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EXC Atlantic City Electric

Filed: 5 May 21, 6:53am



Exhibit 99.1
News Release
exclogoa491.jpg
Contact:  Paul Adams
Corporate Communications
410-245-8717

Emily Duncan
Investor Relations
312-394-2345
EXELON REPORTS FIRST QUARTER 2021 RESULTS
Earnings Release Highlights
GAAP Net Loss of $(0.30) per share and Adjusted (non-GAAP) Operating Loss of $(0.06) per share for the first quarter of 2021
Affirming range for full year 2021 adjusted (non-GAAP) operating earnings guidance of $2.60-$3.00 per share
Strong utility reliability performance - all gas utilities achieved top decile in gas odor response and every utility achieved top quartile in outage frequency and outage duration
Generation’s nuclear fleet capacity factor was 95.3% (owned and operated units)
PECO filed an electric distribution rate case with the PAPUC in March and ComEd filed its annual distribution formula rate update with the ICC in April. Both cases are seeking an increase in electric distribution base rates to support investments that will enhance the reliability of the grid and enable the advancement of clean technologies and renewable energy.
CHICAGO (May 5, 2021) — Exelon Corporation (Nasdaq: EXC) today reported its financial results for the first quarter of 2021.
“Our utility businesses performed at a high level both financially and operationally during the first quarter, and we continue to invest in customer service and grid modernization across our six utilities,” said Christopher M. Crane, president and CEO of Exelon. “The generation business overall was strong, and we are implementing cost savings to offset losses from the unprecedented Texas storms. Looking ahead, we remain on track with the planned separation of our generation and utility businesses and are encouraged by growing momentum for federal and state clean energy policies that, if approved, will leave both standalone companies uniquely positioned to aid our nation’s transition to a carbon-free future.”

“Utility adjusted (non-GAAP) operating earnings was 11 cents per share higher than a year ago and ahead of plan, and excluding the storm impact, Exelon Generation would have earned adjusted (non-GAAP) operating earnings of 32 cents per share, which was in keeping with expectations,” said Joseph Nigro, senior executive vice president and CFO of Exelon. “The Texas storms and subsequent generation outages resulted in a 90 cents per share impact to operating earnings, though we expect to narrow some of that loss over the course of the year. The strong utility results and continued cost-savings measures at Generation
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reduced our adjusted (non-GAAP) operating loss for the quarter to $0.06 cents per share and we are affirming our full-year adjusted (non-GAAP) operating earnings guidance of $2.60 to $3.00 per share.”
First Quarter 2021
Exelon's GAAP Net Loss for the first quarter of 2021 decreased to $(0.30) per share from $0.60 GAAP Net Income per share in the first quarter of 2020. Adjusted (non-GAAP) Operating Loss for the first quarter of 2021 decreased to $(0.06) per share from $0.87 Adjusted (non-GAAP) Operating Earnings per share in the first quarter of 2020. For the reconciliations of GAAP Net Loss to Adjusted (non-GAAP) Operating Loss, refer to the tables beginning on page 6.
Adjusted (non-GAAP) Operating Loss in the first quarter of 2021 primarily reflect:
Lower Generation earnings primarily due to the impacts of the February 2021 extreme cold weather event; partially offset by
Higher utility earnings primarily due to higher electric distribution earnings at ComEd from higher rate base and higher allowed ROE due to an increase in treasury rates; the favorable impacts of the multi-year plan at BGE; regulatory rate increases at PHI; and favorable weather conditions at PECO and PHI.
Operating Company Results1
ComEd
ComEd's first quarter of 2021 GAAP Net Income increased to $197 million from $168 million in the first quarter of 2020. ComEd's Adjusted (non-GAAP) Operating Earnings for the first quarter of 2021 increased to $198 million from $168 million in the first quarter of 2020, primarily due to higher electric distribution earnings from higher rate base and higher allowed ROE due to an increase in treasury rates. Due to revenue decoupling, ComEd's distribution earnings are not affected by actual weather or customer usage patterns.
PECO
PECO’s first quarter of 2021 GAAP Net Income increased to $167 million from $140 million in the first quarter of 2020. PECO's Adjusted (non-GAAP) Operating Earnings for the first quarter of 2021 increased to $170 million from $140 million in the first quarter of 2020, primarily due to favorable weather conditions and favorable volume.
BGE
BGE’s first quarter of 2021 GAAP Net Income increased to $209 million from $181 million in the first quarter of 2020. BGE's Adjusted (non-GAAP) Operating Earnings increased to $211 million from $182 million in the first quarter of 2020, primarily due to the favorable impacts of the multi-year plan. Due to revenue decoupling, BGE's distribution earnings are not affected by actual weather or customer usage patterns.

___________
1Exelon’s five 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; 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; and Generation, which consists of owned and contracted electric generating facilities and wholesale and retail customer supply of electric and natural gas products and services, including renewable energy products and risk management services.

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PHI
PHI’s first quarter of 2021 GAAP Net Income increased to $128 million from $108 million in the first quarter of 2020. PHI’s Adjusted (non-GAAP) Operating Earnings for the first quarter of 2021 increased to $130 million from $110 million in the first quarter of 2020, primarily due to regulatory rate increases and favorable weather conditions in Delaware and New Jersey. Due to revenue decoupling, PHI's distribution earnings related to Pepco Maryland, DPL Maryland and Pepco District of Columbia are not affected by actual weather or customer usage patterns.
Generation
Generation had a GAAP Net Loss of $(793) million in the first quarter of 2021 compared with GAAP Net Income of $45 million in the first quarter of 2020. Generation had an Adjusted (non-GAAP) Operating Loss of $(571) million in the first quarter of 2021 compared with Adjusted (non-GAAP) Operating Earnings of $312 million in the first quarter of 2020, primarily due to the impacts of the February 2021 extreme cold weather event.
As of March 31, 2021, the percentage of expected generation hedged is 94%-97% for 2021.
Recent Developments and First Quarter Highlights
Planned Separation: On Feb. 25, 2021, Exelon and Generation filed applications with the Federal Energy Regulatory Commission (FERC), New York State Department of Public Service (NYPSC), and Nuclear Regulatory Commission (NRC) seeking approvals for the separation of Generation. On March 25, 2021, Exelon filed a request for a private letter ruling with the Internal Revenue Service (IRS) to confirm the tax-free treatment of the planned separation. Exelon and Generation expect a decision from the FERC and the IRS in the third quarter of 2021, the NRC in the fourth quarter of 2021, and have requested a decision from the NYPSC before the end of 2021 but cannot predict if the applications will be approved as filed. Exelon is targeting the completion of the separation in the first quarter of 2022.
Impacts of the February 2021 Extreme Cold Weather Event and Texas-based Generating Assets Outages: Beginning on Feb. 15, 2021, Generation’s Texas-based generating assets within the Electric Reliability Council of Texas (ERCOT) market, specifically Colorado Bend II, Wolf Hollow II, and Handley, experienced outages as a result of extreme cold weather conditions. In addition, those weather conditions drove increased demand for service, dramatically increased wholesale power prices, and also increased gas prices in certain regions. In response to the high demand and significantly reduced total generation on the system, the Public Utility Commission of Texas (PUCT) directed ERCOT to use an administrative price cap of $9,000 per megawatt hour during firm load shedding events.
The estimated impact to Exelon’s and Generation’s Net income for the first quarter of 2021 arising from these market and weather conditions was a reduction of approximately $880 million. The first quarter estimated impact includes certain charges associated with the natural gas business that may be reduced through waivers and/or recoveries from customers. Therefore, such charges are not included in the estimated full year earnings impact. Exelon and Generation estimate a reduction in Net income of approximately $670 million to $820 million for the full year 2021. The ultimate impact to Exelon’s and Generation’s consolidated financial statements may be affected by a number of factors, including final settlement data, the impacts of customer and counterparty credit losses, any state or federal solutions to address the financial challenges caused by the event, and related litigation and contract disputes. Various parties, including Generation, have filed requests with the PUCT to void the PUCT’s orders setting prices at $9,000 per megawatt hour during firm
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load shedding events and to enforce its order and reduce prices for 32 hours between February 18 and February 19 after firm load shedding ceased. Appeals of certain of the PUCT’s orders also have been filed in state court. Exelon and Generation cannot predict the outcome of these proceedings or the financial statement impact.
Exelon expects to offset between $410 million and $490 million of this impact for the full year 2021 primarily at Generation through a combination of enhanced revenue opportunities, deferral of selected non-essential maintenance, and primarily one-time cost savings.
ComEd Distribution Formula Rate: On April 16, 2021, ComEd filed its annual distribution formula rate update with the Illinois Commerce Commission (ICC). The ICC approval is due by December 2021 and the rates will take effect in January 2022. The filing request includes an increase of $40 million for the initial year revenue requirement for 2022 and an increase of $11 million related to the annual reconciliation for 2020. The revenue requirement for 2022 provides for a weighted average debt and equity return on distribution rate base of 5.72%, inclusive of an allowed ROE of 7.36%, reflecting the average monthly yields for 30-year treasury bonds plus 580 basis points. The reconciliation revenue requirement for 2020 provides for a weighted average debt and equity return on distribution rate base of 5.69%, inclusive of an allowed ROE of 7.29%, reflecting the average monthly yields for 30-year treasury bonds plus 580 basis points less a performance metrics penalty of 7 basis points.
PECO Pennsylvania Electric Distribution Rate Case: On March 30, 2021, PECO filed an application with the Pennsylvania Public Utility Commission (PAPUC) to increase its annual electric distribution rates by $246 million, reflecting an ROE of 10.95%. PECO currently expects a decision in the fourth quarter of 2021 but cannot predict if the PAPUC will approve the application as filed.
Nuclear Operations: Generation’s nuclear fleet, including its owned output from the Salem Generating Station and 100% of the CENG units, produced 43,466 gigawatt-hours (GWhs) in the first quarter of 2021, compared with 42,555 GWhs in the first quarter of 2020. Excluding Salem, the Exelon-operated nuclear plants at ownership achieved a 95.3% capacity factor for the first quarter of 2021, compared with 93.9% for the first quarter of 2020. The number of planned refueling outage days in the first quarter of 2021 totaled 84, compared with 94 in the first quarter of 2020. There were 3 non-refueling outage days in the first quarter of 2021 and 11 in the first quarter of 2020.
Fossil and Renewables Operations: The Dispatch Match rate for Generation’s gas and hydro fleet was 68.5% in the first quarter of 2021, compared with 98.2% in the first quarter of 2020. The lower performance in the quarter was attributed to unplanned outages at Texas-based generating assets during the February 2021 extreme cold-weather event.
Energy Capture for the wind and solar fleet was 96.4% in the first quarter of 2021, compared with 94.7% in the first quarter of 2020.





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Financing Activities:
On March 9, 2021, ComEd issued $700 million of its First Mortgage 3.13% Bonds, Series 130, due March 15, 2051. ComEd used the proceeds to repay existing indebtedness and for general corporate purposes.
On March 8, 2021, PECO issued $375 million of its First and Refunding Mortgage Bonds, 3.05% Series due March 15, 2051. PECO used the proceeds for general corporate purposes.
On March 30, 2021, Pepco issued $150 million of its First Mortgage Bonds, 2.32% Series due March 30, 2031. Pepco used the proceeds to repay existing indebtedness and for general corporate purposes.
On March 30, 2021, DPL issued $125 million of its First Mortgage Bonds, 3.24% Series due March 30, 2051. DPL used the proceeds to repay existing indebtedness and for general corporate purposes.
On March 10, 2021, ACE issued $350 million of its First Mortgage Bonds, 2.30% Series due March 15, 2031. ACE used the proceeds to repay existing indebtedness and for general corporate purposes.



















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GAAP/Adjusted (non-GAAP) Operating Earnings Reconciliation
Adjusted (non-GAAP) Operating Earnings (Loss) for the first quarter of 2021 do not include the following items (after tax) that were included in reported GAAP Net Income (Loss):
(in millions)Exelon
Earnings per
Diluted
Share
ExelonComEdPECOBGEPHIGeneration
2021 GAAP Net Income (Loss)$(0.30)$(289)$197 $167 $209 $128 $(793)
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $46 and $45, respectively)(0.14)(135)— — — — (134)
Unrealized Losses Related to Nuclear Decommissioning Trust (NDT) Fund Investments (net of taxes of $40)0.04 43 — — — — 43 
Plant Retirements and Divestitures (net of taxes of $103)0.32 310 — — — — 310 
Cost Management Program (net of taxes of $0)— — — — — 
Change in Environmental Liabilities (net of taxes of $1)— — — — — 
COVID-19 Direct Costs (net of taxes of $4, $1, $0, and $3, respectively)0.01 10 — — 
Acquisition Related Costs (net of taxes of $2)0.01 — — — — 
ERP System Implementation Costs (net of taxes of $1, $0, $0, $0, and $1, respectively)0.01 — 
Planned Separation Costs (net of taxes of $2,$0, $0, $0, and $1, respectively)0.01 — 
Income Tax-Related Adjustments (entire amount represents tax expense)— (2)— — — — — 
Noncontrolling Interests (net of taxes of $6)(0.02)(17)— — — — (17)
2021 Adjusted (non-GAAP) Operating Earnings (Loss)$(0.06)$(60)$198 $170 $211 $130 $(571)
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Adjusted (non-GAAP) Operating Earnings for the first quarter of 2020 do not include the following items (after tax) that were included in reported GAAP Net Income:
(in millions)Exelon
Earnings per
Diluted
Share
ExelonComEdPECOBGEPHIGeneration
2020 GAAP Net Income$0.60 $582 $168 $140 $181 $108 $45 
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $32 and $33, respectively)(0.10)(94)— — — — (97)
Unrealized Losses Related to NDT Fund Investments (net of taxes of $405)0.50 485 — — — — 485 
Asset Impairments (net of taxes of $1)— — — — — 
Plant Retirements and Divestitures (net of taxes of $4)0.01 13 — — — — 13 
Cost Management Program (net of taxes of $3, $0, $1, and $3, respectively)0.01 — — 
Income Tax-Related Adjustments (entire amount represents tax expense)— (2)— — — — — 
Noncontrolling Interests (net of taxes of $30)(0.15)(144)— — — — (144)
2020 Adjusted (non-GAAP) Operating Earnings$0.87 $851 $168 $140 $182 $110 $312 
Note:
Amounts may not sum due to rounding.
Unless otherwise noted, the income tax impact of each reconciling item between GAAP Net Income (Loss) and Adjusted (non-GAAP) Operating Earnings (Loss) 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 except the unrealized losses related to NDT fund investments, the marginal statutory income tax rates for 2021 and 2020 ranged from 25.0% to 29.0%. Under IRS regulations, NDT fund investment returns are taxed at different rates for investments if they are in qualified or non-qualified funds. The effective tax rates for the unrealized losses related to NDT fund investments were 48.0% and 45.5% for the three months ended March 31, 2021 and 2020, respectively.

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Webcast Information
Exelon will discuss first quarter 2021 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 Corporation (Nasdaq: EXC) is a Fortune 100 energy company with the largest number of electricity and natural gas customers in the U.S. Exelon does business in 48 states, the District of Columbia, and Canada and had 2020 revenue of $33 billion. Exelon serves approximately 10 million customers in Delaware, the District of Columbia, Illinois, Maryland, New Jersey, and Pennsylvania through its Atlantic City Electric, BGE, ComEd, Delmarva Power, PECO, and Pepco subsidiaries. Exelon is one of the largest competitive U.S. power generators, with more than 31,000 megawatts of nuclear, gas, wind, solar and hydroelectric generating capacity comprising one of the nation’s cleanest and lowest-cost power generation fleets. The company’s Constellation business unit provides energy products and services to approximately 2 million residential, public sector, and business customers, including three fourths of the Fortune 100. Follow Exelon on Twitter @Exelon.
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, 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. The Company 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: www.exeloncorp.com, and have been furnished to the Securities and Exchange Commission on Form 8-K on May 5, 2021.
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 including, among others, those related to the timing, manner, tax-free nature, and expected benefits associated with the potential separation of Exelon’s competitive power generation and customer-facing energy business from its six regulated electric and gas utilities. 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
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events and operational, economic, and financial performance, are intended to identify such forward-looking statements.
The factors that could cause actual results to differ materially from the forward-looking statements made by Exelon Corporation, Exelon Generation Company, LLC, 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) include those factors discussed herein, as well as the items discussed in (1) the Registrants' 2020 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 19, Commitments and Contingencies; (2) the Registrants' First Quarter 2021 Quarterly Report on Form 10-Q (to be filed on May 5, 2021) 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 14, 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. 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.

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Earnings Release Attachments
Table of Contents


Consolidating Statements of Operations
(unaudited)
(in millions)
 ComEdPECOBGEPHIGenerationOther (a)Exelon
Three Months Ended March 31, 2021
Operating revenues$1,535 $889 $974 $1,244 $5,559 $(311)$9,890 
Operating expenses
Purchased power and fuel527 316 331 479 4,610 (295)5,968 
Operating and maintenance316 234 197 256 1,001 (25)1,979 
Depreciation and amortization292 86 152 210 940 17 1,697 
Taxes other than income taxes75 43 72 113 121 14 438 
Total operating expenses1,210 679 752 1,058 6,672 (289)10,082 
Gain on sales of assets and businesses— — — — 71 — 71 
Operating income (loss)325 210 222 186 (1,042)(22)(121)
Other income and (deductions)
Interest expense, net(96)(38)(34)(67)(72)(79)(386)
Other, net17 167 21 225 
Total other income and (deductions)(89)(33)(26)(50)95 (58)(161)
Income (loss) before income taxes236 177 196 136 (947)(80)(282)
Income taxes39 10 (13)(179)116 (19)
Equity in losses of unconsolidated affiliates— — — — (1)— (1)
Net income (loss)197 167 209 128 (769)(196)(264)
Net income attributable to noncontrolling interests— — — — 24 25 
Net income (loss) attributable to common shareholders$197 $167 $209 $128 $(793)$(197)$(289)
Three Months Ended March 31, 2020
Operating revenues$1,439 $813 $937 $1,171 $4,733 $(346)$8,747 
Operating expenses
Purchased power and fuel486 283 288 435 2,704 (329)3,867 
Operating and maintenance317 217 188 257 1,263 (38)2,204 
Depreciation and amortization273 86 143 194 304 21 1,021 
Taxes other than income taxes75 39 69 114 129 11 437 
Total operating expenses1,151 625 688 1,000 4,400 (335)7,529 
Gain on sales of assets and businesses— — — — — 
Operating income (loss)288 188 249 173 333 (11)1,220 
Other income and (deductions)
Interest expense, net(94)(36)(32)(67)(109)(72)(410)
Other, net10 13 (771)15 (725)
Total other income and (deductions)(84)(33)(27)(54)(880)(57)(1,135)
Income (loss) before income taxes204 155 222 119 (547)(68)85 
Income taxes36 15 41 11 (389)(8)(294)
Equity in losses of unconsolidated affiliates— — — — (3)— (3)
Net income (loss)168 140 181 108 (161)(60)376 
Net loss attributable to noncontrolling interests— — — — (206)— (206)
Net income (loss) attributable to common shareholders$168 $140 $181 $108 $45 $(60)$582 
Change in Net income from 2020 to 2021$29 $27 $28 $20 $(838)$(137)$(871)
__________
(a)Other primarily includes eliminating and consolidating adjustments, Exelon’s corporate operations, shared service entities, and other financing and investment activities.
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Exelon
Consolidated Balance Sheets
(unaudited)
(in millions)
March 31, 2021December 31, 2020
Assets
Current assets
Cash and cash equivalents$1,908 $663 
Restricted cash and cash equivalents374 438 
Accounts receivable
Customer accounts receivable4,0173,597
Customer allowance for credit losses(442)(366)
Customer accounts receivable, net3,575 3,231 
Other accounts receivable1,3201,469
Other allowance for credit losses(79)(71)
Other accounts receivable, net1,241 1,398 
Mark-to-market derivative assets568 644 
Unamortized energy contract assets38 38 
Inventories, net
Fossil fuel and emission allowances205 297 
Materials and supplies1,427 1,425 
Regulatory assets1,269 1,228 
Renewable energy credits694 633 
Assets held for sale11 958 
Other1,687 1,609 
Total current assets12,997 12,562 
Property, plant, and equipment, net82,588 82,584 
Deferred debits and other assets
Regulatory assets8,810 8,759 
Nuclear decommissioning trust funds14,688 14,464 
Investments431 440 
Mark-to-market derivative assets6,677 6,677 
Unamortized energy contract assets491 555 
Pledged assets for Zion Station decommissioning285 294 
Total deferred debits and other assets3,033 2,982 
Total deferred debits and other assets34,415 34,171 
Total assets$130,000 $129,317 
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March 31, 2021December 31, 2020
Liabilities and shareholders’ equity
Current liabilities
Short-term borrowings$3,128 $2,031 
Long-term debt due within one year2,281 1,819 
Accounts payable3,430 3,562 
Accrued expenses1,729 2,078 
Payables to affiliates
Regulatory liabilities663 581 
Mark-to-market derivative liabilities422 295 
Unamortized energy contract liabilities98 100 
Renewable energy credit obligation645 661 
Liabilities held for sale375 
Other1,176 1,264 
Total current liabilities13,580 12,771 
Long-term debt36,248 35,093 
Long-term debt to financing trusts390 390 
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits13,129 13,035 
Asset retirement obligations12,405 12,300 
Pension obligations3,951 4,503 
Non-pension postretirement benefit obligations1,988 2,011 
Spent nuclear fuel obligation1,208 1,208 
Regulatory liabilities9,130 9,485 
Mark-to-market derivative liabilities453 473 
Unamortized energy contract liabilities217 238 
Other2,988 2,942 
Total deferred credits and other liabilities45,469 46,195 
Total liabilities95,687 94,449 
Commitments and contingencies
Shareholders’ equity
Common stock19,412 19,373 
Treasury stock, at cost(123)(123)
Retained earnings16,072 16,735 
Accumulated other comprehensive loss, net(3,346)(3,400)
Total shareholders’ equity32,015 32,585 
Noncontrolling interests2,298 2,283 
Total equity34,313 34,868 
Total liabilities and shareholders’ equity$130,000 $129,317 
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Exelon
Consolidated Statements of Cash Flows
(unaudited)
(in millions)
Three Months Ended March 31,
 20212020
Cash flows from operating activities
Net (loss) income$(264)$376 
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization2,104 1,378 
Asset impairments
Gain on sales of assets and businesses(71)— 
Deferred income taxes and amortization of investment tax credits(142)(245)
Net fair value changes related to derivatives(178)(132)
Net realized and unrealized (gains) losses on NDT funds(118)651 
Unrealized loss on equity investments23 — 
Other non-cash operating activities(170)273 
Changes in assets and liabilities:
Accounts receivable(372)800 
Inventories77 81 
Accounts payable and accrued expenses(176)(976)
Option premiums received (paid), net16 (38)
Collateral received (posted), net273 (21)
Income taxes113 (56)
Pension and non-pension postretirement benefit contributions(537)(531)
Other assets and liabilities(1,840)(488)
Net cash flows (used in) provided by operating activities(1,261)1,080 
Cash flows from investing activities
Capital expenditures(2,140)(2,016)
Proceeds from NDT fund sales2,908 1,183 
Investment in NDT funds(2,939)(1,234)
Collection of DPP1,574 — 
Proceeds from sales of assets and businesses680 — 
Other investing activities12 (8)
Net cash flows provided by (used in) investing activities95 (2,075)
Cash flows from financing activities
Changes in short-term borrowings597 109 
Proceeds from short-term borrowings with maturities greater than 90 days500 500 
Issuance of long-term debt1,705 2,652 
Retirement of long-term debt(79)(1,032)
Dividends paid on common stock(374)(373)
Proceeds from employee stock plans31 30 
Other financing activities(46)(21)
Net cash flows provided by financing activities2,334 1,865 
Increase in cash, restricted cash, and cash equivalents1,168 870 
Cash, restricted cash, and cash equivalents at beginning of period1,166 1,122 
Cash, restricted cash, and cash equivalents at end of period$2,334 $1,992 
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Exelon
Reconciliation of GAAP Net Income to Adjusted (non-GAAP) Operating Earnings and Analysis of Earnings
Three Months Ended March 31, 2021 and 2020
(unaudited)
(in millions, except per share data)
Exelon
Earnings 
per Diluted
Share
ComEdPECOBGEPHIGenerationOther (a)Exelon
2020 GAAP Net Income (Loss)$0.60 $168 $140 $181 $108 $45 $(60)$582 
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $33, $1, and $32, respectively)(0.10)— — — — (97)(94)
Unrealized Losses Related to NDT Fund Investments (net of taxes of $405) (1)0.50 — — — — 485 — 485 
Asset Impairments (net of taxes of $1)— — — — — — 
Plant Retirements and Divestitures (net of taxes of $4) (2)0.01 — — — — 13 — 13 
Cost Management Program (net of taxes of $0, $1, $3, $1, and $3, respectively) (3)0.01 — — (2)
Income Tax-Related Adjustments (entire amount represents tax expense)— — — — — — (2)(2)
Noncontrolling Interests (net of taxes of $30) (4)(0.15)— — — — (144)— (144)
2020 Adjusted (non-GAAP) Operating Earnings (Loss)0.87 168 140 182 110 312 (61)851 
Year Over Year Effects on Adjusted (non-GAAP) Operating Earnings:
ComEd, PECO, BGE and PHI:
Weather0.04 — (b)26 — (b)(b)— — 35 
Load0.01 — (b)10 — (b)(b)— — 12 
Other Energy Delivery (9)0.04 39 (c)(6)(c)(4)(c)(c)— — 38 
Generation, Excluding Mark-to-Market:
Nuclear Volume (10)0.01 — — — — 11 — 11 
Nuclear Fuel Cost (11)0.01 — — — — — 
Capacity Revenue (12)0.02 — — — — 16 — 16 
Market and Portfolio Conditions (13)(0.85)— — — — (833)— (833)
Operating and Maintenance Expense:
Labor, Contracting and Materials (14)0.01 (6)(6)— (1)19 — 
Planned Nuclear Refueling Outages (15)0.04 — — — — 36 — 36 
Pension and Non-Pension Postretirement Benefits— (1)— — — 
Other Operating and Maintenance (16)(0.02)(4)(5)— (15)(15)
Depreciation and Amortization Expense (17)(0.03)(14)— (7)(12)(2)(32)
Interest Expense, Net(0.02)(3)(1)(1)— (14)(18)
Income Taxes (18)(0.19)12 46 (138)(125)(189)
Noncontrolling Interests (19)(0.06)— — — — (57)— (57)
Other (20)0.07 (1)(1)— 73 (1)73 
Total Year Over Year Effects on Adjusted (non-GAAP) Operating Earnings(0.93)30 30 29 20 (883)(136)(910)
2021 GAAP Net Income (Loss)(0.30)197 167 209 128 (793)(197)(289)
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $45, $1, and $46, respectively)(0.14)— — — — (134)(1)(135)
Unrealized Losses Related to NDT Fund Investments (net of taxes of $40) (1)0.04 — — — — 43 — 43 
Plant Retirements and Divestitures (net of taxes of $103) (2)0.32 — — — — 310 — 310 
Cost Management Program (net of taxes of $0)— — — — — — 
Change in Environmental Liabilities (net of taxes of $1)— — — — — 
COVID-19 Direct Costs (net of taxes of $1, $0, $3, and $4, respectively) (5)0.01 — — — 10 
Acquisition Related Costs (net of tax of $2) (6)0.01 — — — — — 
ERP System Implementation Costs (net of taxes of $0, $0, $0 ,$1, and $1, respectively) (7)0.01 — — 
Planned Separation Costs (net of taxes of $0, $0, $0, $1, $1, and $2, respectively) (8)0.01 — 
Income Tax-Related Adjustments (entire amount represents tax expense)— — — — — — (2)(2)
Noncontrolling Interests (net of taxes of $6) (4)(0.02)— — — — (17)— (17)
2021 Adjusted (non-GAAP) Operating Earnings (Loss)$(0.06)$198 $170 $211 $130 $(571)$(197)$(60)
6

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 except the unrealized losses related to NDT fund investments, the marginal statutory income tax rates for 2021 and 2020 ranged from 25.0% to 29.0%. Under IRS regulations, NDT fund investment returns are taxed at different rates for investments if they are in qualified or non-qualified funds. The effective tax rates for the unrealized losses related to NDT fund investments were 48.0% and 45.5% for the three months ended March 31, 2021 and 2020, respectively.
(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, and DPL Maryland, customer rates are adjusted to eliminate the impacts of weather and customer usage on distribution volumes.
(c)For regulatory recovery mechanisms, including ComEd’s distribution formula rate, ComEd, PECO, BGE, and PHI utilities transmission formula rates, and riders across all 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)Reflects the impact of net unrealized losses on Generation’s NDT fund investments for Non-Regulatory and Regulatory Agreement Units. The impacts of the Regulatory Agreement Units, including the associated income taxes, are contractually eliminated, resulting in no earnings impact.
(2)In 2020, primarily reflects accelerated depreciation and amortization expenses associated with the early retirement of certain fossil sites. In 2021, primarily reflects accelerated depreciation and amortization associated with Generation's decision in the third quarter of 2020 to early retire Byron and Dresden nuclear facilities in 2021 and Mystic Units 8 and 9 in 2024, partially offset by a gain on sale of Generation's solar business.
(3)Primarily represents reorganization costs related to cost management programs.
(4)Represents elimination from Generation’s results of the noncontrolling interests related to certain exclusion items, primarily related to unrealized gains and losses on NDT fund investments for CENG units.
(5)Represents direct costs related to COVID-19 consisting primarily of costs to acquire personal protective equipment, costs for cleaning supplies and services, and costs to hire healthcare professionals to monitor the health of employees.
(6)Reflects costs related to the acquisition of Electricite de France SA's (EDF's) interest in CENG.
(7)Reflects costs related to a multi-year Enterprise Resource Program (ERP) system implementation.
(8)Represents costs related to the planned separation primarily comprised of third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the planned separation as well as employee-related severance costs.
(9)For ComEd, reflects increased electric distribution and energy efficiency revenues (due to higher rate base, higher electric distribution ROE due to increased treasury rates, and higher fully recoverable costs). For PHI, reflects increased revenue primarily due to rate increases.
(10)Primarily reflects a decrease in nuclear outage days.
(11)Primarily reflects a decrease in fuel prices.
(12)Reflects increased capacity revenues in the Mid-Atlantic, Midwest, and New York, partially offset by decreased revenues in Other Power Regions.
(13)Primarily reflects the impacts of the February 2021 extreme cold weather event.
(14)For Generation, primarily reflects lower contracting costs.
(15)Primarily reflects a decrease in the number of nuclear outage days in 2021, excluding Salem.
(16)For Generation, reflects increased credit loss expense primarily due to the impacts of the February 2021 extreme cold weather event.
(17)Reflects ongoing capital expenditures across all utilities. For ComEd, also reflects increased amortization of deferred energy efficiency costs pursuant to FEJA and increased amortization related to the August 2020 storm regulatory asset.
(18)For BGE, primarily due to the multi-year plan which resulted in the acceleration of certain income tax benefits. For Generation and Corporate, primarily reflects the timing of tax expense driven primarily by the loss before income taxes at Generation due to the February 2021 extreme cold weather event. These timing impacts will reverse by the end of the year. For Generation, also reflects the absence of a prior year one-time tax settlement.
(19)Reflects elimination from Generation’s results of activity attributable to noncontrolling interests, primarily for CENG.
(20)For Generation, primarily reflects higher realized NDT fund gains, partially offset by net unrealized losses on equity investments that became publicly traded entities in the fourth quarter of 2020 and the first quarter of 2021.
7


Exelon
GAAP Consolidated Statements of Operations and
Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments
(unaudited)
(in millions, except per share data)
Three Months Ended
March 31, 2021
Three Months Ended
March 31, 2020
GAAP (a)Non-GAAP AdjustmentsGAAP (a)Non-GAAP Adjustments
Operating revenues$9,890 $83 (b)$8,747 $(179)(b)
Operating expenses
Purchased power and fuel5,968 204 (b),(c)3,867 (48)(b)
Operating and maintenance1,979 173 (c),(d),(e),(f),(g),(h),(i)2,204 (21)(c),(d),(l)
Depreciation and amortization1,697 (642)(c)1,021 (10)(c)
Taxes other than income taxes438 — 437 — 
Total operating expenses10,082 7,529 
Gain on sales of assets and businesses71 (68)(c)— 
Operating (loss) income(121)1,220 
Other income and (deductions)
Interest expense, net(386)(3)(b)(410)16 (b)
Other, net225 80 (b),(j)(725)879 (b),(j)
Total other income and (deductions)(161)(1,135)
(Loss) income before income taxes(282)85 
Income taxes(19)109 (b),(c),(e),(f),(g),(h),(i),(j)(294)382 (b),(c),(d),(j),(l)
Equity in losses of unconsolidated affiliates(1)— (3)— 
Net (loss) income(264)376 
Net income (loss) attributable to noncontrolling interests25 18 (k)(206)144 (k)
Net income (loss) attributable to common shareholders$(289)$582 
Effective tax rate(m)
6.7 %(345.9)%
Earnings per average common share
Basic$(0.30)$0.60 
Diluted$(0.30)$0.60 
Average common shares outstanding
Basic977 975 
Diluted977 976 
__________
(a)Results reported in accordance with accounting principles generally accepted in the United States (GAAP).
(b)Adjustment to exclude the mark-to-market impact of Exelon’s economic hedging activities, net of intercompany eliminations.
(c)In 2021, adjustment to exclude accelerated depreciation and amortization associated with Generation's decision in the third quarter of 2020 to early retire Byron and Dresden nuclear facilities in 2021 and Mystic Units 8 and 9 in 2024, partially offset by a gain on sale of Generation's solar business. In 2020, adjustment to exclude accelerated depreciation and amortization expenses associated with the early retirement of certain fossil sites.
(d)Adjustment to exclude reorganization related to cost management programs.
(e)Adjustment to exclude costs related to the acquisition of Electricite de France SA's (EDF's) interest in CENG.
(f)Adjustment to exclude changes in environmental liabilities.
(g)Adjustment to exclude direct costs related to COVID-19 consisting primarily of costs to acquire personal protective equipment, costs for cleaning supplies and services, and costs to hire healthcare professionals to monitor the health of employees.
(h)Adjustment to exclude costs related to the planned separation primarily comprised of third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the planned separation as well as employee-related severance costs.
(i)Adjustment to exclude costs related to a multi-year Enterprise Resource Program (ERP) system implementation.
(j)Adjustment to exclude the impact of net unrealized losses on Generation’s NDT fund investments for Non-Regulatory and Regulatory Agreement Units. The impacts of the Regulatory Agreement Units, including the associated income taxes, are contractually eliminated, resulting in no earnings impact.
(k)Adjustment to exclude elimination from Generation’s results of the noncontrolling interests related to certain exclusion items, primarily related to unrealized gains and losses on NDT fund investments for CENG units.
(l)Adjustment to exclude certain asset impairments.
(m)The effective tax rate related to Adjusted (non-GAAP) Operating Earnings is 120.0% and 10.0% for the three months ended March 31, 2021 and 2020, respectively.
8

ComEd
GAAP Consolidated Statements of Operations and
Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments
(unaudited)
(in millions)
 Three Months Ended
March 31, 2021
Three Months Ended
March 31, 2020
 GAAP (a)Non-GAAP AdjustmentsGAAP (a)Non-GAAP Adjustments
Operating revenues$1,535 $— $1,439 $— 
Operating expenses
Purchased power and fuel527 — 486 — 
Operating and maintenance316 (1)(b)317 — 
Depreciation and amortization292 — 273 — 
Taxes other than income taxes75 — 75 — 
Total operating expenses1,210 1,151 
Operating income325 288 
Other income and (deductions)
Interest expense, net(96)— (94)— 
Other, net— 10 — 
Total other income and (deductions)(89)(84)
Income before income taxes236 204 
Income taxes39 — 36 — 
Net income$197 $168 
__________
(a)Results reported in accordance with accounting principles generally accepted in the United States (GAAP).
(b)Adjustment to exclude costs related to the planned separation primarily comprised of third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the planned separation as well as employee-related severance costs.
9

PECO
GAAP Consolidated Statements of Operations and
Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments
(unaudited)
(in millions)
 Three Months Ended
March 31, 2021
Three Months Ended
March 31, 2020
 GAAP (a)Non-GAAP AdjustmentsGAAP (a)Non-GAAP Adjustments 
Operating revenues$889 $— $813 $—  
Operating expenses
Purchased power and fuel316 — 283 —  
Operating and maintenance234 (4)(b)217 — 
Depreciation and amortization86 — 86 —  
Taxes other than income taxes43 — 39 —  
Total operating expenses679 625 
Operating income210 188  
Other income and (deductions)
Interest expense, net(38)— (36)—  
Other, net— —  
Total other income and (deductions)(33)(33) 
Income before income taxes177 155  
Income taxes10 (b)15 — 
Net income$167 $140  
__________
(a)Results reported in accordance with accounting principles generally accepted in the United States (GAAP).
(b)Adjustment to exclude reorganization costs related to cost management programs and direct costs related to COVID-19 consisting primarily of costs to acquire personal protective equipment, costs for cleaning supplies and services, and costs to hire healthcare professionals to monitor the health of employees.
10

BGE
GAAP Consolidated Statements of Operations and
Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments
(unaudited)
(in millions)
 Three Months Ended
March 31, 2021
Three Months Ended
March 31, 2020
 GAAP (a)Non-GAAP AdjustmentsGAAP (a)Non-GAAP Adjustments 
Operating revenues$974 $— $937 $—  
Operating expenses
Purchased power and fuel331 — 288 —  
Operating and maintenance197 (3)(b),(c)188 (1)(d)
Depreciation and amortization152 — 143 —  
Taxes other than income taxes72 — 69 —  
Total operating expenses752 688  
Operating income222 249 
Other income and (deductions)
Interest expense, net(34)— (32)—  
Other, net— —  
Total other income and (deductions)(26)(27) 
Income before income taxes196 222 
Income taxes(13)(b),(c)41 — 
Net income$209 $181 
__________
(a)Results reported in accordance with accounting principles generally accepted in the United States (GAAP).
(b)Adjustment to exclude direct costs related to COVID-19 consisting primarily of costs to acquire personal protective equipment, costs for cleaning supplies and services, and costs to hire healthcare professionals to monitor the health of employees.
(c)Adjustment to exclude costs related to a multi-year Enterprise Resource Program (ERP) system implementation.
(d)Adjustment to exclude reorganization costs related to cost management programs.

11

PHI
GAAP Consolidated Statements of Operations and
Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments
(unaudited)
(in millions)
 Three Months Ended
March 31, 2021
Three Months Ended
March 31, 2020
 GAAP (a)Non-GAAP AdjustmentsGAAP (a)Non-GAAP Adjustments
Operating revenues$1,244 $— $1,171 $— 
Operating expenses
Purchased power and fuel479 — 435 — 
Operating and maintenance256 (3)(b),(c)257 (3)(d)
Depreciation and amortization210 — 194 — 
Taxes other than income taxes113 — 114 — 
Total operating expenses1,058 1,000 
Gain on sales of assets— — — 
Operating income186 173 
Other income and (deductions)
Interest expense, net(67)— (67)— 
Other, net17 — 13 — 
Total other income and (deductions)(50)(54)
Income before income taxes136 119 
Income taxes(b),(c)11 (d)
Net income$128 $108 
__________
(a)Results reported in accordance with accounting principles generally accepted in the United States (GAAP).
(b)Adjustment to exclude costs related to a multi-year Enterprise Resource Program (ERP) system implementation.
(c)Adjustment to exclude costs related to the planned separation primarily comprised of third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the planned separation as well as employee-related severance costs.
(d)Adjustment to exclude reorganization costs related to cost management programs.


12

Generation
GAAP Consolidated Statements of Operations and
Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments
(unaudited)
(in millions)
 Three Months Ended
March 31, 2021
Three Months Ended
March 31, 2020
 GAAP (a)Non-GAAP Adjustments GAAP (a)Non-GAAP Adjustments 
Operating revenues$5,559 $83 (b)$4,733 $(179)(b)
Operating expenses
Purchased power and fuel4,610 204 (b),(c)2,704 (48)(b)
Operating and maintenance1,001 186 (c),(d),(e),(f),(g),(h),(i)1,263 (20)(c),(d),(l)
Depreciation and amortization940 (642)(c)304 (10)(c)
Taxes other than income taxes121 — 129 — 
Total operating expenses6,672 4,400 
Gain on sales of assets and businesses71 (68)(c)— — 
Operating income (loss)(1,042)333 
Other income and (deductions)
Interest expense, net(72)(3)(b)(109)12 (b)
Other, net167 82 (j)(771)879 (b),(j)
Total other income and (deductions)95 (880)
Income (loss) before income taxes(947)(547)
Income taxes(179)105 (b),(c),(e),(f),(g),(h),(i),(j)(389)379 (b),(c),(d).(j),(l)
Equity in losses of unconsolidated affiliates(1)— (3)— 
Net income (loss)(769)(161)
Net (loss) income attributable to noncontrolling interests24 18 (k)(206)144 (k)
Net income (loss) attributable to membership interest$(793)$45  
__________
(a)Results reported in accordance with accounting principles generally accepted in the United States (GAAP).
(b)Adjustment to exclude the mark-to-market impact of Exelon’s economic hedging activities, net of intercompany eliminations.
(c)In 2021, adjustment to exclude accelerated depreciation and amortization associated with Generation's decision in the third quarter of 2020 to early retire Byron and Dresden nuclear facilities in 2021 and Mystic Units 8 and 9 in 2024, partially offset by a gain on sale of Generation's solar business. In 2020, adjustment to exclude accelerated depreciation and amortization expenses associated with the early retirement of certain fossil sites.
(d)Adjustment to exclude reorganization costs related to cost management programs.
(e)Adjustment to exclude costs related to the acquisition of Electricite de France SA's (EDF's) interest in CENG.
(f)Adjustment to exclude changes in environmental liabilities.
(g)Adjustment to exclude direct costs related to COVID-19 consisting primarily of costs to acquire personal protective equipment, costs for cleaning supplies and services, and costs to hire healthcare professionals to monitor the health of employees.
(h)Adjustment to exclude costs related to the planned separation primarily comprised of third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the planned separation as well as employee-related severance costs.
(i)Adjustment to exclude costs related to a multi-year Enterprise Resource Program (ERP) system implementation.
(j)Adjustment to exclude the impact of net unrealized losses on Generation’s NDT fund investments for Non-Regulatory and Regulatory Agreement Units. The impacts of the Regulatory Agreement Units, including the associated income taxes, are contractually eliminated, resulting in no earnings impact.
(k)Adjustment to exclude elimination from Generation’s results of the noncontrolling interests related to certain exclusion items, primarily related to unrealized gains and losses on NDT fund investments for CENG units.
(l)Adjustment to exclude certain asset impairments.

13

Other (a)
GAAP Consolidated Statements of Operations and
Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments
(unaudited)
(in millions)
 Three Months Ended
March 31, 2021
Three Months Ended
March 31, 2020
 GAAP (b)Non-GAAP Adjustments GAAP (b)Non-GAAP Adjustments 
Operating revenues$(311)$—  $(346)$— 
Operating expenses
Purchased power and fuel(295)— (329)— 
Operating and maintenance(25)(2)(c)(38)(f)
Depreciation and amortization17 — 21 — 
Taxes other than income taxes14 — 11 — 
Total operating expenses(289)(335)
Operating loss(22)(11)
Other income and (deductions)
Interest expense, net(79)— (72)(d)
Other, net21 (2)(d)15 — 
Total other income and (deductions)(58)(57)
Loss before income taxes(80)(68)
Income taxes116 (c),(d),(e)(8)(d),(e),(f)
Net loss(196)(60)
Net income attributable to noncontrolling interests— 
Net loss attributable to common shareholders$(197) $(60) 
__________
(a)Other primarily includes eliminating and consolidating adjustments, Exelon’s corporate operations, shared service entities, and other financing and investment activities.
(b)Results reported in accordance with accounting principles generally accepted in the United States (GAAP).
(c)Adjustment to exclude costs related to the planned separation primarily comprised of third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the planned separation as well as employee-related severance costs.
(d)Adjustment to exclude the mark-to-market impact of Exelon’s economic hedging activities, net of intercompany eliminations.
(e)Adjustment to exclude income tax-related adjustments.
(f)Adjustment to exclude reorganization related to cost management programs.


14


ComEd Statistics
Three Months Ended March 31, 2021 and 2020
 Electric Deliveries (in GWhs)Revenue (in millions)
 20212020% ChangeWeather - Normal % Change20212020% Change
Rate-Regulated Deliveries and Revenues(a)
Residential6,685 6,237 7.2 %3.7 %$741 $701 5.7 %
Small commercial & industrial7,266 7,570 (4.0)%(5.8)%367 362 1.4 %
Large commercial & industrial6,479 6,723 (3.6)%(5.1)%134 134 — %
Public authorities & electric railroads267 294 (9.2)%(11.4)%11 13 (15.4)%
Other(b)
— — n/an/a220 211 4.3 %
Total rate-regulated electric revenues(c)
20,697 20,824 (0.6)%(2.8)%1,473 1,421 3.7 %
Other Rate-Regulated Revenues(d)
62 18 244.4 %
Total Electric Revenues$1,535 $1,439 6.7 %
Purchased Power$527 $486 8.4 %
   % Change
Heating and Cooling Degree-Days20212020NormalFrom 2020From Normal
Heating Degree-Days2,989 2,758 3,141 8.4 %(4.8)%

Number of Electric Customers20212020
Residential3,696,208 3,676,312 
Small commercial & industrial388,483 386,012 
Large commercial & industrial1,863 1,954 
Public authorities & electric railroads4,876 4,857 
Total4,091,430 4,069,135 
__________
(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 $6 million and $5 million for the three months ended March 31, 2021 and 2020, respectively..
(d)Includes alternative revenue programs and late payment charges.
15


PECO Statistics
Three Months Ended March 31, 2021 and 2020
Electric and Natural Gas DeliveriesRevenue (in millions)
20212020% ChangeWeather-
Normal
% Change
20212020% Change
Electric (in GWhs)
Rate-Regulated Electric Deliveries and Revenues(a)
Residential3,767 3,254 15.8 %6.2 %$433 $382 13.4 %
Small commercial & industrial1,881 1,905 (1.3)%(5.1)%100 99 1.0 %
Large commercial & industrial3,272 3,421 (4.4)%(5.0)%57 53 7.5 %
Public authorities & electric railroads149 151 (1.3)%(1.4)%28.6 %
Other(b)
— — n/an/a52 58 (10.3)%
Total rate-regulated electric revenues(c)
9,069 8,731 3.9 %(0.6)%651 599 8.7 %
Other Rate-Regulated Revenues(d)
10 100.0 %
Total Electric Revenues661 604 9.4 %
Natural Gas (in mmcfs)
Rate-Regulated Natural Gas Deliveries and Revenues(e)
Residential20,674 17,282 19.6 %2.8 %160 150 6.7 %
Small commercial & industrial10,170 8,809 15.5 %(0.2)%59 51 15.7 %
Large commercial & industrial(22.2)%(0.6)%— — N/A
Transportation7,650 7,135 7.2 %0.4 %16.7 %
Other(f)
— — n/an/a100.0 %
Total rate-regulated natural gas revenues(g)
38,501 33,235 15.8 %1.5 %228 208 9.6 %
Other Rate-Regulated Revenues(d)
— 100.0 %
Total Natural Gas Revenues228 209 9.1 %
Total Electric and Natural Gas Revenues$889 $813 9.3 %
Purchased Power and Fuel$316 $283 11.7 %
% Change
Heating and Cooling Degree-Days20212020NormalFrom 2020From Normal
Heating Degree-Days2,302 1,989 2,418 15.7 %(4.8)%
Cooling Degree-Days— n/a400.0 %
Number of Electric Customers20212020Number of Natural Gas Customers20212020
Residential1,512,255 1,499,019 Residential493,857 489,063 
Small commercial & industrial154,637 154,056 Small commercial & industrial44,604 44,509 
Large commercial & industrial3,109 3,093 Large commercial & industrial
Public authorities & electric railroads10,237 10,096 Transportation685 727 
Total1,680,238 1,666,264 Total539,151 534,304 
__________
(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 $1 million and $2 million for the three months ended March 31, 2021 and 2020, 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 less than $1 million and less than $1 million for the three months ended March 31, 2021 and 2020, respectively.
16


BGE Statistics
Three Months Ended March 31, 2021 and 2020
Electric and Natural Gas DeliveriesRevenue (in millions)
20212020% ChangeWeather-
Normal
% Change
20212020% Change
Electric (in GWhs)
Rate-Regulated Electric Deliveries and Revenues(a)
Residential3,538 3,118 13.5 %4.0 %$362 $339 6.8 %
Small commercial & industrial723 707 2.3 %(4.4)%69 67 3.0 %
Large commercial & industrial3,109 3,122 (0.4)%(4.9)%105 103 1.9 %
Public authorities & electric railroads48 60 (20.0)%(16.8)%— %
Other(b)
— — n/an/a77 79 (2.5)%
Total rate-regulated electric revenues(c)
7,418 7,007 5.9 %(0.8)%620 595 4.2 %
Other Rate-Regulated Revenues(d)
12 18 (33.3)%
Total Electric Revenues632 613 3.1 %
Natural Gas (in mmcfs)
Rate-Regulated Natural Gas Deliveries and Revenues(e)
Residential18,451 18,610 (0.9)%(15.6)%216 206 4.9 %
Small commercial & industrial4,019 4,147 (3.1)%(14.3)%35 34 2.9 %
Large commercial & industrial14,039 12,323 13.9 %2.1 %54 51 5.9 %
Other(f)
7,610 3,301 130.5 %n/a31 244.4 %
Total rate-regulated natural gas revenues(g)
44,119 38,381 15.0 %(9.7)%336 300 12.0 %
Other Rate-Regulated Revenues(d)
24 (75.0)%
Total Natural Gas Revenues342 324 5.6 %
Total Electric and Natural Gas Revenues$974 $937 3.9 %
Purchased Power and Fuel$331 $288 14.9 %
   % Change
Heating Degree-Days20212020NormalFrom 2020From Normal
Heating Degree-Days2,197 1,879 2,387 16.9 %(8.0)%
Number of Electric Customers20212020Number of Natural Gas Customers20212020
Residential1,192,470 1,181,329 Residential648,824 641,608 
Small commercial & industrial114,819 114,697 Small commercial & industrial38,318 38,381 
Large commercial & industrial12,505 12,376 Large commercial & industrial6,120 6,078 
Public authorities & electric railroads266 265 Total693,262 686,067 
Total1,320,060 1,308,667 
__________
(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 $2 million and $3 million for the three months ended March 31, 2021 and 2020, 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 $4 million and $3 million for the three months ended March 31, 2021 and 2020, respectively.
17

Pepco Statistics
Three Months Ended March 31, 2021 and 2020
Electric Deliveries (in GWhs)Revenue (in millions)
20212020% ChangeWeather-
Normal
% Change
20212020% Change
Rate-Regulated Deliveries and Revenues(a)
Residential2,219 1,946 14.0 %3.1 %$253 $236 7.2 %
Small commercial & industrial298 315 (5.4)%(8.8)%33 35 (5.7)%
Large commercial & industrial3,054 3,272 (6.7)%(8.0)%184 188 (2.1)%
Public authorities & electric railroads124 204 (39.2)%(40.0)%(33.3)%
Other(b)
— — n/an/a51 60 (15.0)%
Total rate-regulated electric revenues(c)
5,695 5,737 (0.7)%(5.1)%527 528 (0.2)%
Other Rate-Regulated Revenues(d)
26 16 62.5 %
Total Electric Revenues$553 $544 1.7 %
Purchased Power$166 $164 1.2 %
   % Change
Heating and Cooling Degree-Days20212020NormalFrom 2020From Normal
Heating Degree-Days2,012 1,679 2,124 19.8 %(5.3)%
Cooling Degree-Days40.0 %133.3 %
Number of Electric Customers20212020
Residential835,415 820,283 
Small commercial & industrial53,738 54,304 
Large commercial & industrial22,492 22,248 
Public authorities & electric railroads174 169 
Total911,819 897,004 
__________
(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 $1 million for both the three months ended March 31, 2021 and 2020.
(d)Includes alternative revenue programs and late payment charge revenues.
18

DPL Statistics
Three Months Ended March 31, 2021 and 2020
Electric and Natural Gas Deliveries
Revenue (in millions)
20212020% ChangeWeather -
Normal
% Change
20212020% Change
Electric (in GWhs)
Rate-Regulated Electric Deliveries and Revenues(a)
Residential1,520 1,310 16.0 %5.5 %$190 $161 18.0 %
Small commercial & industrial559 507 10.3 %6.2 %46 43 7.0 %
Large commercial & industrial919 1,069 (14.0)%(15.1)%21 23 (8.7)%
Public authorities & electric railroads12 11 9.1 %5.9 %33.3 %
Other(b)
— — n/an/a41 54 (24.1)%
Total rate-regulated electric revenues(c)
3,010 2,897 3.9 %(1.5)%302 284 6.3 %
Other Rate-Regulated Revenues(d)
350.0 %
Total Electric Revenues311 286 8.7 %
Natural Gas (in mmcfs)
Rate-Regulated Natural Gas Deliveries and Revenues(e)
Residential4,394 3,647 20.5 %2.6 %46 40 15.0 %
Small commercial & industrial1,868 1,671 11.8 %(3.9)%18 17 5.9 %
Large commercial & industrial457 452 1.1 %1.1 %100.0 %
Transportation2,224 2,108 5.5 %(0.9)%— %
Other(f)
— — n/an/a(50.0)%
Total rate-regulated natural gas revenues8,943 7,878 13.5 %0.2 %71 64 10.9 %
Other Rate-Regulated Revenues(d)
— — n/a
Total Natural Gas Revenues71 64 10.9 %
Total Electric and Natural Gas Revenues$382 $350 9.1 %
Purchased Power and Fuel$156 $141 10.6 %
Electric Service Territory% Change
Heating and Cooling Degree-Days20212020NormalFrom 2020From Normal
Heating Degree-Days2,269 1,928 2,414 17.7 %(6.0)%
Cooling Degree-Days150.0 %400.0 %
Natural Gas Service Territory% Change
Heating Degree-Days20212020NormalFrom 2020From Normal
Heating Degree-Days2,358 2,003 2,497 17.7 %(5.6)%
Number of Electric Customers20212020Number of Natural Gas Customers20212020
Residential473,917 469,082 Residential127,522 126,209 
Small commercial & industrial62,647 61,769 Small commercial & industrial10,043 10,004 
Large commercial & industrial1,208 1,414 Large commercial & industrial19 17 
Public authorities & electric railroads608 612 Transportation160 159 
Total538,380 532,877 Total137,744 136,389 
__________
(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 for both the three months ended March 31, 2021 and 2020.
(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.
19

ACE Statistics
Three Months Ended March 31, 2021 and 2020
Electric Deliveries (in GWhs)Revenue (in millions)
20212020% ChangeWeather -
Normal
% Change
20212020% Change
Rate-Regulated Deliveries and Revenues(a)
Residential928 810 14.6 %6.6 %$162 $137 18.2 %
Small commercial & industrial305 294 3.7 %(0.8)%39 37 5.4 %
Large commercial & industrial716 735 (2.6)%(3.5)%43 42 2.4 %
Public authorities & electric railroads13 13 — %0.9 %— %
Other(b)
— — n/an/a52 55 (5.5)%
Total rate-regulated electric revenues(c)
1,962 1,852 5.9 %1.5 %299 274 9.1 %
Other Rate-Regulated Revenues(d)
11 450.0 %
Total Electric Revenues$310 $276 12.3 %
Purchased Power$157 $128 22.7 %
    % Change
Heating and Cooling Degree-Days20212020NormalFrom 2020From Normal
Heating Degree-Days2,348 1,948 2,469 20.5 %(4.9)%
Cooling Degree-Days— — n/an/a
Number of Electric Customers20212020
Residential498,396 495,444 
Small commercial & industrial61,771 61,470 
Large commercial & industrial3,267 3,355 
Public authorities & electric railroads704 684 
Total564,138 560,953 
__________
(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 $1 million for both the three months ended March 31, 2021 and 2020.
(d)Includes alternative revenue programs.
20

Generation Statistics
 Three Months Ended
 March 31, 2021March 31, 2020
Supply (in GWhs)
Nuclear Generation(a)
Mid-Atlantic13,254 12,784 
Midwest23,155 23,598 
New York7,057 6,173 
Total Nuclear Generation43,466 42,555 
Fossil and Renewables
Mid-Atlantic662 853 
Midwest323 388 
New York
ERCOT2,783 3,012 
Other Power Regions(b)
2,964 3,508 
Total Fossil and Renewables6,733 7,762 
Purchased Power
Mid-Atlantic4,483 5,943 
Midwest179 288 
ERCOT772 991 
Other Power Regions(b)
12,834 12,167 
Total Purchased Power18,268 19,389 
Total Supply/Sales by Region
Mid-Atlantic(c)
18,399 19,580 
Midwest(c)
23,657 24,274 
New York7,058 6,174 
ERCOT3,555 4,003 
Other Power Regions(b)
15,798 15,675 
Total Supply/Sales by Region68,467 69,706 
 Three Months Ended
 March 31, 2021March 31, 2020
Outage Days(d)
Refueling84 94 
Non-refueling11 
Total Outage Days87 105 
__________
(a)Includes the proportionate share of output where Generation has an undivided ownership interest in jointly-owned generating plants and includes the total output of plants that are fully consolidated (e.g. CENG).
(b)Other Power Regions includes New England, South, West, and Canada.
(c)Includes affiliate sales to PECO, BGE, Pepco, DPL, and ACE in the Mid-Atlantic region and affiliate sales to ComEd in the Midwest region.
(d)Outage days exclude Salem.
21