Change Heating and Cooling Degree-Days 2024 2023 Normal From 2023 From Normal Heating Degree-Days 3,968 3,674 4,365 8.0 % (9.1) % Cooling Degree-Days 1,279 1,291 1,316 (0.9) % (2.8) % Natural Gas Service Territory % Change Heating Degree-Days 2024 2023 Normal From 2023 From Normal Heating Degree-Days 4,100 3,845 4,631 6.6 % (11.5) % Number of Electric Customers 2024 2023 Number of Natural Gas Customers 2024 2023 Residential 490,626 485,713 Residential 131,392 129,903 Small commercial & industrial 64,813 64,220 Small commercial & industrial 10,218 10,133 Large commercial & industrial 1,255 1,260 Large commercial & industrial 14 14 Public authorities & electric railroads 606 593 Transportation 162 163 Total 557,300 551,786 Total 141,786 140,213 __________ (a) Reflects delivery volumes and revenues from customers purchasing electricity directly from DPL and customers purchasing electricity from a competitive electric generation supplier as all customers are assessed distribution charges. For customers purchasing electricity from DPL, revenues also reflect the cost of energy and transmission. (b) Includes transmission revenue from PJM, wholesale electric revenue, and mutual assistance revenue. (c) Includes operating revenues from affiliates totaling $2 million and $3 million for the three months ended December 31, 2024 and 2023, and $7 million and $8 million for the twelve months ended December 31, 2024 and 2023, respectively. (d) Includes alternative revenue programs and late payment charges. (e) Reflects delivery volumes and revenues from customers purchasing natural gas directly from DPL and customers purchasing natural gas from a competitive natural gas supplier as all customers are assessed distribution charges. For customers purchasing natural gas from DPL, revenue also reflects the cost of natural gas. (f) Includes revenues primarily from off-system sales. 17 Table of Contents ACE Statistics Three Months Ended December 31, 2024 and 2023 Electric Deliveries (in GWhs) Revenue (in millions) 2024 2023 % Change Weather - Normal % Change 2024 2023 % Change Electric Deliveries and Revenues (a) Residential 789 892 (11.5) % (9.5) % $ 174 $ 182 (4.4) % Small commercial & industrial 405 324 25.0 % 25.7 % 57 49 16.3 % Large commercial & industrial 819 673 21.7 % 21.8 % 48 43 11.6 % Public authorities & electric railroads 15 10 50.0 % 34.6 % 5 4 25.0 % Other (b) — — n/a n/a 73 66 10.6 % Total electric revenues (c) 2,028 1,899 6.8 % 8.0 % 357 344 3.8 % Other Revenues (d) (9) 6 (250.0) % Total Electric Revenues $ 348 $ 350 (0.6) % Purchased Power $ 140 $ 144 (2.8) % % Change Heating and Cooling Degree-Days 2024 2023 Normal From 2023 From Normal Heating Degree-Days 1,483 1,485 1,547 (0.1) % (4.1) % Cooling Degree-Days 20 22 31 (9.1) % (35.5) % Twelve Months Ended December 31, 2024 and 2023 Electric Deliveries (in GWhs) Revenue (in millions) 2024 2023 % Change Weather - Normal % Change 2024 2023 % Change Electric Deliveries and Revenues (a) Residential 4,022 4,013 0.2 % (3.7) % $ 900 $ 782 15.1 % Small commercial & industrial 1,651 1,551 6.4 % 4.4 % 244 229 6.6 % Large commercial & industrial 3,167 3,128 1.2 % (0.1) % 196 207 (5.3) % Public authorities & electric railroads 47 44 6.8 % 7.1 % 20 17 17.6 % Other (b) — — n/a n/a 280 260 7.7 % Total electric revenues (c) 8,887 8,736 1.7 % (0.9) % 1,640 1,495 9.7 % Other Revenues (d) (12) 27 (144.4) % Total Electric Revenues $ 1,628 $ 1,522 7.0 % Purchased Power $ 698 $ 637 9.6 % % Change Heating and Cooling Degree-Days 2024 2023 Normal From 2023 From Normal Heating Degree-Days 4,168 4,043 4,528 3.1 % (8.0) % Cooling Degree-Days 1,262 1,029 1,215 22.6 % 3.9 % Number of Electric Customers 2024 2023 Residential 507,483 504,919 Small commercial & industrial 62,739 62,646 Large commercial & industrial 2,843 2,909 Public authorities & electric railroads 714 727 Total 573,779 571,201 __________ (a) Reflects delivery volumes and revenues from customers purchasing electricity directly from ACE and customers purchasing electricity from a competitive electric generation supplier as all customers are assessed distribution charges. For customers purchasing electricity from ACE, revenues also reflect the cost of energy and transmission. (b) Includes transmission revenue from PJM, wholesale electric revenue, and mutual assistance revenue. (c) Includes operating revenues from affiliates totaling less than $1 million for both the three months ended December 31, 2024 and 2023, respectively, and $2 million for both the twelve months ended December 31, 2024 and 2023. (d) Includes alternative revenue programs. 18

the item shown at left

other guidance in this release

Text is the filed exhibit, verbatim.