EX-99.1 2 exc20171102991.htm EXHIBIT 99.1
Exhibit 99.1
News Release

Contact: |  | Dan Eggers Investor Relations 312-394-2345 Paul Adams Corporate Communications 410-470-4167

EXELON REPORTS THIRD QUARTER 2017 RESULTS
Earnings Release Highlights

• | GAAP Net Income of $0.85 per share and Adjusted (non-GAAP) Operating Earnings of $0.85 per share for the third quarter of 2017

• | Narrowing guidance range for full year 2017 Adjusted (non-GAAP) Operating Earnings from $2.50 - $2.80 per share to $2.55 - $2.75 per share including the 9 cent impact from delays to the Illinois Zero Emission Credit (ZEC) contract signing from December 2017 to January 2018

• | Announcing another $250 million of cost reductions with full run-rate savings to be achieved in 2020

• | New Jersey Board of Public Utilities (NJBPU) approval of ACE’s $43 million settlement for its electric distribution rate case

• | Maryland Public Service Commission (MDPSC) order issued granting Pepco Maryland a $32 million increase for its electric distribution rate case

• | Record third-quarter production for Exelon Nuclear and fewer refueling outage days compared with a year ago

CHICAGO (November 2, 2017) — Exelon Corporation (NYSE: EXC) today reported its financial results for the third quarter 2017.
“Exelon delivered a strong third quarter, led by our Utilities that are performing ahead of plan for the year while providing first quartile reliability, customer satisfaction, and safety across most metrics,” said Christopher M. Crane, Exelon’s president and CEO. “We are encouraged by the U.S. Department of Energy’s recent support for proposed market reforms that would help preserve reliable, emissions-free nuclear energy for the benefit of our customers, environment and communities. We see an important first step coming through potential changes in energy price formation which could be implemented in PJM by mid-year 2018. Our company’s commitment to advancing clean energy and sustainability remains a strategic priority, as was recognized by our inclusion on the Dow Jones Sustainability Index for the 12th consecutive year.”
“In the third quarter of 2017, Exelon delivered solid financial performance with Adjusted (non-GAAP) operating earnings of $0.85 per share, which is at the mid-point of our guidance range,” said Jonathan W. Thayer, Exelon’s Senior Executive Vice President and CFO. “Exelon is narrowing the full-year 2017 guidance
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from $2.50 - $2.80 to $2.55 - $2.75 per share as our utilities perform better than planned, absorbing the impact of delays in recognition of Illinois ZEC revenues until 2018. We also continue to execute against a disciplined management plan that is focused on strengthening and optimizing our operations. We are now targeting another $250 million of annual cost savings by 2020, bringing total annual run-rate savings to over $700 million from initiatives identified since 2015.”
Third Quarter 2017
Exelon's GAAP Net Income for the third quarter 2017 increased to $0.85 per share from $0.53 per share in the third quarter of 2016; Adjusted (non-GAAP) Operating Earnings decreased to $0.85 per share in the third quarter of 2017 from $0.91 per share in the third quarter of 2016. For the reconciliations of GAAP Net Income to Adjusted (non-GAAP) Operating Earnings, refer to the tables beginning on page 6.
Adjusted (non-GAAP) Operating Earnings in the third quarter of 2017 reflect the impacts of lower load volumes delivered at Generation due to mild weather, lower realized energy prices related to Exelon's ratable hedging strategy and unfavorable weather conditions at the utilities, partially offset by higher utility earnings due to regulatory rate increases, ZEC revenue related to the New York Clean Energy Standard (CES) and increased capacity prices.
Operating Company Results 1
ComEd
ComEd's third quarter 2017 GAAP Net Income was $189 million compared with $37 million in the third quarter of 2016. ComEd’s Adjusted (non-GAAP) Operating Earnings were $186 million for the third quarter 2017 and the third quarter 2016, primarily reflecting higher electric distribution and transmission formula rate earnings, offset by favorable weather conditions in 2016. Pursuant to the Illinois Future Energy Jobs Act, beginning in 2017, customer rates for ComEd are adjusted to eliminate the favorable and unfavorable impacts of weather and customer usage patterns on distribution volumes.
PECO
PECO’s third quarter 2017 GAAP Net Income was $112 million compared with $122 million in the third quarter of 2016. PECO’s Adjusted (non-GAAP) Operating Earnings for the third quarter 2017 were $114 million compared with $123 million in the third quarter of 2016, primarily due to unfavorable weather conditions, partially offset by the impacts of higher income tax repairs deduction.
Cooling degree days were down 23.2 percent relative to the same period in 2016 and were 7.2 percent above normal. Total retail electric deliveries were down 8.2 percent compared with the third quarter of 2016. Natural gas deliveries (including both retail and transportation segments) in the third quarter of 2017 were down 10.6 percent compared with the same period in 2016.
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1 Exelon’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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BGE
BGE’s third quarter 2017 GAAP Net Income was $62 million compared with $54 million in the third quarter of 2016. BGE’s Adjusted (non-GAAP) Operating Earnings for the third quarter 2017 were $64 million compared with $55 million in the third quarter of 2016, primarily due to regulatory rate increases. Due to revenue decoupling, BGE is not affected by actual weather or customer usage patterns.
PHI
PHI’s third quarter 2017 GAAP Net Income was $153 million compared with $166 million in the third quarter of 2016. PHI’s Adjusted (non-GAAP) Operating Earnings for the third quarter 2017 were $146 million compared with $130 million in the third quarter of 2016, primarily due to regulatory rate increases in 2016 and 2017. Due to revenue decoupling, PHI's revenues related to Pepco and DPL Maryland are not affected by actual weather or customer usage patterns.
Generation
Generation's third quarter 2017 GAAP Net Income was $305 million compared with $236 million in the third quarter of 2016. Generation’s Adjusted (non-GAAP) Operating Earnings for the third quarter 2017 were $347 million compared with $376 million in the third quarter of 2016, primarily reflecting the impacts of lower load volumes delivered due to mild weather and lower realized energy prices related to Exelon's ratable hedging strategy, partially offset by ZEC revenue related to the New York CES and increased capacity prices.
The proportion of expected generation hedged as of September 30, 2017 was 98.0 percent to 101.0 percent for 2017, 79.0 percent to 82.0 percent for 2018 and 45.0 percent to 48.0 percent for 2019.
Third Quarter and Recent Highlights

• | ACE New Jersey Electric Distribution Rate Case: On September 22, 2017, the NJBPU approved ACE’s filed settlement for its pending electric distribution rate case, which provides for an increase in ACE annual electric distribution base rates of $43 million (before New Jersey sales and use tax) reflecting a ROE of 9.6 percent. Pursuant to the settlement agreement, ACE agreed to withdraw its request for approval of a System Renewal Recovery Charge without prejudice to its right to refile. The new rates were effective on October 1, 2017.

• | Pepco Maryland Electric Distribution Rate Case: On October 20, 2017, the MDPSC approved an increase in Pepco electric distribution rates of $34 million, reflecting a ROE of 9.5 percent. On October 27, 2017, the MDPSC issued an errata order revising the approved increase in Pepco electric distribution rates to $32 million. The errata order corrected a number of computational errors in the original order but did not alter any of the findings. The new rates became effective for services rendered on or after October 20, 2017. In its decision, the MDPSC denied Pepco’s request regarding the income tax adjustment without prejudice to Pepco filing another similar proposal with additional information. Requests for rehearing are due November 20, 2017.

• | DPL Delaware Electric and Natural Gas Distribution Rates Case: On August 17, 2017, DPL filed applications with the Delaware Public Service Commission (DPSC) to increase its annual electric and natural gas distribution base rates by $24 million, which was updated to $31 million on October 18, 2017, and $13 million, respectively, reflecting a requested ROE of 10.1 percent. DPL expects a decision in the electric proceeding and the gas proceeding in the third quarter of 2018, but cannot predict how much of the requested rate increases the DPSC will approve. While the DPSC is not

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required to issue a decision on the application within a specified period of time, Delaware law allows DPL to put into effect $2.5 million of the rate increase two months after filing the application and the entire requested rate increase seven months after filing, subject to a cap and a refund obligation based on the final DPSC order. On October 24, 2017, the Staff of the DPSC and the Public Advocate filed a joint motion to dismiss DPL’s electric distribution base rate application without prejudice to refiling, arguing that the amount of the requested increase to $31 million required additional time to review and additional public notice. The DPSC is expected to decide at its meeting on November 9, 2017. DPL cannot predict the outcome of this matter.

• | Updated Cost Management Program: In November 2017, Exelon announced the elimination of approximately $250 million of annual ongoing costs, primarily at Generation, by 2020. This announcement is a result of Exelon’s continuous focus on improving its cost profile through enhanced efficiency and productivity. These cost reductions result in a cost profile that better aligns with current market conditions. The targeted cost savings are incremental to the expected savings from previous cost management initiatives.

• | DOE Notice of Proposed Rulemaking: On August 23, 2017, the United States Department of Energy (DOE) released its report on the reliability of the electric grid. One aspect of the wide-ranging report is the DOE’s recognition that the electricity markets do not currently value the resiliency provided by baseload generation, such as nuclear plants. On September, 28, 2017, the DOE issued a Notice of Proposed Rulemaking (NOPR) that would entitle certain eligible resilient generating units (i.e., those located in organized markets, with a 90-day supply of fuel on site, not already subject to state cost of service regulation and satisfying certain other requirements) to recover fully allocated costs and earn a fair return on equity on their investment. On October 2, 2017, the Federal Energy Regulatory Commission (FERC) issued a notice inviting comments regarding the DOE NOPR within 21 days and established a new docket wherein the FERC will consider the matter. On October 23, 2017, Exelon filed comments with the FERC, supporting the goals of the NOPR and urging the agency to take swift action to protect customers from power supply interruptions and ensure resiliency in a way that appropriately balances the value and cost to customers. Exelon cannot predict the final outcome of the proceeding or its potential impact, if any, on Exelon or Generation.

• | Delay in Illinois ZEC Revenue Recognition: On October 27, 2017, the Illinois Power Agency (IPA) released the schedule for the ZEC procurement event indicating that contracts with zero emission facilities will be fully executed on January 30, 2018. It was anticipated that the procurement event and the execution of contracts with winning ZEC suppliers would occur in December 2017 and therefore Exelon would begin to recognize expected Illinois ZEC revenue retroactive to June 1, 2017, in the fourth quarter 2017. Exelon now expects to recognize Illinois ZEC revenue in the first quarter of 2018, effectively shifting $0.09 of EPS from 2017 into 2018. The delayed timing will have no impact on the amount of ZEC revenue.

• | Nuclear Operations: Generation’s nuclear fleet, including its owned output from the Salem Generating Station and 100 percent of the CENG units, produced 47,747 gigawatt-hours (GWhs) in the third quarter of 2017, compared with 44,709 GWhs in the third quarter of 2016. Excluding Salem, the Exelon-operated nuclear plants at ownership achieved a 96.1 percent capacity factor for the third quarter of 2017, compared with 96.3 percent for the third quarter of 2016. The number of planned refueling outage days in the third quarter of 2017 totaled 13, compared with 17 in the third quarter of 2016. There were 15 non-refueling outage days in the third quarter of 2017, compared with 0 days in the third quarter of 2016.

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• | Fossil and Renewables Operations: The dispatch match rate for Generation’s gas and hydro fleet was 98.4 percent in the third quarter of 2017, compared with 97.9 percent in the third quarter of 2016. The reported performance does not include Wolf Hollow II or Colorado Bend II, the two new combined-cycle gas turbine units that went into full commercial operation in the second quarter of 2017. Energy capture for the wind and solar fleet was 95.9 percent in the third quarter of 2017, compared with 95.2 percent in the third quarter of 2016.

• | State of Illinois Income Tax Rate Change: On July 6, 2017, Illinois enacted Senate Bill 9, which permanently increased Illinois’ total corporate income tax rate from 7.75 percent to 9.50 percent effective July 1, 2017. In addition, in the third quarter of 2017, Exelon updated its marginal state income tax rates based on 2016 state apportionment rates. As a result of these changes, Exelon, Generation and ComEd recorded a one-time increase to Deferred income taxes of approximately $250 million, $20 million and $270 million, respectively, on their Consolidated Balance Sheets in the third quarter of 2017. As income taxes are recovered through rates, each of Exelon and ComEd recorded a corresponding regulatory asset of $272 million. Further, Exelon recorded a decrease of approximately $20 million and Generation recorded an increase of approximately $20 million (each net of federal taxes) to Income tax expense in the third quarter of 2017. The income tax rate increase is not expected to have a material ongoing impact to Exelon’s, Generation’s or ComEd’s future results of operations.

• | Financing Activities:

◦ | On August 23, 2017, ComEd issued $350 million aggregate principal amount of its First Mortgage 2.950 percent Bonds, due August 15, 2027 and $650 million aggregate principal amount of its First Mortgage 3.750 percent Bonds, due August 15, 2047. ComEd used the proceeds from the Bonds to refinance maturing First Mortgage Bonds, to repay a portion of ComEd’s outstanding commercial paper obligations and for general corporate purposes.

◦ | On August 24, 2017, BGE issued $300 million aggregate principal amount of its 3.750 percent Notes due 2047. BGE used the proceeds from the Notes to redeem $250 million in principal amount of the 6.200 percent Deferrable Interest Subordinated Debentures due October 15, 2043 issued by BGE's affiliate BGE Capital Trust II, to repay commercial paper obligations and for general corporate purposes.

◦ | On September 18, 2017, PECO issued $325 million aggregate principal amount of its First and Refunding Mortgage Bonds, 3.700 percent Series due September 15, 2047. PECO used the proceeds from the Bonds for general corporate purposes.

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GAAP/Adjusted (non-GAAP) Operating Earnings Reconciliation
Adjusted (non-GAAP) Operating Earnings for the third quarter of 2017 do not include the following items (after tax) that were included in reported GAAP Net Income:

(in millions) | Exelon Earnings per Diluted Share | Exelon | ComEd | PECO | BGE | PHI | Generation
2017 GAAP Net Income | $ | 0.85 |  | $ | 824 |  | $ | 189 |  | $ | 112 |  | $ | 62 |  | $ | 153 |  | $ | 305 |
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $29) | (0.05 | ) | (45 | ) | — |  | — |  | — |  | — |  | (46 | )
Unrealized Gains Related to Nuclear Decommissioning Trust (NDT) Fund Investments (net of taxes of $45) | (0.07 | ) | (67 | ) | — |  | — |  | — |  | — |  | (67 | )
Amortization of Commodity Contract Intangibles (net of taxes of $8) | 0.01 |  | 12 |  | — |  | — |  | — |  | — |  | 12 |
Merger and Integration Costs (net of taxes of $1, $6 and $5, respectively) | — |  | (1 | ) | — |  | — |  | — |  | (9 | ) | 7 |
Long-Lived Asset Impairments (net of taxes of $16) | 0.03 |  | 24 |  | — |  | — |  | — |  | — |  | 25 |
Plant Retirements and Divestitures (net of taxes of $47 and $46, respectively) | 0.08 |  | 71 |  | — |  | — |  | — |  | — |  | 72 |
Cost Management Program (net of taxes of $8, $1, $1 and $6 respectively) | 0.01 |  | 13 |  | — |  | 2 |  | 2 |  | — |  | 10 |
Reassessment of State Deferred Income Taxes (entire amount represents tax expense) | (0.02 | ) | (21 | ) | (3 | ) | — |  | — |  | 2 |  | 18 |
Bargain Purchase Gain (net of taxes of $0) | (0.01 | ) | (7 | ) | — |  | — |  | — |  | — |  | (7 | )
Asset Retirement Obligation (net of taxes of $1) | — |  | (2 | ) | — |  | — |  | — |  | — |  | (2 | )
Noncontrolling Interests (net of taxes of $4) | 0.02 |  | 20 |  | — |  | — |  | — |  | — |  | 20 |
2017 Adjusted (non-GAAP) Operating Earnings | $ | 0.85 |  | $ | 821 |  | $ | 186 |  | $ | 114 |  | $ | 64 |  | $ | 146 |  | $ | 347 |

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Adjusted (non-GAAP) Operating Earnings for the third quarter of 2016 do not include the following items (after tax) that were included in reported GAAP Net Income:

(in millions) | Exelon Earnings per Diluted Share | Exelon | ComEd | PECO | BGE | PHI | Generation
2016 GAAP Net Income | $ | 0.53 |  | $ | 490 |  | $ | 37 |  | $ | 122 |  | $ | 54 |  | $ | 166 |  | $ | 236 |
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $35) | (0.06 | ) | (54 | ) | — |  | — |  | — |  | — |  | (54 | )
Unrealized Gains Related to NDT Fund Investments (net of taxes of $48) | (0.07 | ) | (70 | ) | — |  | — |  | — |  | — |  | (70 | )
Amortization of Commodity Contract Intangibles (net of taxes of $8) | 0.01 |  | 13 |  | — |  | — |  | — |  | — |  | 13 |
Merger and Integrations Costs (net of taxes of $10, $1, $1, $3 and $5, respectively) | 0.01 |  | 13 |  | — |  | 1 |  | 1 |  | 4 |  | 7 |
Merger Commitments (net of taxes of $1 and $10, respectively) | 0.01 |  | 5 |  | — |  | — |  | — |  | (40 | ) | — |
Long-Lived Asset Impairments (net of taxes of $5 and $6, respectively) | 0.01 |  | 11 |  | — |  | — |  | — |  | — |  | 10 |
Plant Retirements and Divestitures (net of taxes of $129) | 0.22 |  | 204 |  | — |  | — |  | — |  | — |  | 204 |
Cost Management Program (net of taxes of $5) | 0.01 |  | 7 |  | — |  | — |  | — |  | — |  | 7 |
Like-Kind Exchange Tax Position (net of taxes of $61 and $42, respectively) | 0.21 |  | 199 |  | 149 |  | — |  | — |  | — |  | — |
Noncontrolling Interests (net of taxes of $5) | 0.03 |  | 23 |  | — |  | — |  | — |  | — |  | 23 |
2016 Adjusted (non-GAAP) Operating Earnings | $ | 0.91 |  | $ | 841 |  | $ | 186 |  | $ | 123 |  | $ | 55 |  | $ | 130 |  | $ | 376 |

Note:
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 gains and losses related to NDT fund investments, the marginal statutory income tax rates ranged from 39.0 percent to 41.0 percent. Under IRS regulations, NDT fund investment returns are taxed at differing rates for investments in qualified vs. non-qualified funds. The tax rates applied to unrealized gains and losses related to NDT fund investments were 43.2 percent and 52.6 percent for the three months ended September 30, 2017 and 2016, respectively.
Webcast Information
Exelon will discuss third quarter 2017 earnings in a one-hour conference call scheduled for today at 9 a.m. Central Time (10 a.m. Ea​stern Time).​ The webcast and associated materials can be accessed at www.exeloncorp.com/investor-relations.
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About Exelon
Exelon Corporation (NYSE: EXC) is a Fortune 100 energy company with the largest number of utility customers in the U.S. Exelon does business in 48 states, the District of Columbia and Canada and had 2016 revenue of $31.4 billion. Exelon’s six utilities deliver electricity and natural gas to 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 35,500 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 2.2 million residential, public sector and business customers, including more than two-thirds 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 November 2, 2017.
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. 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' 2016 Annual Report on Form 10-K in (a) ITEM 1A. Risk Factors, (b) ITEM 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations and (c) ITEM 8. Financial Statements and Supplementary Data: Note 24, Commitments and Contingencies; (2) the Registrants' Third Quarter 2017 Quarterly Report on Form 10-Q (to be filed on November 2, 2017) in (a) Part II, Other Information, ITEM 1A. Risk Factors; (b) Part 1, Financial Information, ITEM 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations and (c) Part I, Financial Information, ITEM 1. Financial Statements: Note 18, Commitments and Contingencies; and (3)
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other factors discussed in filings with the SEC by the Registrants. Readers are cautioned not to place undue reliance on these forward-looking statements, 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 - Three Months Ended September 30, 2017 and 2016 | 1
Consolidating Statements of Operations - Nine Months Ended September 30, 2017 and 2016 | 2
Business Segment Comparative Statements of Operations - Generation and ComEd - Three and Nine Months Ended September 30, 2017 and 2016 | 3
Business Segment Comparative Statements of Operations - PECO and BGE - Three and Nine Months Ended September 30, 2017 and 2016 | 4
Business Segment Comparative Statements of Operations - PHI and Other - Three and Nine Months Ended September 30, 2017 and 2016 | 5
Consolidated Balance Sheets - September 30, 2017 and December 31, 2016 | 6
Consolidated Statements of Cash Flows - Nine Months Ended September 30, 2017 and 2016 | 7
GAAP Consolidated Statements of Operations and Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments - Exelon - three months ended September 30, 2017 and 2016 | 8
GAAP Consolidated Statements of Operations and Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments - Exelon - nine months ended September 30, 2017 and 2016 | 10
Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Net Income - Three Months Ended September 30, 2017 and 2016 | 12
Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Net Income - Nine Months Ended September 30, 2017 and 2016 | 14
GAAP Consolidated Statements of Operations and Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments - Generation - Three and Nine Months Ended September 30, 2017 and 2016 | 17
GAAP Consolidated Statements of Operations and Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments - ComEd - Three and Nine Months Ended September 30, 2017 and 2016 | 19
GAAP Consolidated Statements of Operations and Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments - PECO - Three and Nine Months Ended September 30, 2017 and 2016 | 21
GAAP Consolidated Statements of Operations and Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments - BGE - Three and Nine Months Ended September 30, 2017 and 2016 | 22
GAAP Consolidated Statements of Operations and Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments - PHI - Three and Nine Months Ended September 30, 2017 and 2016 | 24
GAAP Consolidated Statements of Operations and Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments - Other - Three and Nine Months Ended September 30, 2017 and 2016 | 26
Exelon Generation Statistics - Three Months Ended September 30, 2017, June 30, 2017, March 31, 2017, December 31, 2016 and September 30, 2016 | 28
Exelon Generation Statistics - Nine Months Ended September 30, 2017 and 2016 | 29
ComEd Statistics - Three and Nine Months Ended September 30, 2017 and 2016 | 30
PECO Statistics - Three and Nine Months Ended September 30, 2017 and 2016 | 31
BGE Statistics - Three and Nine Months Ended September 30, 2017 and 2016 | 33
Pepco Statistics - Three and Nine Months Ended September 30, 2017 and 2016 | 35
DPL Statistics - Three and Nine Months Ended September 30, 2017 and 2016 | 36
ACE Statistics - Three and Nine Months Ended September 30, 2017 and 2016 | 38

EXELON CORPORATION
Consolidating Statements of Operations
(unaudited)
(in millions)

|  | Three Months Ended September 30, 2017
|  | Generation |  | ComEd |  | PECO |  | BGE |  | PHI (a) |  | Other (b) |  | Exelon Consolidated
Operating revenues |  | $ | 4,751 |  |  | $ | 1,571 |  |  | $ | 715 |  |  | $ | 738 |  |  | $ | 1,310 |  |  | $ | (316 | ) |  | $ | 8,769 |
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | 2,331 |  |  | 529 |  |  | 235 |  |  | 269 |  |  | 473 |  |  | (295 | ) |  | 3,542 |
Operating and maintenance |  | 1,374 |  |  | 346 |  |  | 197 |  |  | 175 |  |  | 251 |  |  | (43 | ) |  | 2,300 |
Depreciation and amortization |  | 410 |  |  | 212 |  |  | 72 |  |  | 109 |  |  | 179 |  |  | 20 |  |  | 1,002 |
Taxes other than income |  | 141 |  |  | 80 |  |  | 42 |  |  | 61 |  |  | 122 |  |  | 10 |  |  | 456 |
Total operating expenses |  | 4,256 |  |  | 1,167 |  |  | 546 |  |  | 614 |  |  | 1,025 |  |  | (308 | ) |  | 7,300 |
(Loss) gain on sales of assets |  | (2 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | 1 |  |  | (1 | )
Bargain purchase gain |  | 7 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 7 |
Operating income (loss) |  | 500 |  |  | 404 |  |  | 169 |  |  | 124 |  |  | 285 |  |  | (7 | ) |  | 1,475 |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (113 | ) |  | (89 | ) |  | (31 | ) |  | (26 | ) |  | (62 | ) |  | (65 | ) |  | (386 | )
Other, net |  | 209 |  |  | 5 |  |  | 2 |  |  | 4 |  |  | 13 |  |  | 4 |  |  | 237 |
Total other income and (deductions) |  | 96 |  |  | (84 | ) |  | (29 | ) |  | (22 | ) |  | (49 | ) |  | (61 | ) |  | (149 | )
Income (loss) before income taxes |  | 596 |  |  | 320 |  |  | 140 |  |  | 102 |  |  | 236 |  |  | (68 | ) |  | 1,326 |
Income taxes |  | 240 |  |  | 131 |  |  | 28 |  |  | 40 |  |  | 83 |  |  | (70 | ) |  | 452 |
Equity in (losses) earnings of unconsolidated affiliates |  | (8 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | 1 |  |  | (7 | )
Net income |  | 348 |  |  | 189 |  |  | 112 |  |  | 62 |  |  | 153 |  |  | 3 |  |  | 867 |
Net income attributable to noncontrolling interests |  | 43 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 43 |
Net income attributable to common shareholders |  | $ | 305 |  |  | $ | 189 |  |  | $ | 112 |  |  | $ | 62 |  |  | $ | 153 |  |  | $ | 3 |  |  | $ | 824 |
|  | Three Months Ended September 30, 2016
|  | Generation |  | ComEd |  | PECO |  | BGE |  | PHI (a) |  | Other (a) |  | Exelon Consolidated
Operating revenues |  | $ | 5,035 |  |  | $ | 1,497 |  |  | $ | 788 |  |  | $ | 812 |  |  | $ | 1,394 |  |  | $ | (524 | ) |  | $ | 9,002 |
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | 2,589 |  |  | 454 |  |  | 272 |  |  | 360 |  |  | 583 |  |  | (504 | ) |  | 3,754 |
Operating and maintenance |  | 1,336 |  |  | 377 |  |  | 199 |  |  | 178 |  |  | 226 |  |  | 22 |  |  | 2,338 |
Depreciation and amortization |  | 632 |  |  | 196 |  |  | 67 |  |  | 101 |  |  | 182 |  |  | 17 |  |  | 1,195 |
Taxes other than income |  | 136 |  |  | 82 |  |  | 46 |  |  | 58 |  |  | 124 |  |  | 3 |  |  | 449 |
Total operating expenses |  | 4,693 |  |  | 1,109 |  |  | 584 |  |  | 697 |  |  | 1,115 |  |  | (462 | ) |  | 7,736 |
Gain on sales of assets |  | — |  |  | 1 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 1 |
Operating income (loss) |  | 342 |  |  | 389 |  |  | 204 |  |  | 115 |  |  | 279 |  |  | (62 | ) |  | 1,267 |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (77 | ) |  | (197 | ) |  | (30 | ) |  | (28 | ) |  | (64 | ) |  | (120 | ) |  | (516 | )
Other, net |  | 185 |  |  | (80 | ) |  | 2 |  |  | 5 |  |  | 19 |  |  | (11 | ) |  | 120 |
Total other income and (deductions) |  | 108 |  |  | (277 | ) |  | (28 | ) |  | (23 | ) |  | (45 | ) |  | (131 | ) |  | (396 | )
Income (loss) before income taxes |  | 450 |  |  | 112 |  |  | 176 |  |  | 92 |  |  | 234 |  |  | (193 | ) |  | 871 |
Income taxes |  | 173 |  |  | 75 |  |  | 54 |  |  | 36 |  |  | 68 |  |  | (66 | ) |  | 340 |
Equity in losses of unconsolidated affiliates |  | (6 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | 1 |  |  | (5 | )
Net income (loss) |  | 271 |  |  | 37 |  |  | 122 |  |  | 56 |  |  | 166 |  |  | (126 | ) |  | 526 |
Net income (loss) attributable to noncontrolling interests and preference stock dividends |  | 35 |  |  | — |  |  | — |  |  | 2 |  |  | — |  |  | (1 | ) |  | 36 |
Net income (loss) attributable to common shareholders |  | $ | 236 |  |  | $ | 37 |  |  | $ | 122 |  |  | $ | 54 |  |  | $ | 166 |  |  | $ | (125 | ) |  | $ | 490 |

(a) | PHI includes the consolidated results of Potomac Electric Power Company, Delmarva Power & Light Company and Atlantic City Electric Company.

(b) | Other primarily includes eliminating and consolidating adjustments, Exelon’s corporate operations, shared service entities and other financing and investment activities.

1

EXELON CORPORATION
Consolidating Statements of Operations
(unaudited)
(in millions)

|  | Nine Months Ended September 30, 2017
|  | Generation |  | ComEd |  | PECO |  | BGE |  | PHI |  | Other (a) |  | Exelon Consolidated
Operating revenues |  | $ | 13,812 |  |  | $ | 4,227 |  |  | $ | 2,141 |  |  | $ | 2,363 |  |  | $ | 3,557 |  |  | $ | (951 | ) |  | $ | 25,149 |
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | 7,286 |  |  | 1,241 |  |  | 719 |  |  | 853 |  |  | 1,318 |  |  | (890 | ) |  | 10,527 |
Operating and maintenance |  | 4,871 |  |  | 1,096 |  |  | 595 |  |  | 532 |  |  | 774 |  |  | (136 | ) |  | 7,732 |
Depreciation and amortization |  | 1,046 |  |  | 631 |  |  | 213 |  |  | 348 |  |  | 511 |  |  | 65 |  |  | 2,814 |
Taxes other than income |  | 425 |  |  | 223 |  |  | 116 |  |  | 180 |  |  | 344 |  |  | 25 |  |  | 1,313 |
Total operating expenses |  | 13,628 |  |  | 3,191 |  |  | 1,643 |  |  | 1,913 |  |  | 2,947 |  |  | (936 | ) |  | 22,386 |
Gain on sales of assets |  | 3 |  |  | — |  |  | — |  |  | — |  |  | 1 |  |  | — |  |  | 4 |
Bargain purchase gain |  | 233 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 233 |
Operating income (loss) |  | 420 |  |  | 1,036 |  |  | 498 |  |  | 450 |  |  | 611 |  |  | (15 | ) |  | 3,000 |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (342 | ) |  | (275 | ) |  | (93 | ) |  | (80 | ) |  | (183 | ) |  | (221 | ) |  | (1,194 | )
Other, net |  | 648 |  |  | 14 |  |  | 6 |  |  | 12 |  |  | 40 |  |  | 5 |  |  | 725 |
Total other income and (deductions) |  | 306 |  |  | (261 | ) |  | (87 | ) |  | (68 | ) |  | (143 | ) |  | (216 | ) |  | (469 | )
Income (loss) before income taxes |  | 726 |  |  | 775 |  |  | 411 |  |  | 382 |  |  | 468 |  |  | (231 | ) |  | 2,531 |
Income taxes |  | 209 |  |  | 328 |  |  | 84 |  |  | 151 |  |  | 109 |  |  | (286 | ) |  | 595 |
Equity in (losses) earnings of unconsolidated affiliates |  | (26 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | 1 |  |  | (25 | )
Net income |  | 491 |  |  | 447 |  |  | 327 |  |  | 231 |  |  | 359 |  |  | 56 |  |  | 1,911 |
Net income attributable to noncontrolling interests |  | 12 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 12 |
Net income attributable to common shareholders |  | $ | 479 |  |  | $ | 447 |  |  | $ | 327 |  |  | $ | 231 |  |  | $ | 359 |  |  | $ | 56 |  |  | $ | 1,899 |
|  | Nine Months Ended September 30, 2016
|  | Generation |  | ComEd |  | PECO |  | BGE |  | PHI (b) |  | Other (a) |  | Exelon Consolidated
Operating revenues |  | $ | 13,363 |  |  | $ | 4,031 |  |  | $ | 2,293 |  |  | $ | 2,421 |  |  | $ | 2,565 |  |  | $ | (1,187 | ) |  | $ | 23,486 |
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | 6,609 |  |  | 1,141 |  |  | 809 |  |  | 994 |  |  | 1,037 |  |  | (1,128 | ) |  | 9,462 |
Operating and maintenance |  | 4,333 |  |  | 1,113 |  |  | 604 |  |  | 588 |  |  | 921 |  |  | 118 |  |  | 7,677 |
Depreciation and amortization |  | 1,329 |  |  | 574 |  |  | 201 |  |  | 307 |  |  | 355 |  |  | 55 |  |  | 2,821 |
Taxes other than income |  | 380 |  |  | 222 |  |  | 126 |  |  | 172 |  |  | 248 |  |  | 20 |  |  | 1,168 |
Total operating expenses |  | 12,651 |  |  | 3,050 |  |  | 1,740 |  |  | 2,061 |  |  | 2,561 |  |  | (935 | ) |  | 21,128 |
Gain on sales of assets |  | 31 |  |  | 6 |  |  | — |  |  | — |  |  | — |  |  | 4 |  |  | 41 |
Operating income (loss) |  | 743 |  |  | 987 |  |  | 553 |  |  | 360 |  |  | 4 |  |  | (248 | ) |  | 2,399 |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (273 | ) |  | (374 | ) |  | (92 | ) |  | (76 | ) |  | (135 | ) |  | (229 | ) |  | (1,179 | )
Other, net |  | 395 |  |  | (72 | ) |  | 6 |  |  | 16 |  |  | 31 |  |  | 1 |  |  | 377 |
Total other income and (deductions) |  | 122 |  |  | (446 | ) |  | (86 | ) |  | (60 | ) |  | (104 | ) |  | (228 | ) |  | (802 | )
Income (loss) before income taxes |  | 865 |  |  | 541 |  |  | 467 |  |  | 300 |  |  | (100 | ) |  | (476 | ) |  | 1,597 |
Income taxes |  | 293 |  |  | 244 |  |  | 121 |  |  | 109 |  |  | (9 | ) |  | (133 | ) |  | 625 |
Equity in losses of unconsolidated affiliates |  | (16 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (16 | )
Net income (loss) |  | 556 |  |  | 297 |  |  | 346 |  |  | 191 |  |  | (91 | ) |  | (343 | ) |  | 956 |
Net income attributable to noncontrolling interests and preference stock dividends |  | 18 |  |  | — |  |  | — |  |  | 8 |  |  | — |  |  | — |  |  | 26 |
Net income (loss) attributable to common shareholders |  | $ | 538 |  |  | $ | 297 |  |  | $ | 346 |  |  | $ | 183 |  |  | $ | (91 | ) |  | $ | (343 | ) |  | $ | 930 |

(a) | Other primarily includes eliminating and consolidating adjustments, Exelon’s corporate operations, shared service entities and other financing and investment activities.

(b) | PHI includes the consolidated results of Potomac Electric Power Company, Delmarva Power & Light Company and Atlantic City Electric Company beginning on March 24, 2016, the day after the merger was completed.

2

EXELON CORPORATION
Business Segment Comparative Statements of Operations
(unaudited)
(in millions)

|  | Generation
|  | Three Months Ended September 30, |  | Nine Months Ended September 30,
|  | 2017 |  | 2016 |  | Variance |  | 2017 |  | 2016 |  | Variance
Operating revenues |  | $ | 4,751 |  |  | $ | 5,035 |  |  | $ | (284 | ) |  | $ | 13,812 |  |  | $ | 13,363 |  |  | $ | 449 |
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | 2,331 |  |  | 2,589 |  |  | (258 | ) |  | 7,286 |  |  | 6,609 |  |  | 677 |
Operating and maintenance |  | 1,374 |  |  | 1,336 |  |  | 38 |  |  | 4,871 |  |  | 4,333 |  |  | 538 |
Depreciation and amortization |  | 410 |  |  | 632 |  |  | (222 | ) |  | 1,046 |  |  | 1,329 |  |  | (283 | )
Taxes other than income |  | 141 |  |  | 136 |  |  | 5 |  |  | 425 |  |  | 380 |  |  | 45 |
Total operating expenses |  | 4,256 |  |  | 4,693 |  |  | (437 | ) |  | 13,628 |  |  | 12,651 |  |  | 977 |
Gain on sales of assets |  | (2 | ) |  | — |  |  | (2 | ) |  | 3 |  |  | 31 |  |  | (28 | )
Bargain purchase gain |  | 7 |  |  | — |  |  | 7 |  |  | 233 |  |  | — |  |  | 233 |
Operating income |  | 500 |  |  | 342 |  |  | 158 |  |  | 420 |  |  | 743 |  |  | (323 | )
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (113 | ) |  | (77 | ) |  | (36 | ) |  | (342 | ) |  | (273 | ) |  | (69 | )
Other, net |  | 209 |  |  | 185 |  |  | 24 |  |  | 648 |  |  | 395 |  |  | 253 |
Total other income and (deductions) |  | 96 |  |  | 108 |  |  | (12 | ) |  | 306 |  |  | 122 |  |  | 184 |
Income before income taxes |  | 596 |  |  | 450 |  |  | 146 |  |  | 726 |  |  | 865 |  |  | (139 | )
Income taxes |  | 240 |  |  | 173 |  |  | 67 |  |  | 209 |  |  | 293 |  |  | (84 | )
Equity in losses of unconsolidated affiliates |  | (8 | ) |  | (6 | ) |  | (2 | ) |  | (26 | ) |  | (16 | ) |  | (10 | )
Net income |  | 348 |  |  | 271 |  |  | 77 |  |  | 491 |  |  | 556 |  |  | (65 | )
Net income attributable to noncontrolling interests |  | 43 |  |  | 35 |  |  | 8 |  |  | 12 |  |  | 18 |  |  | (6 | )
Net income attributable to membership interest |  | $ | 305 |  |  | $ | 236 |  |  | $ | 69 |  |  | $ | 479 |  |  | $ | 538 |  |  | $ | (59 | )
|  | ComEd
|  | Three Months Ended September 30, |  | Nine Months Ended September 30,
|  | 2017 |  | 2016 |  | Variance |  | 2017 |  | 2016 |  | Variance
Operating revenues |  | $ | 1,571 |  |  | $ | 1,497 |  |  | $ | 74 |  |  | $ | 4,227 |  |  | $ | 4,031 |  |  | $ | 196 |
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Purchased power |  | 529 |  |  | 454 |  |  | 75 |  |  | 1,241 |  |  | 1,141 |  |  | 100 |
Operating and maintenance |  | 346 |  |  | 377 |  |  | (31 | ) |  | 1,096 |  |  | 1,113 |  |  | (17 | )
Depreciation and amortization |  | 212 |  |  | 196 |  |  | 16 |  |  | 631 |  |  | 574 |  |  | 57 |
Taxes other than income |  | 80 |  |  | 82 |  |  | (2 | ) |  | 223 |  |  | 222 |  |  | 1 |
Total operating expenses |  | 1,167 |  |  | 1,109 |  |  | 58 |  |  | 3,191 |  |  | 3,050 |  |  | 141 |
Gain on sales of assets |  | — |  |  | 1 |  |  | (1 | ) |  | — |  |  | 6 |  |  | (6 | )
Operating income |  | 404 |  |  | 389 |  |  | 15 |  |  | 1,036 |  |  | 987 |  |  | 49 |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (89 | ) |  | (197 | ) |  | 108 |  |  | (275 | ) |  | (374 | ) |  | 99 |
Other, net |  | 5 |  |  | (80 | ) |  | 85 |  |  | 14 |  |  | (72 | ) |  | 86 |
Total other income and (deductions) |  | (84 | ) |  | (277 | ) |  | 193 |  |  | (261 | ) |  | (446 | ) |  | 185 |
Income before income taxes |  | 320 |  |  | 112 |  |  | 208 |  |  | 775 |  |  | 541 |  |  | 234 |
Income taxes |  | 131 |  |  | 75 |  |  | 56 |  |  | 328 |  |  | 244 |  |  | 84 |
Net income |  | $ | 189 |  |  | $ | 37 |  |  | $ | 152 |  |  | $ | 447 |  |  | $ | 297 |  |  | $ | 150 |

.
3

EXELON CORPORATION
Business Segment Comparative Statements of Operations
(unaudited)
(in millions)

|  | PECO
|  | Three Months Ended September 30, |  | Nine Months Ended September 30,
|  | 2017 |  | 2016 |  | Variance |  | 2017 |  | 2016 |  | Variance
Operating revenues |  | $ | 715 |  |  | $ | 788 |  |  | $ | (73 | ) |  | $ | 2,141 |  |  | $ | 2,293 |  |  | $ | (152 | )
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | 235 |  |  | 272 |  |  | (37 | ) |  | 719 |  |  | 809 |  |  | (90 | )
Operating and maintenance |  | 197 |  |  | 199 |  |  | (2 | ) |  | 595 |  |  | 604 |  |  | (9 | )
Depreciation and amortization |  | 72 |  |  | 67 |  |  | 5 |  |  | 213 |  |  | 201 |  |  | 12 |
Taxes other than income |  | 42 |  |  | 46 |  |  | (4 | ) |  | 116 |  |  | 126 |  |  | (10 | )
Total operating expenses |  | 546 |  |  | 584 |  |  | (38 | ) |  | 1,643 |  |  | 1,740 |  |  | (97 | )
Operating income |  | 169 |  |  | 204 |  |  | (35 | ) |  | 498 |  |  | 553 |  |  | (55 | )
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (31 | ) |  | (30 | ) |  | (1 | ) |  | (93 | ) |  | (92 | ) |  | (1 | )
Other, net |  | 2 |  |  | 2 |  |  | — |  |  | 6 |  |  | 6 |  |  | — |
Total other income and (deductions) |  | (29 | ) |  | (28 | ) |  | (1 | ) |  | (87 | ) |  | (86 | ) |  | (1 | )
Income before income taxes |  | 140 |  |  | 176 |  |  | (36 | ) |  | 411 |  |  | 467 |  |  | (56 | )
Income taxes |  | 28 |  |  | 54 |  |  | (26 | ) |  | 84 |  |  | 121 |  |  | (37 | )
Net income |  | $ | 112 |  |  | $ | 122 |  |  | $ | (10 | ) |  | $ | 327 |  |  | $ | 346 |  |  | $ | (19 | )
|  | BGE
|  | Three Months Ended September 30, |  | Nine Months Ended September 30,
|  | 2017 |  | 2016 |  | Variance |  | 2017 |  | 2016 |  | Variance
Operating revenues |  | $ | 738 |  |  | $ | 812 |  |  | $ | (74 | ) |  | $ | 2,363 |  |  | $ | 2,421 |  |  | $ | (58 | )
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | 269 |  |  | 360 |  |  | (91 | ) |  | 853 |  |  | 994 |  |  | (141 | )
Operating and maintenance |  | 175 |  |  | 178 |  |  | (3 | ) |  | 532 |  |  | 588 |  |  | (56 | )
Depreciation and amortization |  | 109 |  |  | 101 |  |  | 8 |  |  | 348 |  |  | 307 |  |  | 41 |
Taxes other than income |  | 61 |  |  | 58 |  |  | 3 |  |  | 180 |  |  | 172 |  |  | 8 |
Total operating expenses |  | 614 |  |  | 697 |  |  | (83 | ) |  | 1,913 |  |  | 2,061 |  |  | (148 | )
Operating income |  | 124 |  |  | 115 |  |  | 9 |  |  | 450 |  |  | 360 |  |  | 90 |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (26 | ) |  | (28 | ) |  | 2 |  |  | (80 | ) |  | (76 | ) |  | (4 | )
Other, net |  | 4 |  |  | 5 |  |  | (1 | ) |  | 12 |  |  | 16 |  |  | (4 | )
Total other income and (deductions) |  | (22 | ) |  | (23 | ) |  | 1 |  |  | (68 | ) |  | (60 | ) |  | (8 | )
Income before income taxes |  | 102 |  |  | 92 |  |  | 10 |  |  | 382 |  |  | 300 |  |  | 82 |
Income taxes |  | 40 |  |  | 36 |  |  | 4 |  |  | 151 |  |  | 109 |  |  | 42 |
Net income |  | 62 |  |  | 56 |  |  | 6 |  |  | 231 |  |  | 191 |  |  | 40 |
Preference stock dividends |  | — |  |  | 2 |  |  | (2 | ) |  | — |  |  | 8 |  |  | (8 | )
Net income attributable to common shareholder |  | $ | 62 |  |  | $ | 54 |  |  | $ | 8 |  |  | $ | 231 |  |  | $ | 183 |  |  | $ | 48 |

4

EXELON CORPORATION
Business Segment Comparative Statements of Operations
(unaudited)
(in millions)

|  | PHI
|  | Three Months Ended September 30, |  | Nine Months Ended September 30,
|  | 2017 |  | 2016 |  | Variance |  | 2017 |  | 2016 (a) |  | Variance
Operating revenues |  | $ | 1,310 |  |  | $ | 1,394 |  |  | $ | (84 | ) |  | $ | 3,557 |  |  | $ | 2,565 |  |  | $ | 992 |
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | 473 |  |  | 583 |  |  | (110 | ) |  | 1,318 |  |  | 1,037 |  |  | 281 |
Operating and maintenance |  | 251 |  |  | 226 |  |  | 25 |  |  | 774 |  |  | 921 |  |  | (147 | )
Depreciation and amortization |  | 179 |  |  | 182 |  |  | (3 | ) |  | 511 |  |  | 355 |  |  | 156 |
Taxes other than income |  | 122 |  |  | 124 |  |  | (2 | ) |  | 344 |  |  | 248 |  |  | 96 |
Total operating expenses |  | 1,025 |  |  | 1,115 |  |  | (90 | ) |  | 2,947 |  |  | 2,561 |  |  | 386 |
Gain on sales of assets |  | — |  |  | — |  |  | — |  |  | 1 |  |  | — |  |  | 1 |
Operating income |  | 285 |  |  | 279 |  |  | 6 |  |  | 611 |  |  | 4 |  |  | 607 |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (62 | ) |  | (64 | ) |  | 2 |  |  | (183 | ) |  | (135 | ) |  | (48 | )
Other, net |  | 13 |  |  | 19 |  |  | (6 | ) |  | 40 |  |  | 31 |  |  | 9 |
Total other income and (deductions) |  | (49 | ) |  | (45 | ) |  | (4 | ) |  | (143 | ) |  | (104 | ) |  | (39 | )
Income (loss) before income taxes |  | 236 |  |  | 234 |  |  | 2 |  |  | 468 |  |  | (100 | ) |  | 568 |
Income taxes |  | 83 |  |  | 68 |  |  | 15 |  |  | 109 |  |  | (9 | ) |  | 118 |
Net income (loss) |  | $ | 153 |  |  | $ | 166 |  |  | $ | (13 | ) |  | $ | 359 |  |  | $ | (91 | ) |  | $ | 450 |
|  | Other (b)
|  | Three Months Ended September 30, |  | Nine Months Ended September 30,
|  | 2017 |  | 2016 |  | Variance |  | 2017 |  | 2016 |  | Variance
Operating revenues |  | $ | (316 | ) |  | $ | (524 | ) |  | $ | 208 |  |  | $ | (951 | ) |  | $ | (1,187 | ) |  | $ | 236 |
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | (295 | ) |  | (504 | ) |  | 209 |  |  | (890 | ) |  | (1,128 | ) |  | 238 |
Operating and maintenance |  | (43 | ) |  | 22 |  |  | (65 | ) |  | (136 | ) |  | 118 |  |  | (254 | )
Depreciation and amortization |  | 20 |  |  | 17 |  |  | 3 |  |  | 65 |  |  | 55 |  |  | 10 |
Taxes other than income |  | 10 |  |  | 3 |  |  | 7 |  |  | 25 |  |  | 20 |  |  | 5 |
Total operating expenses |  | (308 | ) |  | (462 | ) |  | 154 |  |  | (936 | ) |  | (935 | ) |  | (1 | )
Gain on sales of assets |  | 1 |  |  | — |  |  | 1 |  |  | — |  |  | 4 |  |  | (4 | )
Operating loss |  | (7 | ) |  | (62 | ) |  | 55 |  |  | (15 | ) |  | (248 | ) |  | 233 |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (65 | ) |  | (120 | ) |  | 55 |  |  | (221 | ) |  | (229 | ) |  | 8 |
Other, net |  | 4 |  |  | (11 | ) |  | 15 |  |  | 5 |  |  | 1 |  |  | 4 |
Total other income and (deductions) |  | (61 | ) |  | (131 | ) |  | 70 |  |  | (216 | ) |  | (228 | ) |  | 12 |
Loss before income taxes |  | (68 | ) |  | (193 | ) |  | 125 |  |  | (231 | ) |  | (476 | ) |  | 245 |
Income taxes |  | (70 | ) |  | (66 | ) |  | (4 | ) |  | (286 | ) |  | (133 | ) |  | (153 | )
Equity in earnings of unconsolidated affiliates |  | 1 |  |  | 1 |  |  | — |  |  | 1 |  |  | — |  |  | 1 |
Net income (loss) |  | 3 |  |  | (126 | ) |  | 129 |  |  | $ | 56 |  |  | $ | (343 | ) |  | $ | 399 |
Net loss attributable to noncontrolling interests and preference stock dividends |  | — |  |  | (1 | ) |  | 1 |  |  | — |  |  | — |  |  | — |
Net income (loss) attributable to common shareholders |  | $ | 3 |  |  | $ | (125 | ) |  | $ | 128 |  |  | $ | 56 |  |  | $ | (343 | ) |  | $ | 399 |

(a) | PHI includes the consolidated results of Potomac Electric Power Company, Delmarva Power & Light Company and Atlantic City Electric Company beginning on March 24, 2016, the day after the merger was completed.

(b) | Other primarily includes eliminating and consolidating adjustments, Exelon’s corporate operations, shared service entities and other financing and investment activities.

5

EXELON CORPORATION
Consolidated Balance Sheets
(unaudited) (in millions)

|  | September 30, 2017 |  | December 31, 2016
Assets |  |  |  |
Current assets |  |  |  |
Cash and cash equivalents |  | $ | 1,203 |  |  | $ | 635 |
Restricted cash and cash equivalents |  | 320 |  |  | 253 |
Deposit with IRS |  | 1,250 |  |  | 1,250 |
Accounts receivable, net |  |  |  |
Customer |  | 3,854 |  |  | 4,158 |
Other |  | 950 |  |  | 1,201 |
Mark-to-market derivative assets |  | 699 |  |  | 917 |
Unamortized energy contract assets |  | 81 |  |  | 88 |
Inventories, net |  |  |  |
Fossil fuel and emission allowances |  | 387 |  |  | 364 |
Materials and supplies |  | 1,281 |  |  | 1,274 |
Regulatory assets |  | 1,264 |  |  | 1,342 |
Other |  | 1,435 |  |  | 930 |
Total current assets |  | 12,724 |  |  | 12,412 |
Property, plant and equipment, net |  | 73,067 |  |  | 71,555 |
Deferred debits and other assets |  |  |  |
Regulatory assets |  | 10,238 |  |  | 10,046 |
Nuclear decommissioning trust funds |  | 12,966 |  |  | 11,061 |
Investments |  | 634 |  |  | 629 |
Goodwill |  | 6,677 |  |  | 6,677 |
Mark-to-market derivative assets |  | 426 |  |  | 492 |
Unamortized energy contract assets |  | 407 |  |  | 447 |
Pledged assets for Zion Station decommissioning |  | 57 |  |  | 113 |
Other |  | 1,277 |  |  | 1,472 |
Total deferred debits and other assets |  | 32,682 |  |  | 30,937 |
Total assets |  | $ | 118,473 |  |  | $ | 114,904 |
Liabilities and shareholders’ equity |  |  |  |
Current liabilities |  |  |  |
Short-term borrowings |  | $ | 710 |  |  | $ | 1,267 |
Long-term debt due within one year |  | 3,164 |  |  | 2,430 |
Accounts payable |  | 3,132 |  |  | 3,441 |
Accrued expenses |  | 3,080 |  |  | 3,460 |
Payables to affiliates |  | 5 |  |  | 8 |
Regulatory liabilities |  | 553 |  |  | 602 |
Mark-to-market derivative liabilities |  | 178 |  |  | 282 |
Unamortized energy contract liabilities |  | 283 |  |  | 407 |
Renewable energy credit obligation |  | 261 |  |  | 428 |
PHI merger related obligation |  | 96 |  |  | 151 |
Other |  | 933 |  |  | 981 |
Total current liabilities |  | 12,395 |  |  | 13,457 |
Long-term debt |  | 31,701 |  |  | 31,575 |
Long-term debt to financing trusts |  | 389 |  |  | 641 |
Deferred credits and other liabilities |  |  |  |
Deferred income taxes and unamortized investment tax credits |  | 19,250 |  |  | 18,138 |
Asset retirement obligations |  | 9,733 |  |  | 9,111 |
Pension obligations |  | 4,055 |  |  | 4,248 |
Non-pension postretirement benefit obligations |  | 1,977 |  |  | 1,848 |
Spent nuclear fuel obligation |  | 1,142 |  |  | 1,024 |
Regulatory liabilities |  | 4,549 |  |  | 4,187 |
Mark-to-market derivative liabilities |  | 410 |  |  | 392 |
Unamortized energy contract liabilities |  | 656 |  |  | 830 |
Payable for Zion Station decommissioning |  | — |  |  | 14 |
Other |  | 1,899 |  |  | 1,827 |
Total deferred credits and other liabilities |  | 43,671 |  |  | 41,619 |
Total liabilities |  | 88,156 |  |  | 87,292 |
Commitments and contingencies |  |  |  |
Shareholders’ equity |  |  |  |
Common stock |  | 18,862 |  |  | 18,794 |
Treasury stock, at cost |  | (123 | ) |  | (2,327 | )
Retained earnings |  | 11,950 |  |  | 12,030 |
Accumulated other comprehensive loss, net |  | (2,589 | ) |  | (2,660 | )
Total shareholders’ equity |  | 28,100 |  |  | 25,837 |
Noncontrolling interests |  | 2,217 |  |  | 1,775 |
Total equity |  | 30,317 |  |  | 27,612 |
Total liabilities and shareholders’ equity |  | $ | 118,473 |  |  | $ | 114,904 |

6

EXELON CORPORATION
Consolidated Statements of Cash Flows
(unaudited)
(in millions)

|  | Nine Months Ended September 30,
|  | 2017 |  | 2016
Cash flows from operating activities |  |  |  |
Net income |  | $ | 1,911 |  |  | $ | 956 |
Adjustments to reconcile net income to net cash flows provided by operating activities: |  |  |  |
Depreciation, amortization and accretion, including nuclear fuel and energy contract amortization |  | 3,999 |  |  | 4,009 |
Impairment of long-lived assets and losses on regulatory assets |  | 488 |  |  | 274 |
Gain on sales of assets |  | (5 | ) |  | (41 | )
Bargain purchase gain |  | (233 | ) |  | — |
Deferred income taxes and amortization of investment tax credits |  | 439 |  |  | 623 |
Net fair value changes related to derivatives |  | 149 |  |  | 100 |
Net realized and unrealized gains on nuclear decommissioning trust fund investments |  | (429 | ) |  | (243 | )
Other non-cash operating activities |  | 603 |  |  | 1,224 |
Changes in assets and liabilities: |  |  |  |
Accounts receivable |  | 224 |  |  | (296 | )
Inventories |  | (87 | ) |  | 21 |
Accounts payable and accrued expenses |  | (593 | ) |  | 296 |
Option premiums received (paid), net |  | 35 |  |  | (24 | )
Collateral (posted) received, net |  | (100 | ) |  | 757 |
Income taxes |  | 167 |  |  | 527 |
Pension and non-pension postretirement benefit contributions |  | (344 | ) |  | (283 | )
Other assets and liabilities |  | (547 | ) |  | (537 | )
Net cash flows provided by operating activities |  | 5,677 |  |  | 7,363 |
Cash flows from investing activities |  |  |  |
Capital expenditures |  | (5,556 | ) |  | (6,368 | )
Proceeds from nuclear decommissioning trust fund sales |  | 6,848 |  |  | 7,914 |
Investment in nuclear decommissioning trust funds |  | (7,044 | ) |  | (8,093 | )
Acquisition of businesses, net |  | (208 | ) |  | (6,896 | )
Proceeds from sales of long-lived assets |  | 219 |  |  | 49 |
Proceeds from termination of direct financing lease investment |  | — |  |  | 360 |
Change in restricted cash |  | (67 | ) |  | (75 | )
Other investing activities |  | (2 | ) |  | (110 | )
Net cash flows used in investing activities |  | (5,810 | ) |  | (13,219 | )
Cash flows from financing activities |  |  |  |
Changes in short-term borrowings |  | (570 | ) |  | (1,014 | )
Proceeds from short-term borrowings with maturities greater than 90 days |  | 621 |  |  | 195 |
Repayments on short-term borrowings with maturities greater than 90 days |  | (610 | ) |  | (452 | )
Issuance of long-term debt |  | 2,616 |  |  | 4,488 |
Retirement of long-term debt |  | (1,728 | ) |  | (944 | )
Retirement of long-term debt to financing trust |  | (250 | ) |  | — |
Restricted proceeds from issuance of long-term debt |  | — |  |  | (30 | )
Redemption of preference stock |  | — |  |  | (190 | )
Sale of noncontrolling interest |  | 396 |  |  | — |
Dividends paid on common stock |  | (921 | ) |  | (873 | )
Common stock issued from treasury stock |  | 1,150 |  |  | — |
Proceeds from employee stock plans |  | 61 |  |  | 36 |
Other financing activities |  | (64 | ) |  | 35 |
Net cash flows provided by financing activities |  | 701 |  |  | 1,251 |
Increase (Decrease) in cash and cash equivalents |  | 568 |  |  | (4,605 | )
Cash and cash equivalents at beginning of period |  | 635 |  |  | 6,502 |
Cash and cash equivalents at end of period |  | $ | 1,203 |  |  | $ | 1,897 |

7

EXELON CORPORATION
GAAP Consolidated Statements of Operations and
Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments
(unaudited)
(in millions, except per share data)

|  | Three Months Ended September 30, 2017 |  |  |  | Three Months Ended September 30, 2016 |  |
|  | GAAP (a) |  | Non-GAAP Adjustments |  |  |  | GAAP (a) |  | Non-GAAP Adjustments |  |
Operating revenues |  | $ | 8,769 |  |  | $ | (39 | ) |  | (b),(d) |  | $ | 9,002 |  |  | $ | (166 | ) |  | (b),(d)
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | 3,542 |  |  | 9 |  |  | (b),(d),(h) |  | 3,754 |  |  | (127 | ) |  | (b),(d),(h)
Operating and maintenance |  | 2,300 |  |  | (60 | ) |  | (e),(g),(h),(i),(m) |  | 2,338 |  |  | (23 | ) |  | (e),(f),(g),(h),(i)
Depreciation and amortization |  | 1,002 |  |  | (106 | ) |  | (h) |  | 1,195 |  |  | (338 | ) |  | (e),(h)
Taxes other than income |  | 456 |  |  | — |  |  |  |  | 449 |  |  | — |  |  |
Total operating expenses |  | 7,300 |  |  |  |  |  |  |  | 7,736 |  |  |  |  |  |
Gain on sales of assets |  | (1 | ) |  | 2 |  |  | (h) |  | 1 |  |  | — |  |  |
Bargain purchase gain |  | 7 |  |  | (7 | ) |  | (l) |  | — |  |  | — |  |  |
Operating income |  | 1,475 |  |  |  |  |  |  |  | 1,267 |  |  |  |  |  |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (386 | ) |  | — |  |  |  |  | (516 | ) |  | 153 |  |  | (j)
Other, net |  | 237 |  |  | (118 | ) |  | (c) |  | 120 |  |  | (39 | ) |  | (c),(j)
Total other income and (deductions) |  | (149 | ) |  |  |  |  |  |  | (396 | ) |  |  |  |  |
Income before income taxes |  | 1,326 |  |  |  |  |  |  |  | 871 |  |  |  |  |  |
Income taxes |  | 452 |  |  | 18 |  |  | (b),(c),(d),(e),(g),(h),(i),(k),(m) |  | 340 |  |  | 108 |  |  | (b),(c),(d)(e),(f),(g),(h),(i),(j)
Equity in losses of unconsolidated affiliates |  | (7 | ) |  | — |  |  |  |  | (5 | ) |  | — |  |  |
Net income |  | 867 |  |  |  |  |  |  |  | 526 |  |  |  |  |  |
Net income attributable to noncontrolling interests and preference stock dividends |  | 43 |  |  | (20 | ) |  | (n) |  | 36 |  |  | (23 | ) |  | (n)
Net income attributable to common shareholders |  | $ | 824 |  |  |  |  |  |  |  | $ | 490 |  |  |  |  |  |
Effective tax rate(o) |  | 34.1 | % |  |  |  |  |  | 39.0 | % |  |  |  |
Earnings per average common share |  |  |  |  |  |  |  |  |  |  |  |
Basic |  | $ | 0.86 |  |  |  |  |  |  | $ | 0.53 |  |  |  |  |
Diluted |  | $ | 0.85 |  |  |  |  |  |  | $ | 0.53 |  |  |  |  |
Average common shares outstanding |  |  |  |  |  |  |  |  |  |  |  |
Basic |  | 962 |  |  |  |  |  |  | 925 |  |  |  |  |
Diluted |  | 965 |  |  |  |  |  |  | 927 |  |  |  |  |
Effect of adjustments on earnings per average diluted common share recorded in accordance with GAAP:
Mark-to-market impact of economic hedging activities (b) |  | $ | (0.05 | ) |  |  |  |  |  | $ | (0.06 | ) |  |
Unrealized gains related to NDT fund investments (c) |  | (0.07 | ) |  |  |  |  |  | (0.07 | ) |  |
Amortization of commodity contract intangibles (d) |  | 0.01 |  |  |  |  |  |  | 0.01 |  |  |
Merger and integration costs (e) |  | — |  |  |  |  |  |  | 0.01 |  |  |
Merger commitments (f) |  | — |  |  |  |  |  |  | 0.01 |  |  |
Long-lived asset impairments (g) |  | 0.03 |  |  |  |  |  |  | 0.01 |  |  |
Plant retirements and divestitures (h) |  | 0.08 |  |  |  |  |  |  | 0.22 |  |  |
Cost management program (i) |  | 0.01 |  |  |  |  |  |  | 0.01 |  |  |
Like-kind exchange tax position (j) |  | — |  |  |  |  |  |  | 0.21 |  |  |
Reassessment of state deferred income taxes (k) |  | (0.02 | ) |  |  |  |  |  | — |  |  |
Bargain purchase gain (l) |  | (0.01 | ) |  |  |  |  |  | — |  |  |
Asset retirement obligation (m) |  | — |  |  |  |  |  |  | — |  |  |
Noncontrolling interests (n) |  | 0.02 |  |  |  |  |  |  | 0.03 |  |  |
Total adjustments |  | $ | — |  |  |  |  |  |  | $ | 0.38 |  |  |

(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) | Adjustment to exclude the unrealized gains and losses on NDT fund investments to the extent not offset by contractual accounting as described in the notes to the consolidated financial statements.

(d) | Adjustment to exclude the non-cash amortization of intangible assets, net, primarily related to commodity contracts recorded at fair value related to the Integrys and ConEdison Solutions acquisitions in 2016, and in 2017, the ConEdison Solutions and FitzPatrick acquisitions.

8

(e) | Adjustment to exclude certain costs associated with mergers and acquisitions, including, if and when applicable, professional fees, employee-related expenses and integration activities related to the PHI acquisition in 2016, and in 2017, the PHI and FitzPatrick acquisitions, offset at PHI by the anticipated recovery of previously incurred PHI acquisition costs.

(f) | Adjustment to exclude costs incurred as part of the settlement orders approving the PHI acquisition.

(g) | Adjustment to exclude charges to earnings related to the impairment of upstream assets at Generation in 2016, and in 2017, impairments of the ExGen Texas Power, LLC assets held for sale.

(h) | Adjustment to exclude accelerated depreciation and amortization expenses associated with Generation's previous decision to early retire the Clinton and Quad Cities nuclear facilities in 2016, and Generation's decision to early retire the Three Mile Island nuclear facility in 2017.

(i) | Adjustment to exclude severance and reorganization costs related to a cost management program.

(j) | Adjustment to exclude the recognition of a penalty and associated interest expense in the third quarter of 2016, as a result of a tax court decision on Exelon’s like-kind exchange tax position.

(k) | Adjustment to exclude the non-cash impact of the remeasurement of state deferred income taxes, primarily as a result of a change in the Illinois statutory tax rate and changes in forecasted apportionment.

(l) | Adjustment to exclude a measurement period adjustment to the bargain purchase gain for the FitzPatrick acquisition.

(m) | Adjustment to exclude a non-cash benefit pursuant to the annual update of the Generation nuclear decommissioning obligation related to the non-regulatory units.

(n) | Adjustment to exclude from Generation’s results the noncontrolling interests related to certain exclusion items, primarily related to the impact of unrealized gains and losses on NDT fund investments at CENG.

(o) | The effective tax rate related to Adjusted (non-GAAP) Operating Earnings is 35.6% and 34.3% for the three months ended September 30, 2017 and September 30, 2016, respectively.

9

EXELON CORPORATION
GAAP Consolidated Statements of Operations and
Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments
(unaudited)
(in millions, except per share data)

|  | Nine Months Ended September 30, 2017 |  |  |  | Nine Months Ended September 30, 2016 |  |
|  | GAAP (a) |  | Non-GAAP Adjustments |  |  |  | GAAP (a) |  | Non-GAAP Adjustments |  |
Operating revenues |  | $ | 25,149 |  |  | $ | 77 |  |  | (b),(d) |  | $ | 23,486 |  |  | $ | 368 |  |  | (b),(d),(e)
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | 10,527 |  |  | (133 | ) |  | (b),(d),(h) |  | 9,462 |  |  | 211 |  |  | (b),(d),(h)
Operating and maintenance |  | 7,732 |  |  | (633 | ) |  | (e),(g),(h),(j),(l) |  | 7,677 |  |  | (956 | ) |  | (e),(f),(g),(h),(j)
Depreciation and amortization |  | 2,814 |  |  | (143 | ) |  | (d),(h) |  | 2,821 |  |  | (452 | ) |  | (e),(h)
Taxes other than income |  | 1,313 |  |  | — |  |  |  |  | 1,168 |  |  | (1 | ) |  | (j)
Total operating expenses |  | 22,386 |  |  |  |  |  |  |  | 21,128 |  |  |  |  |  |
Gain on sales of assets |  | 4 |  |  | 1 |  |  | (h) |  | 41 |  |  | — |  |  |
Bargain purchase gain |  | 233 |  |  | (233 | ) |  | (n) |  | — |  |  | — |  |  |
Operating income |  | 3,000 |  |  |  |  |  |  |  | 2,399 |  |  |  |  |  |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (1,194 | ) |  | 59 |  |  | (g),(k),(m) |  | (1,179 | ) |  | 153 |  |  | (k)
Other, net |  | 725 |  |  | (393 | ) |  | (c),(k) |  | 377 |  |  | (193 | ) |  | (c),(h),(k)
Total other income and (deductions) |  | (469 | ) |  |  |  |  |  |  | (802 | ) |  |  |  |  |
Income before income taxes |  | 2,531 |  |  |  |  |  |  |  | 1,597 |  |  |  |  |  |
Income taxes |  | 595 |  |  | 459 |  |  | (b),(c),(d),(e),(f),(g),(h),(i),(j),(k),(l),(m) |  | 625 |  |  | 419 |  |  | (b),(c),(d),(e),(f),(g),(h),(j),(k)
Equity in losses of unconsolidated affiliates |  | (25 | ) |  | — |  |  |  |  | (16 | ) |  | — |  |  |
Net income |  | 1,911 |  |  |  |  |  |  |  | 956 |  |  |  |  |  |
Net loss attributable to noncontrolling interests and preference stock dividends |  | 12 |  |  | (75 | ) |  | (o) |  | 26 |  |  | (41 | ) |  | (o)
Net income attributable to common shareholders |  | $ | 1,899 |  |  |  |  |  |  |  | $ | 930 |  |  |  |  |  |
Effective tax rate(p) |  | 23.5 | % |  |  |  |  |  | 39.1 | % |  |  |  |
Earnings per average common share |  |  |  |  |  |  |  |  |  |  |  |
Basic |  | $ | 2.02 |  |  |  |  |  |  | $ | 1.01 |  |  |  |  |
Diluted |  | $ | 2.01 |  |  |  |  |  |  | $ | 1.00 |  |  |  |  |
Average common shares outstanding |  |  |  |  |  |  |  |  |  |  |  |
Basic |  | 941 |  |  |  |  |  |  | 924 |  |  |  |  |
Diluted |  | 943 |  |  |  |  |  |  | 926 |  |  |  |  |
Effect of adjustments on earnings per average diluted common share recorded in accordance with GAAP:
Mark-to-market impact of economic hedging activities (b) |  | $ | 0.10 |  |  |  |  |  |  | $ | 0.07 |  |  |
Unrealized gains related to NDT fund investments (c) |  | (0.22 | ) |  |  |  |  |  | (0.13 | ) |  |
Amortization of commodity contract intangibles (d) |  | 0.03 |  |  |  |  |  |  | 0.01 |  |  |
Merger and integration costs (e) |  | 0.04 |  |  |  |  |  |  | 0.10 |  |  |
Merger commitments (f) |  | (0.15 | ) |  |  |  |  |  | 0.43 |  |  |
Long-lived asset impairments (g) |  | 0.31 |  |  |  |  |  |  | 0.11 |  |  |
Plant retirements and divestitures (h) |  | 0.15 |  |  |  |  |  |  | 0.37 |  |  |
Reassessment of state deferred income taxes (i) |  | (0.04 | ) |  |  |  |  |  | — |  |  |
Cost management program (j) |  | 0.03 |  |  |  |  |  |  | 0.03 |  |  |
Like-kind exchange tax position (k) |  | (0.03 | ) |  |  |  |  |  | 0.21 |  |  |
Asset retirement obligation (l) |  | — |  |  |  |  |  |  | — |  |  |
Tax settlements (m) |  | (0.01 | ) |  |  |  |  |  | — |  |  |
Bargain purchase gain (n) |  | (0.25 | ) |  |  |  |  |  | — |  |  |
Noncontrolling interests (o) |  | 0.08 |  |  |  |  |  |  | 0.04 |  |  |
Total adjustments |  | $ | 0.04 |  |  |  |  |  |  | $ | 1.24 |  |  |

As a result of the PHI acquisition completion on March 23, 2016, the table includes financial results for PHI beginning on March 24, 2016 to September 30, 2017. Therefore, the results of operations from 2017 and 2016 are not comparable for Exelon. The explanations below identify any other significant or unusual items affecting the results of operations.

(a) | Results reported in accordance with accounting principles generally accepted in the United States (GAAP).

10

(b) | Adjustment to exclude the mark-to-market impact of Exelon’s economic hedging activities, net of intercompany eliminations.

(c) | Adjustment to exclude the unrealized gains on NDT fund investments to the extent not offset by contractual accounting as described in the notes to the consolidated financial statements.

(d) | Adjustment to exclude the non-cash amortization of intangible assets, net, primarily related to commodity contracts recorded at fair value related to the Integrys and ConEdison Solutions acquisitions in 2016, and in 2017, the ConEdison Solutions and FitzPatrick acquisitions.

(e) | Adjustment to exclude certain costs associated with mergers and acquisitions, including, if and when applicable, professional fees, employee-related expenses and integration activities related to the PHI acquisition in 2016, partially offset at ComEd, BGE and PHI by the anticipated recovery of previously incurred PHI acquisition costs, and in 2017, the PHI and FitzPatrick acquisitions, partially offset at PHI by the anticipated recovery of previously incurred PHI acquisition costs.

(f) | Adjustment to exclude in 2016 costs incurred as part of the settlement orders approving the PHI acquisition, and in 2017, a decrease in reserves for uncertain tax positions related to the deductibility of certain merger commitments associated with the 2012 CEG and 2016 PHI acquisitions.

(g) | Adjustment to exclude charges to earnings related to the impairment of upstream assets and certain wind projects at Generation in 2016, and in 2017, impairments as a result of the ExGen Texas Power, LLC assets held for sale.

(h) | Adjustment to exclude accelerated depreciation and amortization expenses, increases to materials and supplies inventory reserves, charges for severance reserves and construction work in progress impairments associated with Generation's previous decision to early retire the Clinton and Quad Cities nuclear facilities in 2016, and Generation's decision to early retire the Three Mile Island nuclear facility in 2017, partially offset in 2016 by a gain associated with Generation’s sale of the New Boston generating site.

(i) | Adjustment to exclude the non-cash impact of the remeasurement of state deferred income taxes, primarily as a result of changes in forecasted apportionment related to the PHI acquisition in 2016, and in 2017, changes in the Illinois and District of Columbia statutory tax rates and changes in forecasted apportionment.

(j) | Adjustment to exclude severance and reorganization costs related to a cost management program.

(k) | Adjustment to exclude the recognition of a penalty and associated interest expense in 2016 as a result of a tax court decision on Exelon’s like-kind exchange tax position, and adjustments to income tax, penalties and interest expenses in 2017 as a result of the finalization of the IRS tax computation related to Exelon’s like-kind exchange tax position.

(l) | Adjustment to exclude a non-cash benefit pursuant to the annual update of the Generation nuclear decommissioning obligation related to the non-regulatory units.

(m) | Adjustment to exclude benefits related to the favorable settlement in 2017 of certain income tax positions related to PHI's unregulated business interests that were transferred to Generation.

(n) | Adjustment to exclude the excess of the fair value of assets and liabilities acquired over the purchase price for the FitzPatrick acquisition.

(o) | Adjustment to exclude from Generation’s results the noncontrolling interests related to certain exclusion items, primarily related to the impact of unrealized gains and losses on NDT fund investments at CENG.

(p) | The effective tax rate related to Adjusted (non-GAAP) Operating Earnings is 35.7% and 33.4% for the nine months ended September 30, 2017 and September 30, 2016, respectively.

11

EXELON CORPORATION
Reconciliation of Adjusted (non-GAAP) Operating
Earnings to GAAP Net Income (in millions)
Three Months Ended September 30, 2017 and 2016
(unaudited)

|  | Exelon Earnings per Diluted Share |  | Generation |  | ComEd |  | PECO |  | BGE |  | PHI (a) |  | Other(b) |  | Exelon
2016 GAAP Net Income (Loss) |  | $ | 0.53 |  |  | $ | 236 |  |  | $ | 37 |  |  | $ | 122 |  |  | $ | 54 |  |  | $ | 166 |  |  | $ | (125 | ) |  | $ | 490 |
2016 Adjusted (non-GAAP) Operating (Earnings) Loss Adjustments:
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $35) |  | (0.06 | ) |  | (54 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (54 | )
Unrealized Gains Related to NDT Fund Investments (net of taxes of $48) (1) |  | (0.07 | ) |  | (70 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (70 | )
Amortization of Commodity Contract Intangibles (net of taxes of $8) (2) |  | 0.01 |  |  | 13 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 13 |
Merger and Integration Costs (net of taxes of $5, $1, $1, $3, and $10, respectively) (3) |  | 0.01 |  |  | 7 |  |  | — |  |  | 1 |  |  | 1 |  |  | 4 |  |  | — |  |  | 13 |
Merger Commitments (net of taxes of $10, $11 and $1, respectively) (4) |  | 0.01 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (40 | ) |  | 45 |  |  | 5 |
Long-Lived Asset Impairments (net of taxes of $6, $1 and $5) (5) |  | 0.01 |  |  | 10 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 1 |  |  | 11 |
Plant Retirements and Divestitures (net of taxes of $129) (6) |  | 0.22 |  |  | 204 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 204 |
Cost Management Program (net of taxes of $5) (7) |  | 0.01 |  |  | 7 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 7 |
Like-Kind Exchange Tax Position (net of taxes of $42, $19 and $61, respectively) (8) |  | 0.21 |  |  | — |  |  | 149 |  |  | — |  |  | — |  |  | — |  |  | 50 |  |  | 199 |
Noncontrolling Interests (net of taxes of $5) (9) |  | 0.03 |  |  | 23 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 23 |
2016 Adjusted (non-GAAP) Operating Earnings (Loss) |  | 0.91 |  |  | 376 |  |  | 186 |  |  | 123 |  |  | 55 |  |  | 130 |  |  | (29 | ) |  | 841 |
Year Over Year Effects on Earnings:
ComEd, PECO, BGE and PHI Margins: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Weather |  | (0.06 | ) |  | — |  |  | (20 | ) | (c) | (28 | ) |  | — |  | (c) | (6 | ) | (c) | — |  |  | (54 | )
Load |  | (0.01 | ) |  | — |  |  | (3 | ) | (c) | 1 |  |  | — |  | (c) | (4 | ) | (c) | — |  |  | (6 | )
Other Energy Delivery (13) |  | 0.07 |  |  | — |  |  | 23 |  | (d) | 6 |  | (d) | 10 |  | (d) | 26 |  | (d) | — |  |  | 65 |
Generation Energy Margins, Excluding Mark-to-Market: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Nuclear Volume (14) |  | 0.06 |  |  | 59 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 59 |
Nuclear Fuel Cost (15) |  | — |  |  | (2 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (2 | )
Capacity Pricing (16) |  | 0.05 |  |  | 46 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 46 |
Zero Emission Credit Revenue (17) |  | 0.08 |  |  | 73 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 73 |
Market and Portfolio Conditions (18) |  | (0.21 | ) |  | (198 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (198 | )
Operating and Maintenance Expense: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Labor, Contracting and Materials |  | 0.01 |  |  | 5 |  |  | 3 |  |  | (4 | ) |  | 2 |  |  | 1 |  |  | — |  |  | 7 |
Planned Nuclear Refueling Outages (19) |  | — |  |  | 4 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 4 |
Pension and Non-Pension Postretirement Benefits (20) |  | — |  |  | (2 | ) |  | (1 | ) |  | 1 |  |  | 1 |  |  | 1 |  |  | (1 | ) |  | (1 | )
Other Operating and Maintenance (21) |  | 0.04 |  |  | 9 |  |  | 16 |  |  | 5 |  |  | — |  |  | — |  |  | 6 |  |  | 36 |
Depreciation and Amortization Expense (22) |  | (0.02 | ) |  | (6 | ) |  | (10 | ) |  | (3 | ) |  | (5 | ) |  | 2 |  |  | (2 | ) |  | (24 | )
Interest Expense, Net (23) |  | (0.02 | ) |  | (19 | ) |  | 2 |  |  | (1 | ) |  | 1 |  |  | 1 |  |  | 1 |  |  | (15 | )
Income Taxes (24) |  | (0.01 | ) |  | (7 | ) |  | (10 | ) |  | 12 |  |  | — |  |  | (3 | ) |  | (6 | ) |  | (14 | )
Equity in Earnings of Unconsolidated Affiliates |  | — |  |  | (1 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (1 | )
Noncontrolling Interests (25) |  | (0.01 | ) |  | (7 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (7 | )
Other (26) |  | 0.01 |  |  | 17 |  |  | — |  |  | 2 |  |  | — |  |  | (2 | ) |  | (5 | ) |  | 12 |
Share Differential (27) |  | (0.04 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
2017 Adjusted (non-GAAP) Operating Earnings (Loss) |  | 0.85 |  |  | 347 |  |  | 186 |  |  | 114 |  |  | 64 |  |  | 146 |  |  | (36 | ) |  | 821 |
2017 Adjusted (non-GAAP) Operating Earnings (Loss) Adjustments:
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $29) |  | 0.05 |  |  | 46 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (1 | ) |  | 45 |
Unrealized Gains Related to NDT Fund Investments (net of taxes of $45) (1) |  | 0.07 |  |  | 67 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 67 |
Amortization of Commodity Contract Intangibles (net of taxes of $8) (2) |  | (0.01 | ) |  | (12 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (12 | )
Merger and Integration Costs (net of taxes of $5, $6, $0 and $1, respectively) (3) |  | — |  |  | (7 | ) |  | — |  |  | — |  |  | — |  |  | 9 |  |  | (1 | ) |  | 1 |
Long-Lived Asset Impairments (net of taxes of $16, $0 and $16, respectively) (5) |  | (0.03 | ) |  | (25 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | 1 |  |  | (24 | )
Plant Retirements and Divestitures (net of taxes of $46, $1 and $47, respectively) (6) |  | (0.08 | ) |  | (72 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | 1 |  |  | (71 | )
Cost Management Program (net of taxes of $6, $1, $1, $0 and $8, respectively) (7) |  | (0.01 | ) |  | (10 | ) |  | — |  |  | (2 | ) |  | (2 | ) |  | — |  |  | 1 |  |  | (13 | )
Reassessment of State Deferred Income Taxes (entire amount represents tax expense) (10) |  | 0.02 |  |  | (18 | ) |  | 3 |  |  | — |  |  | — |  |  | (2 | ) |  | 38 |  |  | 21 |
Bargain Purchase Gain (net of taxes of $0) (11) |  | 0.01 |  |  | 7 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 7 |
Asset Retirement Obligation (net of taxes of $1) (12) |  | — |  |  | 2 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 2 |
Noncontrolling Interests (net of taxes of $4) (9) |  | (0.02 | ) |  | (20 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (20 | )
2017 GAAP Net Income |  | $ | 0.85 |  |  | $ | 305 |  |  | $ | 189 |  |  | $ | 112 |  |  | $ | 62 |  |  | $ | 153 |  |  | $ | 3 |  |  | $ | 824 |

12

Note:
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 gains and losses related to NDT fund investments, the marginal statutory income tax rates ranged from 39.0 percent to 41.0 percent. Under IRS regulations, NDT fund investment returns are taxed at differing rates for investments in qualified vs. non-qualified funds. The tax rates applied to unrealized gains and losses related to NDT fund investments were 43.2 percent and 52.6 percent for the three months ended September 30, 2017 and 2016, respectively.

(a) | PHI consolidated results includes Potomac Electric Power Company, Delmarva Power & Light Company and Atlantic City Electric Company.

(b) | Other primarily includes eliminating and consolidating adjustments, Exelon’s corporate operations, shared service entities and other financing and investment activities.

(c) | As approved by the Maryland PSC and District of Columbia PSC, customer rates for BGE, Pepco and DPL Maryland are adjusted to eliminate the favorable and unfavorable impacts of weather and usage patterns per customer on distribution volumes. Pursuant to the Illinois Future Energy Jobs Act, beginning in 2017, customer rates for ComEd are adjusted to eliminate the favorable and unfavorable impacts of weather and customer usage patterns on distribution volumes.

(d) | For regulatory recovery mechanisms, including ComEd’s distribution formula rate, ComEd, 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 unrealized gains on NDT fund investments to the extent not offset by contractual accounting as described in the notes to the consolidated financial statements.

(2) | Represents the non-cash amortization of intangible assets, net, primarily related to commodity contracts recorded at fair value related to the Integrys and ConEdison Solutions acquisitions in 2016, and in 2017, the ConEdison Solutions and FitzPatrick acquisitions.

(3) | Reflects certain costs associated with mergers and acquisitions, including, if and when applicable, professional fees, employee-related expenses and integration activities related to the PHI acquisition in 2016, and in 2017, the PHI and FitzPatrick acquisitions, offset at PHI by the anticipated recovery of previously incurred PHI acquisition costs.

(4) | Represents costs incurred as part of the settlement orders approving the PHI acquisition.

(5) | Primarily reflects charges to earnings related to the impairment of upstream assets at Generation in 2016, and in 2017, impairments of the ExGen Texas Power, LLC assets held for sale.

(6) | Primarily reflects accelerated depreciation and amortization expenses associated with Generation's previous decision to early retire the Clinton and Quad Cities nuclear facilities in 2016, and Generation's decision to early retire the Three Mile Island nuclear facility in 2017.

(7) | Represents severance and reorganization costs related to a cost management program.

(8) | Represents the recognition of a penalty and associated interest expense in the third quarter of 2016, as a result of a tax court decision on Exelon’s like-kind exchange tax position.

(9) | Represents elimination from Generation’s results of the noncontrolling interests related to certain exclusion items, primarily related to the impact of unrealized gains and losses on NDT fund investments at CENG.

(10) | Reflects the non-cash impact of the remeasurement of state deferred income taxes, primarily as a result of a change in the Illinois statutory tax rate and changes in forecasted apportionment.

(11) | Represents a measurement period adjustment to the bargain purchase gain for the FitzPatrick acquisition.

(12) | Primarily reflects a non-cash benefit pursuant to the annual update of the Generation nuclear decommissioning obligation related to the non-regulatory units.

(13) | For ComEd, primarily reflects increased electric distribution and transmission formula rate revenues (due to increased capital investments and higher electric distribution ROE, which is due to an increase in treasury rates), partially offset by lower revenues resulting from the change to defer and recover over time energy efficiency costs pursuant to the Illinois Future Energy Jobs Act. For BGE and PHI, primarily reflects increased revenue as a result of rate increases.

(14) | Primarily reflects the acquisition of the FitzPatrick nuclear facility and a decrease in nuclear outage days.

(15) | Primarily reflects increased nuclear output, partially offset by a decrease in fuel prices.

(16) | Primarily reflects increased capacity prices in the New England, Midwest and Mid-Atlantic regions.

(17) | Reflects the impact of the New York Clean Energy Standard.

(18) | Primarily reflects the impacts of lower load volumes delivered due to mild weather and lower realized energy prices related to Exelon's ratable hedging strategy, partially offset by the addition of two combined-cycle gas turbines in Texas.

(19) | Primarily reflects a decrease in the number of nuclear outage days in 2017, excluding Salem.

(20) | Primarily reflects the unfavorable impact of lower pension and OPEB discount rates, partially offset by the favorable impact of lower health care claims experience.

(21) | For ComEd, primarily reflects the change to defer and recover over time energy efficiency costs pursuant to the Illinois Future Energy Jobs Act.

(22) | For Generation, reflects increased depreciation for the addition of two combined-cycle gas turbines in Texas, partially offset by the absence of depreciation due to the EGTP assets held for sale. Additionally, primarily reflects increased depreciation from ongoing capital expenditures across all operating companies.

(23) | For Generation, primarily reflects the impact of project in-service dates on the capitalization of interest and higher outstanding debt.

(24) | For ComEd, reflects the 2017 increase in the Illinois statutory income tax rate. For PECO, primarily reflects an increase in the repairs tax deduction.

(25) | Reflects elimination from Generation’s results of activity attributable to noncontrolling interests, primarily for CENG and the Renewables Joint Venture.

(26) | For Generation, primarily reflects higher realized NDT fund gains.

(27) | Reflects the impact on earnings per share due to the increase in Exelon’s average diluted common shares outstanding as a result of the June 2017 common stock issuance.

13

EXELON CORPORATION
Reconciliation of Adjusted (non-GAAP) Operating
Earnings to GAAP Net Income (in millions)
Nine Months Ended September 30, 2017 and 2016
(unaudited)

|  | Exelon Earnings per Diluted Share |  | Generation |  | ComEd |  | PECO |  | BGE |  | PHI (a) |  | Other (b) |  | Exelon (a)
2016 GAAP Net Income (Loss) |  | $ | 1.00 |  |  | $ | 538 |  |  | $ | 297 |  |  | $ | 346 |  |  | $ | 183 |  |  | $ | (91 | ) |  | $ | (343 | ) |  | $ | 930 |
2016 Adjusted (non-GAAP) Operating (Earnings) Loss Adjustments:
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $46) |  | 0.07 |  |  | 67 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 67 |
Unrealized Gains Related to NDT Fund Investments (net of taxes of $89) (1) |  | (0.13 | ) |  | (127 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (127 | )
Amortization of Commodity Contract Intangibles (net of taxes of $6) (2) |  | 0.01 |  |  | 8 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 8 |
Merger and Integration Costs (net of taxes of $12, $3, $2, $1, $25, $1 and $36, respectively) (3) |  | 0.10 |  |  | 20 |  |  | (3 | ) |  | 2 |  |  | (1 | ) |  | 37 |  |  | 37 |  |  | 92 |
Merger Commitments (net of taxes of $1, $74, $38 and $114, respectively) (4) |  | 0.43 |  |  | 2 |  |  | — |  |  | — |  |  | — |  |  | 239 |  |  | 159 |  |  | 400 |
Long-Lived Asset Impairments (net of taxes of $68, $1 and $67, respectively) (5) |  | 0.11 |  |  | 103 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 1 |  |  | 104 |
Plant Retirements and Divestitures (net of taxes of $214) (6) |  | 0.37 |  |  | 338 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 338 |
Reassessment of State Deferred Income Taxes (entire amount represents tax expense) (7) |  | — |  |  | 6 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (6 | ) |  | — |
Cost Management Program (net of taxes of $13, $2, $2 and $17, respectively) (8) |  | 0.03 |  |  | 22 |  |  | — |  |  | 2 |  |  | 2 |  |  | — |  |  | — |  |  | 26 |
Like-Kind Exchange Tax Position (net of taxes of $42, $19 and $61, respectively) (9) |  | 0.21 |  |  | — |  |  | 149 |  |  | — |  |  | — |  |  | — |  |  | 50 |  |  | 199 |
Noncontrolling Interests (net of taxes of $8) (10) |  | 0.04 |  |  | 41 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 41 |
2016 Adjusted (non-GAAP) Operating Earnings (Loss) |  | 2.24 |  |  | 1,018 |  |  | 443 |  |  | 350 |  |  | 184 |  |  | 185 |  |  | (102 | ) |  | 2,078 |
Year Over Year Effects on Earnings:
ComEd, PECO, BGE and PHI Margins: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Weather |  | (0.07 | ) |  | — |  |  | (22 | ) | (c) | (28 | ) |  | — |  | (c) | (12 | ) | (c) | — |  |  | (62 | )
Load |  | (0.01 | ) |  | — |  |  | (7 | ) | (c) | (4 | ) |  | — |  | (c) | 4 |  | (c) | — |  |  | (7 | )
Other Energy Delivery (14) |  | 0.60 |  |  | — |  |  | 90 |  | (d) | (4 | ) | (d) | 49 |  | (d) | 431 |  | (d) | — |  |  | 566 |
Generation Energy Margins, Excluding Mark-to-Market: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Nuclear Volume (15) |  | 0.07 |  |  | 69 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 69 |
Nuclear Fuel Cost (16) |  | 0.01 |  |  | 12 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 12 |
Capacity Pricing (17) |  | 0.02 |  |  | 15 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 15 |
Zero Emission Credit Revenue (18) |  | 0.13 |  |  | 118 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 118 |
Market and Portfolio Conditions (19) |  | (0.35 | ) |  | (329 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (329 | )
Operating and Maintenance Expense: |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Labor, Contracting and Materials (20) |  | (0.13 | ) |  | (46 | ) |  | 7 |  |  | (8 | ) |  | 1 |  |  | (83 | ) |  | — |  |  | (129 | )
Planned Nuclear Refueling Outages (21) |  | (0.07 | ) |  | (65 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (65 | )
Pension and Non-Pension Postretirement Benefits (22) |  | (0.01 | ) |  | (2 | ) |  | (1 | ) |  | 1 |  |  | 2 |  |  | (5 | ) |  | (2 | ) |  | (7 | )
Other Operating and Maintenance (23) |  | (0.03 | ) |  | (37 | ) |  | 4 |  |  | 13 |  |  | 35 |  |  | (62 | ) |  | 19 |  |  | (28 | )
Depreciation and Amortization Expense (24) |  | (0.19 | ) |  | (16 | ) |  | (34 | ) |  | (7 | ) |  | (24 | ) |  | (92 | ) |  | (6 | ) |  | (179 | )
Interest Expense, Net (25) |  | (0.08 | ) |  | (28 | ) |  | 5 |  |  | (1 | ) |  | (3 | ) |  | (29 | ) |  | (18 | ) |  | (74 | )
Income Taxes (26) |  | (0.02 | ) |  | (24 | ) |  | (13 | ) |  | 14 |  |  | (9 | ) |  | 5 |  |  | 4 |  |  | (23 | )
Equity in Earnings of Unconsolidated Affiliates |  | (0.01 | ) |  | (6 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (6 | )
Noncontrolling Interests (27) |  | 0.03 |  |  | 25 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 25 |
Other (28) |  | (0.04 | ) |  | 17 |  |  | (4 | ) |  | 6 |  |  | 1 |  |  | (52 | ) |  | (7 | ) |  | (39 | )
Share Differential (29) |  | (0.04 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
2017 Adjusted (non-GAAP) Operating Earnings (Loss) |  | 2.05 |  |  | 721 |  |  | 468 |  |  | 332 |  |  | 236 |  |  | 290 |  |  | (112 | ) |  | 1,935 |
2017 Adjusted (non-GAAP) Operating Earnings (Loss) Adjustments:
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $62) |  | (0.10 | ) |  | (98 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | 1 |  |  | (97 | )
Unrealized Gains Related to NDT Fund Investments (net of taxes of $137) (1) |  | 0.22 |  |  | 211 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 211 |
Amortization of Commodity Contract Intangibles (net of taxes of $17) (2) |  | (0.03 | ) |  | (27 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (27 | )
Merger and Integration Costs (net of taxes of $28, $0, $1, $1, $6, $0 and $24, respectively) (3) |  | (0.04 | ) |  | (44 | ) |  | (1 | ) |  | (2 | ) |  | (2 | ) |  | 11 |  |  | (1 | ) |  | (39 | )
Merger Commitments (net of taxes of $18, $52, $67 and $137, respectively) (4) |  | 0.15 |  |  | 18 |  |  | — |  |  | — |  |  | — |  |  | 59 |  |  | 60 |  |  | 137 |
Long-Lived Asset Impairments (net of taxes of $187, $1 and $188, respectively) (5) |  | (0.31 | ) |  | (294 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | 1 |  |  | (293 | )
Plant Retirements and Divestitures (net of taxes of $88, $1 and $89, respectively) (6) |  | (0.15 | ) |  | (138 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | 1 |  |  | (137 | )
Reassessment of State Deferred Income Taxes (entire amount represents tax expense) (7) |  | 0.04 |  |  | (18 | ) |  | 3 |  |  | — |  |  | — |  |  | (1 | ) |  | 58 |  |  | 42 |
Cost Management Program (net of taxes of $11, $2, $2, $0 and $15, respectively) (8) |  | (0.03 | ) |  | (17 | ) |  | — |  |  | (3 | ) |  | (3 | ) |  | — |  |  | (1 | ) |  | (24 | )
Like-Kind Exchange Tax Position (net of taxes of $9, $75 and $66, respectively) (9) |  | 0.03 |  |  | — |  |  | (23 | ) |  | — |  |  | — |  |  | — |  |  | 49 |  |  | 26 |
Asset Retirement Obligation (net of taxes of $1) (11) |  | — |  |  | 2 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 2 |
Tax Settlements (net of taxes of $1) (12) |  | 0.01 |  |  | 5 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 5 |
Bargain Purchase Gain (net of taxes of $0) (13) |  | 0.25 |  |  | 233 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 233 |
Noncontrolling Interests (net of taxes of $16) (10) |  | (0.08 | ) |  | (75 | ) |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (75 | )
2017 GAAP Net Income |  | $ | 2.01 |  |  | $ | 479 |  |  | $ | 447 |  |  | $ | 327 |  |  | $ | 231 |  |  | $ | 359 |  |  | $ | 56 |  |  | $ | 1,899 |

14

Note:
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 gains and losses related to NDT fund investments, the marginal statutory income tax rates ranged from 39.0 percent to 41.0 percent. Under IRS regulations, NDT fund investment returns are taxed at differing rates for investments in qualified vs. non-qualified funds. The tax rates applied to unrealized gains and losses related to NDT fund investments were 46.2 percent and 52.5 percent for the nine months ended September 30, 2017 and 2016, respectively.

(a) | For the nine months ended September 30, 2016, includes financial results for PHI beginning on March 24, 2016, the day after the merger was completed. Therefore, the results of operations from 2017 and 2016 are not comparable for PHI and Exelon. The explanations below identify any other significant or unusual items affecting the results of operations. PHI consolidated results includes Potomac Electric Power Company, Delmarva Power & Light Company and Atlantic City Electric Company.

(b) | Other primarily includes eliminating and consolidating adjustments, Exelon’s corporate operations, shared service entities and other financing and investment activities.

(c) | As approved by the Maryland PSC and District of Columbia PSC, customer rates for BGE, Pepco and DPL Maryland are adjusted to eliminate the favorable and unfavorable impacts of weather and usage patterns per customer on distribution volumes. Pursuant to the Illinois Future Energy Jobs Act, beginning in 2017, customer rates for ComEd are adjusted to eliminate the favorable and unfavorable impacts of weather and customer usage patterns on distribution volumes.

(d) | For regulatory recovery mechanisms, including ComEd’s distribution formula rate, ComEd, 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 unrealized gains on NDT fund investments to the extent not offset by contractual accounting as described in the notes to the consolidated financial statements.

(2) | Represents the non-cash amortization of intangible assets, net, primarily related to commodity contracts recorded at fair value related to the Integrys and ConEdison Solutions acquisitions in 2016, and in 2017, the ConEdison Solutions and FitzPatrick acquisitions.

(3) | Reflects certain costs associated with mergers and acquisitions, including, if and when applicable, professional fees, employee-related expenses and integration activities related to the PHI acquisition in 2016, partially offset at ComEd, BGE and PHI by the anticipated recovery of previously incurred PHI acquisition costs, and in 2017, the PHI and FitzPatrick acquisitions, partially offset at PHI by the anticipated recovery of previously incurred PHI acquisition costs.

(4) | Primarily reflects in 2016 costs incurred as part of the settlement orders approving the PHI acquisition, and in 2017, a decrease in reserves for uncertain tax positions related to the deductibility of certain merger commitments associated with the 2012 CEG and 2016 PHI acquisitions.

(5) | Primarily reflects charges to earnings related to the impairment of upstream assets and certain wind projects at Generation in 2016, and in 2017, impairments as a result of the ExGen Texas Power, LLC assets held for sale.

(6) | Primarily reflects accelerated depreciation and amortization expenses, increases to materials and supplies inventory reserves, charges for severance reserves and construction work in progress impairments associated with Generation's previous decision to early retire the Clinton and Quad Cities nuclear facilities in 2016, and Generation's decision to early retire the Three Mile Island nuclear facility in 2017, partially offset in 2016 by a gain associated with Generation’s sale of the New Boston generating site.

(7) | Reflects the non-cash impact of the remeasurement of state deferred income taxes, primarily as a result of changes in forecasted apportionment related to the PHI acquisition in 2016, and in 2017, changes in the Illinois and District of Columbia statutory tax rates and changes in forecasted apportionment.

(8) | Represents severance and reorganization costs related to a cost management program.

(9) | Represents the recognition of a penalty and associated interest expense in 2016 as a result of a tax court decision on Exelon’s like-kind exchange tax position, and adjustments to income tax, penalties and interest expenses in 2017 as a result of the finalization of the IRS tax computation related to Exelon’s like-kind exchange tax position.

(10) | Represents elimination from Generation’s results of the noncontrolling interests related to certain exclusion items, primarily related to the impact of unrealized gains and losses on NDT fund investments at CENG.

(11) | Primarily reflects a non-cash benefit pursuant to the annual update of the Generation nuclear decommissioning obligation related to the non-regulatory units.

(12) | Reflects benefits related to the favorable settlement in 2017 of certain income tax positions related to PHI's unregulated business interests that were transferred to Generation.

(13) | Represents the excess of the fair value of assets and liabilities acquired over the purchase price for the FitzPatrick acquisition.

(14) | For ComEd, primarily reflects increased electric distribution and transmission formula rate revenues (due to increased capital investments and higher electric distribution ROE, which is due to an increase in treasury rates), partially offset by lower revenues resulting from the change to defer and recover over time energy efficiency costs pursuant to the Illinois Future Energy Jobs Act. For BGE and PHI, primarily reflects increased revenue as a result of rate increases.

(15) | Primarily reflects the acquisition of the FitzPatrick nuclear facility.

(16) | Primarily reflects a decrease in fuel prices, partially offset by an increase in nuclear output as a result of the FitzPatrick acquisition.

(17) | Primarily reflects increased capacity prices in the New England region, partially offset by decreased capacity prices in the Mid-Atlantic region.

(18) | Reflects the impact of the New York Clean Energy Standard.

(19) | Primarily reflects the conclusion of the Ginna Reliability Support Services Agreement, the impact of declining natural gas prices on Generation’s natural gas portfolio, the impacts of lower load volumes delivered due to mild weather and lower realized energy prices related to Exelon's ratable hedging strategy, partially offset by the addition of two combined-cycle gas turbines in Texas and the absence of oil inventory write downs in 2017.

(20) | For Generation, primarily reflects increased salaries, wages and contracting costs related to the acquisition of the FitzPatrick nuclear facility.

(21) | Primarily reflects an increase in the number of nuclear outage days in 2017, excluding Salem.

(22) | Primarily reflects the unfavorable impact of lower pension and OPEB discount rates, partially offset by the favorable impact of lower health care claims experience.

(23) | For Generation, includes an increase in nuclear decommissioning obligation expense related to the FitzPatrick nuclear facility. For ComEd, primarily reflects the change to defer and recover over time energy efficiency costs pursuant to the Illinois Future Energy Jobs Act. For PECO, primarily reflects decreased fully recoverable costs associated with regulatory programs. For BGE, primarily reflects certain disallowances contained in 2016 rate case orders and decreased storm costs in the BGE service territory.

(24) | For Generation, reflects increased depreciation for the addition of two combined-cycle gas turbines in Texas, offset by the absence of depreciation due to the EGTP assets held for sale. For BGE, primarily reflects increased amortization due to the initiation of cost recovery of the AMI programs and increased depreciation from AMI program capital expenditures. Additionally, primarily reflects increased depreciation from ongoing capital expenditures across all operating companies.

15

(25) | For Generation, primarily reflects the impact of project in-service dates on the capitalization of interest and higher outstanding debt. For Corporate, primarily reflects increased interest expense due to higher outstanding debt, as well as debt issuance costs related to the April 2017 remarketing of Junior Subordinated Notes due in 2024.

(26) | For Generation, primarily reflects the favorable settlement of certain income tax positions in 2016. For ComEd, reflects the 2017 increase in the Illinois statutory income tax rate. For PECO, primarily reflects an increase in the repairs tax deduction. For BGE, primarily reflects a 2016 cumulative adjustment to tax expense for transmission-related regulatory assets.

(27) | Reflects elimination from Generation’s results of activity attributable to noncontrolling interests, primarily for CENG and the Renewables Joint Venture.

(28) | For Generation, primarily reflects higher realized NDT fund gains, partially offset by increased real estate taxes as a result of the FitzPatrick acquisition.

(29) | Reflects the impact on earnings per share due to the increase in Exelon’s average diluted common shares outstanding as a result of the June 2017 common stock issuance.

16

EXELON CORPORATION
GAAP Consolidated Statements of Operations and
Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments
(unaudited)
(in millions)

|  | Generation |  |
|  | Three Months Ended September 30, 2017 |  |  |  | Three Months Ended September 30, 2016 |  |
|  | GAAP (a) |  | Non-GAAP Adjustments |  |  |  | GAAP (a) |  | Non-GAAP Adjustments |  |
Operating revenues |  | $ | 4,751 |  |  | $ | (39 | ) |  | (b),(d) |  | $ | 5,035 |  |  | $ | (166 | ) |  | (b),(d)
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | 2,331 |  |  | 9 |  |  | (b),(d),(h) |  | 2,589 |  |  | (127 | ) |  | (b),(d),(h)
Operating and maintenance |  | 1,374 |  |  | (68 | ) |  | (e),(g),(h),(j),(l) |  | 1,336 |  |  | (6 | ) |  | (e),(g),(h),(j)
Depreciation and amortization |  | 410 |  |  | (106 | ) |  | (h) |  | 632 |  |  | (338 | ) |  | (e),(h)
Taxes other than income |  | 141 |  |  | — |  |  |  |  | 136 |  |  | — |  |  |
Total operating expenses |  | 4,256 |  |  |  |  |  |  |  | 4,693 |  |  |  |  |
Gain on sales of assets |  | (2 | ) |  | 2 |  |  | (h) |  | — |  |  | — |  |  |
Bargain purchase gain |  | 7 |  |  | (7 | ) |  | (n) |  | — |  |  | — |  |  |
Operating income |  | 500 |  |  |  |  |  |  |  | 342 |  |  |  |  |  |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (113 | ) |  | — |  |  |  |  | (77 | ) |  | — |  |  |
Other, net |  | 209 |  |  | (118 | ) |  | (c) |  | 185 |  |  | (145 | ) |  | (c)
Total other income and (deductions) |  | 96 |  |  |  |  |  |  |  | 108 |  |  |  |  |  |
Income before income taxes |  | 596 |  |  |  |  |  |  |  | 450 |  |  |  |  |  |
Income taxes |  | 240 |  |  | (19 | ) |  | (b),(c),(d),(e),(g),(h),(i)(j),(l) |  | 173 |  |  | 43 |  |  | (b),(c),(d),(e),(g),(h),(j)
Equity in losses of unconsolidated affiliates |  | (8 | ) |  | — |  |  |  |  | (6 | ) |  | — |  |  |
Net income |  | 348 |  |  |  |  |  |  |  | 271 |  |  |  |  |  |
Net income attributable to noncontrolling interests |  | 43 |  |  | (20 | ) |  | (k) |  | 35 |  |  | (23 | ) |  | (k)
Net income attributable to membership interest |  | $ | 305 |  |  |  |  |  |  |  | $ | 236 |  |  |  |  |  |
|  | Nine Months Ended September 30, 2017 |  |  |  | Nine Months Ended September 30, 2016 |  |
|  | GAAP (a) |  | Non-GAAP Adjustments |  |  |  | GAAP (a) |  | Non-GAAP Adjustments |  |
Operating revenues |  | $ | 13,812 |  |  | $ | 77 |  |  | (b), (d) |  | $ | 13,363 |  |  | $ | 376 |  |  | (b),(d)
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | 7,286 |  |  | (133 | ) |  | (b),(d),(h) |  | 6,609 |  |  | 211 |  |  | (b),(d),(h)
Operating and maintenance |  | 4,871 |  |  | (630 | ) |  | (e),(g),(h),(j),(l) |  | 4,333 |  |  | (335 | ) |  | (e),(f),(g),(h),(j)
Depreciation and amortization |  | 1,046 |  |  | (143 | ) |  | (d),(h) |  | 1,329 |  |  | (452 | ) |  | (e),(h)
Taxes other than income |  | 425 |  |  | — |  |  |  |  | 380 |  |  | (1 | ) |  | (j)
Total operating expenses |  | 13,628 |  |  |  |  |  |  |  | 12,651 |  |  |  |  |  |
Gain on sales of assets |  | 3 |  |  | 1 |  |  | (h) |  | 31 |  |  | — |  |  |
Bargain purchase gain |  | 233 |  |  | (233 | ) |  | (n) |  | — |  |  | — |  |  |
Operating income |  | 420 |  |  |  |  |  |  |  | 743 |  |  |  |  |  |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (342 | ) |  | 18 |  |  | (g),(m) |  | (273 | ) |  | — |  |  |
Other, net |  | 648 |  |  | (392 | ) |  | (c) |  | 395 |  |  | (299 | ) |  | (c),(h)
Total other income and (deductions) |  | 306 |  |  |  |  |  |  |  | 122 |  |  |  |  |  |
Income before income taxes |  | 726 |  |  |  |  |  |  |  | 865 |  |  |  |  |  |
Income taxes |  | 209 |  |  | 210 |  |  | (b),(c),(d),(e),(f),(g),(h),(i),(j),(l),(m) |  | 293 |  |  | 215 |  |  | (b),(c),(d),(e),(f),(g),(h),(i),(j)
Equity in losses of unconsolidated affiliates |  | (26 | ) |  | — |  |  |  |  | (16 | ) |  | — |  |  |
Net income |  | 491 |  |  |  |  |  |  |  | 556 |  |  |  |  |  |
Net income attributable to noncontrolling interests |  | 12 |  |  | (75 | ) |  | (k) |  | 18 |  |  | (41 | ) |  | (k)
Net income attributable to membership interest |  | $ | 479 |  |  |  |  |  |  |  | $ | 538 |  |  |  |  |  |

17

(a) | Results reported in accordance with GAAP.

(b) | Adjustment to exclude the mark-to-market impact of Exelon’s economic hedging activities, net of intercompany eliminations.

(c) | Adjustment to exclude the unrealized gains on NDT fund investments to the extent not offset by contractual accounting as described in the notes to the consolidated financial statements.

(d) | Adjustment to exclude the non-cash amortization of intangible assets, net, primarily related to commodity contracts recorded at fair value related to the Integrys and ConEdison Solutions acquisitions in 2016, and in 2017, the ConEdison Solutions and FitzPatrick acquisitions.

(e) | Adjustment to exclude costs associated with mergers and acquisitions, including, if and when applicable, professional fees, employee-related expenses and integration activities related to the PHI acquisition in 2016, partially offset at ComEd, BGE and PHI by the anticipated recovery of previously incurred PHI acquisition costs, and in 2017, the PHI and FitzPatrick acquisitions, partially offset at PHI by the anticipated recovery of previously incurred PHI acquisition costs.

(f) | Adjustment to exclude 2016 costs incurred as part of the settlement orders approving the PHI acquisition, and in 2017, a decrease in reserves for uncertain tax positions related to the deductibility of certain merger commitments associated with the 2012 CEG and 2016 PHI acquisitions.

(g) | Adjustment to exclude charges to earnings related to the impairment of upstream assets and certain wind projects at Generation in 2016, and in 2017, impairments as a result of the ExGen Texas Power, LLC assets held for sale.

(h) | Adjustment to exclude accelerated depreciation and amortization expenses, increases to materials and supplies inventory reserves, charges for severance reserves and construction work in progress impairments associated with Generation's previous decision to early retire the Clinton and Quad Cities nuclear facilities in 2016, and Generation's decision to early retire the Three Mile Island nuclear facility in 2017, partially offset in 2016 by a gain associated with Generation’s sale of the New Boston generating site.

(i) | Adjustment to exclude the non-cash impact of the remeasurement of state deferred income taxes, primarily as a result of changes in forecasted apportionment related to the PHI acquisition in 2016, and in 2017, changes in the Illinois and District of Columbia statutory tax rates and changes in forecasted apportionment.

(j) | Adjustment to exclude severance and reorganization costs related to a cost management program.

(k) | Adjustment to exclude from Generation’s results the noncontrolling interests related to certain exclusion items, primarily related to the impact of unrealized gains and losses on NDT fund investments at CENG.

(l) | Adjustment to exclude a non-cash benefit pursuant to the annual update of the Generation nuclear decommissioning obligation related to the non-regulatory units.

(m) | Adjustment to exclude benefits related to the favorable settlement in 2017 of certain income tax positions related to PHI's unregulated business interests that were transferred to Generation.

(n) | Adjustments to exclude the excess of the fair value of assets and liabilities acquired over the purchase price for the FitzPatrick acquisition.

18

EXELON CORPORATION
GAAP Consolidated Statements of Operations and
Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments
(unaudited)
(in millions)

|  | ComEd |  |
|  | Three Months Ended September 30, 2017 |  |  |  | Three Months Ended September 30, 2016 |  |
|  | GAAP (a) |  | Non-GAAP Adjustments |  |  |  | GAAP (a) |  | Non-GAAP Adjustments |  |
Operating revenues |  | $ | 1,571 |  |  | $ | — |  |  |  |  | $ | 1,497 |  |  | $ | — |  |  |
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | 529 |  |  | — |  |  |  |  | 454 |  |  | — |  |  |
Operating and maintenance |  | 346 |  |  | — |  |  |  |  | 377 |  |  | — |  |  |
Depreciation and amortization |  | 212 |  |  | — |  |  |  |  | 196 |  |  | — |  |  |
Taxes other than income |  | 80 |  |  | — |  |  |  |  | 82 |  |  | — |  |  |
Total operating expenses |  | 1,167 |  |  |  |  |  |  | 1,109 |  |  |  |  |
Gain on sales of assets |  | — |  |  | — |  |  |  |  | 1 |  |  | — |  |  |
Operating income |  | 404 |  |  |  |  |  |  | 389 |  |  |  |  |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (89 | ) |  | — |  |  |  |  | (197 | ) |  | 105 |  |  | (c)
Other, net |  | 5 |  |  | — |  |  |  |  | (80 | ) |  | 86 |  |  | (c)
Total other income and (deductions) |  | (84 | ) |  |  |  |  |  |  | (277 | ) |  |  |  |
Income before income taxes |  | 320 |  |  |  |  |  |  |  | 112 |  |  |  |  |
Income taxes |  | 131 |  |  | 3 |  |  | (d) |  | 75 |  |  | 42 |  |  | (c)
Net income |  | $ | 189 |  |  |  |  |  |  |  | $ | 37 |  |  |  |  |  |
|  | Nine Months Ended September 30, 2017 |  |  |  | Nine Months Ended September 30, 2016 |  |
|  | GAAP (a) |  | Non-GAAP Adjustments |  |  |  | GAAP (a) |  | Non-GAAP Adjustments |  |
Operating revenues |  | $ | 4,227 |  |  | $ | — |  |  |  |  | $ | 4,031 |  |  | $ | (8 | ) |  | (b)
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | 1,241 |  |  | — |  |  |  |  | 1,141 |  |  | — |  |  |
Operating and maintenance |  | 1,096 |  |  | (1 | ) |  | (b) |  | 1,113 |  |  | (2 | ) |  | (b)
Depreciation and amortization |  | 631 |  |  | — |  |  |  |  | 574 |  |  | — |  |  |
Taxes other than income |  | 223 |  |  | — |  |  |  |  | 222 |  |  | — |  |  |
Total operating expenses |  | 3,191 |  |  |  |  |  |  | 3,050 |  |  |  |  |
Gain on sales of assets |  | — |  |  | — |  |  |  |  | 6 |  |  | — |  |  |
Operating income |  | 1,036 |  |  |  |  |  |  |  | 987 |  |  |  |  |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (275 | ) |  | 14 |  |  | (c) |  | (374 | ) |  | 105 |  |  | (c)
Other, net |  | 14 |  |  | — |  |  |  |  | (72 | ) |  | 86 |  |  | (c)
Total other income and (deductions) |  | (261 | ) |  |  |  |  |  |  | (446 | ) |  |  |  |  |
Income before income taxes |  | 775 |  |  |  |  |  |  |  | 541 |  |  |  |  |  |
Income taxes |  | 328 |  |  | (6 | ) |  | (b),(c),(d) |  | 244 |  |  | 39 |  |  | (b),(c)
Net income |  | $ | 447 |  |  |  |  |  |  |  | $ | 297 |  |  |  |  |  |

(a) | Results reported in accordance with GAAP.

(b) | Adjustment to exclude certain costs associated with mergers and acquisitions, including, if and when applicable, professional fees, employee-related expenses and integration activities related to the PHI acquisition, partially offset in 2016 at ComEd by the anticipated recovery of previously incurred PHI acquisition costs.

(c) | Adjustment to exclude the recognition of a penalty and associated interest expense in 2016 as a result of a tax court decision on Exelon's like-kind exchange tax position, and adjustments to income tax, penalties and interest expenses in 2017 as a result of the finalization of the IRS tax computation related toExelon's like-kind exchange tax position.

19

(d) | Adjustment to exclude the non-cash impact of the remeasurement of state deferred income taxes, primarily as a result of changes in forecasted apportionment related to changes in the Illinois statutory tax rate and changes in forecasted apportionment.

20

EXELON CORPORATION
GAAP Consolidated Statements of Operations and
Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments
(unaudited)
(in millions)

|  | PECO |  |
|  | Three Months Ended September 30, 2017 |  |  |  | Three Months Ended September 30, 2016 |  |
|  | GAAP (a) |  | Non-GAAP Adjustments |  |  |  | GAAP (a) |  | Non-GAAP Adjustments |  |
Operating revenues |  | $ | 715 |  |  | $ | — |  |  |  |  | $ | 788 |  |  | $ | — |  |  |
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | 235 |  |  | — |  |  |  |  | 272 |  |  | — |  |  |
Operating and maintenance |  | 197 |  |  | (3 | ) |  | (c) |  | 199 |  |  | (2 | ) |  | (b)
Depreciation and amortization |  | 72 |  |  | — |  |  |  |  | 67 |  |  | — |  |  |
Taxes other than income |  | 42 |  |  | — |  |  |  |  | 46 |  |  | — |  |  |
Total operating expenses |  | 546 |  |  |  |  |  |  | 584 |  |  |  |  |
Operating income |  | 169 |  |  |  |  |  |  | 204 |  |  |  |  |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (31 | ) |  | — |  |  |  |  | (30 | ) |  | — |  |  |
Other, net |  | 2 |  |  | — |  |  |  |  | 2 |  |  | — |  |  |
Total other income and (deductions) |  | (29 | ) |  |  |  |  |  |  | (28 | ) |  |  |  |
Income before income taxes |  | 140 |  |  |  |  |  |  |  | 176 |  |  |  |  |  |
Income taxes |  | 28 |  |  | 1 |  |  | (c) |  | 54 |  |  | 1 |  |  | (b)
Net income |  | $ | 112 |  |  |  |  |  |  |  | $ | 122 |  |  |  |  |  |
|  | Nine Months Ended September 30, 2017 |  |  |  | Nine Months Ended September 30, 2016 |  |
|  | GAAP (a) |  | Non-GAAP Adjustments |  |  |  | GAAP (a) |  | Non-GAAP Adjustments |  |
Operating revenues |  | $ | 2,141 |  |  | $ | — |  |  |  |  | $ | 2,293 |  |  | $ | — |  |  |
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | 719 |  |  | — |  |  |  |  | 809 |  |  | — |  |  |
Operating and maintenance |  | 595 |  |  | (8 | ) |  | (b),(c) |  | 604 |  |  | (7 | ) |  | (b),(c)
Depreciation and amortization |  | 213 |  |  | — |  |  |  |  | 201 |  |  | — |  |  |
Taxes other than income |  | 116 |  |  | — |  |  |  |  | 126 |  |  | — |  |  |
Total operating expenses |  | 1,643 |  |  |  |  |  |  | 1,740 |  |  |  |  |
Operating income |  | 498 |  |  |  |  |  |  | 553 |  |  |  |  |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (93 | ) |  | — |  |  |  |  | (92 | ) |  | — |  |  |
Other, net |  | 6 |  |  | — |  |  |  |  | 6 |  |  | — |  |  |
Total other income and (deductions) |  | (87 | ) |  |  |  |  |  |  | (86 | ) |  |  |  |  |
Income before income taxes |  | 411 |  |  |  |  |  |  |  | 467 |  |  |  |  |  |
Income taxes |  | 84 |  |  | 3 |  |  | (b),(c) |  | 121 |  |  | 3 |  |  | (b),(c)
Net income |  | $ | 327 |  |  |  |  |  |  |  | $ | 346 |  |  |  |  |  |

(a) | Results reported in accordance with GAAP.

(b) | Adjustment to exclude certain costs associated with mergers and acquisitions, including, if and when applicable, professional fees, employee-related expenses and integration activities related to the PHI acquisition.

(c) | Adjustment to exclude reorganization costs related to a cost management program.

21

EXELON CORPORATION
GAAP Consolidated Statements of Operations and
Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments
(unaudited)
(in millions)

|  | BGE |  |
|  | Three Months Ended September 30, 2017 |  |  |  | Three Months Ended September 30, 2016 |  |
|  | GAAP (a) |  | Non-GAAP Adjustments |  |  |  | GAAP (a) |  | Non-GAAP Adjustments |  |
Operating revenues |  | $ | 738 |  |  | $ | — |  |  |  |  | $ | 812 |  |  | $ | — |  |  |
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | 269 |  |  | — |  |  |  |  | 360 |  |  | — |  |  |
Operating and maintenance |  | 175 |  |  | (4 | ) |  | (c) |  | 178 |  |  | (1 | ) |  | (b)
Depreciation and amortization |  | 109 |  |  | — |  |  |  |  | 101 |  |  | — |  |  |
Taxes other than income |  | 61 |  |  | — |  |  |  |  | 58 |  |  | — |  |  |
Total operating expenses |  | 614 |  |  |  |  |  |  | 697 |  |  |  |  |
Operating income |  | 124 |  |  |  |  |  |  | 115 |  |  |  |  |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (26 | ) |  | — |  |  |  |  | (28 | ) |  | — |  |  |
Other, net |  | 4 |  |  | — |  |  |  |  | 5 |  |  | — |  |  |
Total other income and (deductions) |  | (22 | ) |  |  |  |  |  |  | (23 | ) |  |  |  |  |
Income before income taxes |  | 102 |  |  |  |  |  |  |  | 92 |  |  |  |  |  |
Income taxes |  | 40 |  |  | 2 |  |  | (c) |  | 36 |  |  | — |  |  |
Net income |  | 62 |  |  |  |  |  |  |  | 56 |  |  |  |  |  |
Preference stock dividends |  | — |  |  |  |  |  |  | 2 |  |  |  |  |
Net income attributable to common shareholder |  | $ | 62 |  |  |  |  |  |  |  | $ | 54 |  |  |  |  |  |
|  | Nine Months Ended September 30, 2017 |  |  |  | Nine Months Ended September 30, 2016 |  |
|  | GAAP (a) |  | Non-GAAP Adjustments |  |  |  | GAAP (a) |  | Non-GAAP Adjustments |  |
Operating revenues |  | $ | 2,363 |  |  | $ | — |  |  |  |  | $ | 2,421 |  |  | $ | — |  |  |
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | 853 |  |  | — |  |  |  |  | 994 |  |  | — |  |  |
Operating and maintenance |  | 532 |  |  | (9 | ) |  | (b),(c) |  | 588 |  |  | (2 | ) |  | (b),(c)
Depreciation and amortization |  | 348 |  |  | — |  |  |  |  | 307 |  |  | — |  |  |
Taxes other than income |  | 180 |  |  | — |  |  |  |  | 172 |  |  | — |  |  |
Total operating expenses |  | 1,913 |  |  |  |  |  |  |  | 2,061 |  |  |  |  |  |
Operating income |  | 450 |  |  |  |  |  |  |  | 360 |  |  |  |  |  |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (80 | ) |  | — |  |  |  |  | (76 | ) |  | — |  |  |
Other, net |  | 12 |  |  | — |  |  |  |  | 16 |  |  | — |  |  |
Total other income and (deductions) |  | (68 | ) |  |  |  |  |  |  | (60 | ) |  |  |  |  |
Income before income taxes |  | 382 |  |  |  |  |  |  |  | 300 |  |  |  |  |  |
Income taxes |  | 151 |  |  | 4 |  |  | (b),(c) |  | 109 |  |  | 1 |  |  | (b),(c)
Net income |  | 231 |  |  |  |  |  |  |  | 191 |  |  |  |  |
Preference stock dividends |  | — |  |  |  |  |  |  | 8 |  |  |  |  |
Net income attributable to common shareholder |  | $ | 231 |  |  |  |  |  |  |  | $ | 183 |  |  |  |  |  |

(a) | Results reported in accordance with GAAP.

22

(b) | Adjustment to exclude certain costs associated with mergers and acquisitions, including, if and when applicable, professional fees, employee-related expenses and integration activities related to the PHI acquisition, partially offset in 2016 at BGE by the anticipated recovery of previously incurred PHI acquisition costs.

(c) | Adjustment to exclude reorganization costs related to a cost management program.

23

EXELON CORPORATION
GAAP Consolidated Statements of Operations and
Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments
(unaudited)
(in millions)

|  | PHI |  |
|  | Three Months Ended September 30, 2017 |  |  |  | Three Months Ended September 30, 2016 |  |
|  | GAAP (a) |  | Non-GAAP Adjustments |  |  |  | GAAP (a) |  | Non-GAAP Adjustments |  |
Operating revenues |  | $ | 1,310 |  |  | $ | — |  |  |  |  | $ | 1,394 |  |  | $ | — |  |  |
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | 473 |  |  | — |  |  |  |  | 583 |  |  | — |  |  |
Operating and maintenance |  | 251 |  |  | 15 |  |  | (c) |  | 226 |  |  | 43 |  |  | (c),(d)
Depreciation and amortization |  | 179 |  |  | — |  |  |  |  | 182 |  |  | — |  |  |
Taxes other than income |  | 122 |  |  | — |  |  |  |  | 124 |  |  | — |  |  |
Total operating expenses |  | 1,025 |  |  |  |  |  |  | 1,115 |  |  |  |  |
Operating income |  | 285 |  |  |  |  |  |  | 279 |  |  |  |  |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (62 | ) |  | — |  |  |  |  | (64 | ) |  | — |  |  |
Other, net |  | 13 |  |  | — |  |  |  |  | 19 |  |  | — |  |  |
Total other income and (deductions) |  | (49 | ) |  |  |  |  |  |  | (45 | ) |  |  |  |  |
Income before income taxes |  | 236 |  |  |  |  |  |  |  | 234 |  |  |  |  |  |
Income taxes |  | 83 |  |  | (8 | ) |  | (c),(e) |  | 68 |  |  | (7 | ) |  | (c),(d)
Net income |  | $ | 153 |  |  |  |  |  |  |  | $ | 166 |  |  |  |  |  |
|  | Nine Months Ended September 30, 2017 |  |  |  | Nine Months Ended September 30, 2016 (b) |  |
|  | GAAP (a) |  | Non-GAAP Adjustments |  |  |  | GAAP (a) |  | Non-GAAP Adjustments |  |
Operating revenues |  | $ | 3,557 |  |  | $ | — |  |  |  |  | $ | 2,565 |  |  | $ | — |  |  |
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | 1,318 |  |  | — |  |  |  |  | 1,037 |  |  | — |  |  |
Operating and maintenance |  | 774 |  |  | 25 |  |  | (c),(d) |  | 921 |  |  | (375 | ) |  | (c),(d)
Depreciation and amortization |  | 511 |  |  | — |  |  |  |  | 355 |  |  | — |  |  |
Taxes other than income |  | 344 |  |  | — |  |  |  |  | 248 |  |  | — |  |  |
Total operating expenses |  | 2,947 |  |  |  |  |  |  |  | 2,561 |  |  |  |  |  |
Gain on sales of assets |  | 1 |  |  | — |  |  |  |  | — |  |  | — |  |  |
Operating income (loss) |  | 611 |  |  |  |  |  |  |  | 4 |  |  |  |  |  |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (183 | ) |  | — |  |  |  |  | (135 | ) |  | — |  |  |
Other, net |  | 40 |  |  | — |  |  |  |  | 31 |  |  | — |  |  |
Total other income and (deductions) |  | (143 | ) |  |  |  |  |  |  | (104 | ) |  |  |  |  |
Income (loss) before income taxes |  | 468 |  |  |  |  |  |  |  | (100 | ) |  |  |  |  |
Income taxes |  | 109 |  |  | 44 |  |  | (c),(d),(e) |  | (9 | ) |  | 99 |  |  | (c),(d)
Net income (loss) |  | $ | 359 |  |  |  |  |  |  |  | $ | (91 | ) |  |  |  |  |

(a) | Results reported in accordance with GAAP.

(b) | For the nine months ended September 30, 2016, includes financial results for PHI beginning on March 24, 2016, the day after the merger was completed. Therefore, the results of operations from 2017 and 2016 are not comparable for PHI and Exelon. The explanations below identify any other significant or unusual items affecting the results of operations. PHI consolidated results includes Potomac Electric Power Company, Delmarva Power & Light Company, and Atlantic City Electric Company.

(c) | Adjustment to exclude certain costs associated with mergers and acquisitions, including, if and when applicable, professional fees, employee-related expenses and integration activities related to the PHI acquisition, partially offset in 2016 and 2017 at PHI by the anticipated recovery of previously incurred acquisition costs.

24

(d) | Adjustment to exclude in 2016 costs incurred as part of the settlement orders approving the PHI acquisition, and in 2017, a decrease in reserves for uncertain tax positions related to the deductibility of certain merger commitments associated with the 2016 PHI acquisition.

(e) | Adjustment to exclude the non-cash impact of the remeasurement of state deferred income taxes, primarily as a result of changes in forecasted apportionment.

25

EXELON CORPORATION
GAAP Consolidated Statements of Operations and
Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments
(unaudited)
(in millions)

|  | Other (a) |  |
|  | Three Months Ended September 30, 2017 |  |  |  | Three Months Ended September 30, 2016 |  |
|  | GAAP (b) |  | Non-GAAP Adjustments |  |  |  | GAAP (b) |  | Non-GAAP Adjustments |  |
Operating revenues |  | $ | (316 | ) |  | $ | — |  |  |  |  | $ | (524 | ) |  | $ | — |  |  |
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | (295 | ) |  | — |  |  |  |  | (504 | ) |  | — |  |  |
Operating and maintenance |  | (43 | ) |  | — |  |  |  |  | 22 |  |  | (57 | ) |  | (e)
Depreciation and amortization |  | 20 |  |  | — |  |  |  |  | 17 |  |  | — |  |  |
Taxes other than income |  | 10 |  |  | — |  |  |  |  | 3 |  |  | — |  |  |
Total operating expenses |  | (308 | ) |  |  |  |  |  |  | (462 | ) |  |  |  |
Gain on sales of assets |  | 1 |  |  | — |  |  |  |  | — |  |  | — |  |  |
Operating loss |  | (7 | ) |  |  |  |  |  |  | (62 | ) |  |  |  |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (65 | ) |  | — |  |  |  |  | (120 | ) |  | 48 |  |  | (j)
Other, net |  | 4 |  |  | — |  |  |  |  | (11 | ) |  | 20 |  |  | (j)
Total other income and (deductions) |  | (61 | ) |  |  |  |  |  |  | (131 | ) |  |  |  |
Loss before income taxes |  | (68 | ) |  |  |  |  |  |  | (193 | ) |  |  |  |
Income taxes |  | (70 | ) |  | 39 |  |  | (c),(d),(f),(g),(h),(i) |  | (66 | ) |  | 29 |  |  | (e),(f),(j)
Equity in earnings of unconsolidated affiliates |  | 1 |  |  | — |  |  |  |  | 1 |  |  | — |  |  |
Net income (loss) |  | 3 |  |  |  |  |  |  |  | (126 | ) |  |  |  |  |
Net loss attributable to noncontrolling interests and preference stock dividends |  | — |  |  |  |  |  |  | (1 | ) |  | — |  |  |
Net income (loss) attributable to common shareholders |  | $ | 3 |  |  |  |  |  |  |  | $ | (125 | ) |  |  |  |  |
|  | Nine Months Ended September 30, 2017 |  |  |  | Nine Months Ended September 30, 2016 |  |
|  | GAAP (b) |  | Non-GAAP Adjustments |  |  |  | GAAP (b) |  | Non-GAAP Adjustments |  |
Operating revenues |  | $ | (951 | ) |  | $ | — |  |  |  |  | $ | (1,187 | ) |  | $ | — |  |  |
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Purchased power and fuel |  | (890 | ) |  | — |  |  |  |  | (1,128 | ) |  | — |  |  |
Operating and maintenance |  | (136 | ) |  | (10 | ) |  | (d),(e),(i) |  | 118 |  |  | (235 | ) |  | (d),(e)
Depreciation and amortization |  | 65 |  |  | — |  |  |  |  | 55 |  |  | — |  |  |
Taxes other than income |  | 25 |  |  | — |  |  |  |  | 20 |  |  | — |  |  |
Total operating expenses |  | (936 | ) |  |  |  |  |  | (935 | ) |  |  |  |
Gain on sales of assets |  | — |  |  | — |  |  |  |  | 4 |  |  | — |  |  |
Operating loss |  | (15 | ) |  |  |  |  |  |  | (248 | ) |  |  |  |
Other income and (deductions) |  |  |  |  |  |  |  |  |  |  |  |
Interest expense, net |  | (221 | ) |  | 27 |  |  | (j) |  | (229 | ) |  | 48 |  |  | (j)
Other, net |  | 5 |  |  | (1 | ) |  | (j) |  | 1 |  |  | 20 |  |  | (j)
Total other income and (deductions) |  | (216 | ) |  |  |  |  |  |  | (228 | ) |  |  |  |
Loss before income taxes |  | (231 | ) |  |  |  |  |  |  | (476 | ) |  |  |  |  |
Income taxes |  | (286 | ) |  | 204 |  |  | (c),(d),(e),(f),(g),(h),(i),(j) |  | (133 | ) |  | 62 |  |  | (d),(e),(f),(h),(j)
Equity in earnings of unconsolidated affiliates |  | 1 |  |  | — |  |  |  |  | — |  |  | — |  |  |
Net income (loss) attributable to common shareholders |  | $ | 56 |  |  |  |  |  |  |  | $ | (343 | ) |  |  |  |

(a) | Other primarily includes eliminating and consolidating adjustments, Exelon’s corporate operations, shared service entities and other financing and investment activities.

26

(b) | Results reported in accordance with GAAP.

(c) | Adjustment to exclude the mark-to-market impact of Exelon’s economic hedging activities, net of intercompany eliminations.

(d) | Adjustment to exclude certain costs associated with mergers and acquisitions, including, if and when applicable, professional fees, employee-related expenses and integration activities related to the PHI acquisition.

(e) | Adjustment to exclude in 2016 costs incurred as part of the settlement orders approving the PHI acquisition, and in 2017, a decrease in reserves for uncertain tax positions related to the deductibility of certain merger commitments associated with the 2016 PHI acquisition.

(f) | Adjustment to exclude the impact of charges to earnings related to the impairment of upstream assets and certain wind projects at Generation in 2016, and in 2017, impairments as a result of the ExGen Texas Power, LLC assets held for sale.

(g) | Adjustment to exclude the impact associated with Generation's decision to early retire the Three Mile Island nuclear facility in 2017.

(h) | Adjustment to exclude the non-cash impact of the remeasurement of state deferred income taxes, primarily as a result of changes in forecasted apportionment related to the PHI acquisition in 2016, and in 2017, changes in the Illinois and District of Columbia statutory tax rates and changes in forecasted apportionment.

(i) | Adjustment to exclude reorganization costs related to a cost management program.

(j) | Adjustment to exclude the recognition of a penalty and associated interest expense in 2016 as a result of a tax court decision on Exelon's like-kind exchange tax position, and adjustments to income tax, penalties and interest expenses in 2017 as a result of the finalization of the IRS tax computation related to Exelon's like-kind exchange tax position.

27

EXELON CORPORATION
Exelon Generation Statistics

|  | Three Months Ended
|  | September 30, 2017 |  | June 30, 2017 |  | March 31, 2017 |  | December 31, 2016 |  | September 30, 2016
Supply (in GWhs) |  |  |  |  |  |  |  |  |  |
Nuclear Generation |  |  |  |  |  |  |  |  |  |
Mid-Atlantic(a) |  | 16,480 |  |  | 15,246 |  |  | 16,545 |  |  | 16,410 |  |  | 15,604 |
Midwest |  | 24,362 |  |  | 22,592 |  |  | 22,468 |  |  | 23,743 |  |  | 24,262 |
New York(a)(f) |  | 6,905 |  |  | 6,227 |  |  | 4,491 |  |  | 4,681 |  |  | 4,843 |
Total Nuclear Generation |  | 47,747 |  |  | 44,065 |  |  | 43,504 |  |  | 44,834 |  |  | 44,709 |
Fossil and Renewables |  |  |  |  |  |  |  |  |  |
Mid-Atlantic |  | 596 |  |  | 899 |  |  | 836 |  |  | 442 |  |  | 706 |
Midwest |  | 218 |  |  | 417 |  |  | 418 |  |  | 442 |  |  | 273 |
New England |  | 1,919 |  |  | 1,925 |  |  | 2,077 |  |  | 1,142 |  |  | 1,886 |
New York |  | 1 |  |  | 1 |  |  | 1 |  |  | 1 |  |  | 1 |
ERCOT |  | 5,703 |  |  | 2,315 |  |  | 1,370 |  |  | 1,056 |  |  | 2,472 |
Other Power Regions(b) |  | 2,149 |  |  | 2,084 |  |  | 1,423 |  |  | 1,935 |  |  | 2,103 |
Total Fossil and Renewables |  | 10,586 |  |  | 7,641 |  |  | 6,125 |  |  | 5,018 |  |  | 7,441 |
Purchased Power |  |  |  |  |  |  |  |  |  |
Mid-Atlantic |  | 2,541 |  |  | 2,901 |  |  | 3,398 |  |  | 2,849 |  |  | 7,139 |
Midwest |  | 217 |  |  | 413 |  |  | 388 |  |  | 400 |  |  | 461 |
New England |  | 4,513 |  |  | 4,343 |  |  | 5,064 |  |  | 4,768 |  |  | 3,927 |
New York |  | — |  |  | — |  |  | 28 |  |  | — |  |  | — |
ERCOT |  | 1,199 |  |  | 1,871 |  |  | 2,655 |  |  | 3,189 |  |  | 2,895 |
Other Power Regions(b) |  | 3,982 |  |  | 3,507 |  |  | 2,868 |  |  | 3,308 |  |  | 3,803 |
Total Purchased Power |  | 12,452 |  |  | 13,035 |  |  | 14,401 |  |  | 14,514 |  |  | 18,225 |
Total Supply/Sales by Region(c) |  |  |  |  |  |  |  |  |  |
Mid-Atlantic(d) |  | 19,617 |  |  | 19,046 |  |  | 20,779 |  |  | 19,701 |  |  | 23,449 |
Midwest(d) |  | 24,797 |  |  | 23,422 |  |  | 23,274 |  |  | 24,585 |  |  | 24,996 |
New England |  | 6,432 |  |  | 6,268 |  |  | 7,141 |  |  | 5,910 |  |  | 5,813 |
New York |  | 6,906 |  |  | 6,228 |  |  | 4,520 |  |  | 4,682 |  |  | 4,844 |
ERCOT |  | 6,902 |  |  | 4,186 |  |  | 4,025 |  |  | 4,245 |  |  | 5,367 |
Other Power Regions(b) |  | 6,131 |  |  | 5,591 |  |  | 4,291 |  |  | 5,243 |  |  | 5,906 |
Total Supply/Sales by Region |  | 70,785 |  |  | 64,741 |  |  | 64,030 |  |  | 64,366 |  |  | 70,375 |
|  | Three Months Ended
|  | September 30, 2017 |  | June 30, 2017 |  | March 31, 2017 |  | December 31, 2016 |  | September 30, 2016
Outage Days(e) |  |  |  |  |  |  |  |  |  |
Refueling(f) |  | 13 |  |  | 125 |  |  | 95 |  |  | 71 |  |  | 17 |
Non-refueling(f) |  | 15 |  |  | 12 |  |  | 8 |  |  | 32 |  |  | — |
Total Outage Days |  | 28 |  |  | 137 |  |  | 103 |  |  | 103 |  |  | 17 |

(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, South, West and Canada.

(c) | Excludes physical proprietary trading volumes of 2,601 GHhs, 2,312 GWhs, 1,850 GWhs, 2,164 GWhs, and 1,506 GWhs for the three months ended September 30, 2017, June 30, 2017, March 31, 2017, December 31, 2016, and September 30, 2016, respectively.

(d) | Includes affiliate sales to PECO, BGE, Pepco, DPL and ACE in the Mid-Atlantic region and affiliate sales to ComEd in the Midwest region.

(e) | Outage days exclude Salem.

(f) | Includes the ownership of the FitzPatrick nuclear facility from March 31, 2017.

28

EXELON CORPORATION
Exelon Generation Statistics
Nine Months Ended September 30, 2017 and 2016

|  | September 30, 2017 |  | September 30, 2016
Supply (in GWhs) |  |  |  |
Nuclear Generation |  |  |  |
Mid-Atlantic(a) |  | 48,271 |  |  | 47,035 |
Midwest |  | 69,422 |  |  | 70,925 |
New York(a)(d) |  | 17,623 |  |  | 14,002 |
Total Nuclear Generation |  | 135,316 |  |  | 131,962 |
Fossil and Renewables |  |  |  |
Mid-Atlantic |  | 2,330 |  |  | 2,290 |
Midwest |  | 1,053 |  |  | 1,046 |
New England |  | 5,921 |  |  | 5,826 |
New York |  | 3 |  |  | 3 |
ERCOT |  | 9,388 |  |  | 5,726 |
Other Power Regions |  | 5,656 |  |  | 6,245 |
Total Fossil and Renewables |  | 24,351 |  |  | 21,136 |
Purchased Power |  |  |  |
Mid-Atlantic |  | 8,840 |  |  | 14,024 |
Midwest |  | 1,018 |  |  | 1,855 |
New England |  | 13,920 |  |  | 11,863 |
New York |  | 28 |  |  | — |
ERCOT |  | 5,724 |  |  | 7,448 |
Other Power Regions |  | 10,357 |  |  | 10,281 |
Total Purchased Power |  | 39,887 |  |  | 45,471 |
Total Supply/Sales by Region(b) |  |  |  |
Mid-Atlantic(c) |  | 59,441 |  |  | 63,349 |
Midwest(c) |  | 71,493 |  |  | 73,826 |
New England |  | 19,841 |  |  | 17,689 |
New York |  | 17,654 |  |  | 14,005 |
ERCOT |  | 15,112 |  |  | 13,174 |
Other Power Regions |  | 16,013 |  |  | 16,526 |
Total Supply/Sales by Region |  | 199,554 |  |  | 198,569 |

(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) | Excludes physical proprietary trading volumes of 6,763 GWh and 4,015 GWh for the nine months ended September 30, 2017 and 2016, respectively.

(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) | Includes the ownership of the FitzPatrick nuclear facility from March 31, 2017.

29

EXELON CORPORATION
ComEd Statistics
Three Months Ended September 30, 2017 and 2016

|  | Electric Deliveries (in GWhs) |  | Revenue (in millions)
|  | 2017 |  | 2016 |  | % Change |  | Weather- Normal % Change |  | 2017 |  | 2016 |  | % Change
Retail Deliveries and Sales (a) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Residential |  | 8,004 |  |  | 9,014 |  |  | (11.2 | )% |  | (0.6 | )% |  | $ | 825 |  |  | $ | 786 |  |  | 5.0 | %
Small Commercial & Industrial |  | 8,488 |  |  | 8,833 |  |  | (3.9 | )% |  | (1.0 | )% |  | 369 |  |  | 356 |  |  | 3.7 | %
Large Commercial & Industrial |  | 7,232 |  |  | 7,565 |  |  | (4.4 | )% |  | (2.5 | )% |  | 121 |  |  | 126 |  |  | (4.0 | )%
Public Authorities & Electric Railroads |  | 302 |  |  | 308 |  |  | (1.9 | )% |  | (1.7 | )% |  | 11 |  |  | 10 |  |  | 10.0 | %
Total Retail |  | 24,026 |  |  | 25,720 |  |  | (6.6 | )% |  | (1.3 | )% |  | 1,326 |  |  | 1,278 |  |  | 3.8 | %
Other Revenue (b) |  |  |  |  |  |  |  |  |  | 245 |  |  | 219 |  |  | 11.9 | %
Total Electric Revenue (c) |  |  |  |  |  |  |  |  |  | $ | 1,571 |  |  | $ | 1,497 |  |  | 4.9 | %
Purchased Power |  |  |  |  |  |  |  |  |  | $ | 529 |  |  | $ | 454 |  |  | 16.5 | %

|  |  |  |  |  |  |  | % Change
Heating and Cooling Degree-Days |  | 2017 |  | 2016 |  | Normal |  | From 2016 |  | From Normal
Heating Degree-Days |  | 42 |  |  | 23 |  |  | 97 |  |  | 82.6 | % |  | (56.7 | )%
Cooling Degree-Days |  | 699 |  |  | 840 |  |  | 641 |  |  | (16.8 | )% |  | 9.0 | %

Nine Months Ended September 30, 2017 and 2016

|  | Electric Deliveries (in GWhs) |  | Revenue (in millions)
|  | 2017 |  | 2016 |  | % Change |  | Weather- Normal % Change |  | 2017 |  | 2016 |  | % Change
Retail Deliveries and Sales (a) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Residential |  | 20,164 |  |  | 21,738 |  |  | (7.2 | )% |  | (1.3 | )% |  | $ | 2,108 |  |  | $ | 2,018 |  |  | 4.5 | %
Small Commercial & Industrial |  | 23,634 |  |  | 24,447 |  |  | (3.3 | )% |  | (1.6 | )% |  | 1,051 |  |  | 1,007 |  |  | 4.4 | %
Large Commercial & Industrial |  | 20,712 |  |  | 21,057 |  |  | (1.6 | )% |  | (0.5 | )% |  | 352 |  |  | 350 |  |  | 0.6 | %
Public Authorities & Electric Railroads |  | 928 |  |  | 947 |  |  | (2.0 | )% |  | (1.4 | )% |  | 34 |  |  | 33 |  |  | 3.0 | %
Total Retail |  | 65,438 |  |  | 68,189 |  |  | (4.0 | )% |  | (1.1 | )% |  | 3,545 |  |  | 3,408 |  |  | 4.0 | %
Other Revenue (b) |  |  |  |  |  |  |  |  |  | 682 |  |  | 623 |  |  | 9.5 | %
Total Electric Revenue (c) |  |  |  |  |  |  |  |  |  | $ | 4,227 |  |  | $ | 4,031 |  |  | 4.9 | %
Purchased Power |  |  |  |  |  |  |  |  |  | $ | 1,241 |  |  | $ | 1,141 |  |  | 8.8 | %

|  |  |  |  |  |  |  | % Change
Heating and Cooling Degree-Days |  | 2017 |  | 2016 |  | Normal |  | From 2016 |  | From Normal
Heating Degree-Days |  | 3,269 |  |  | 3,678 |  |  | 3,972 |  |  | (11.1 | )% |  | (17.7 | )%
Cooling Degree-Days |  | 962 |  |  | 1,130 |  |  | 882 |  |  | (14.9 | )% |  | 9.1 | %

Number of Electric Customers |  | 2017 |  | 2016
Residential |  | 3,610,091 |  |  | 3,578,846 |
Small Commercial & Industrial |  | 376,309 |  |  | 372,603 |
Large Commercial & Industrial |  | 1,954 |  |  | 2,010 |
Public Authorities & Electric Railroads |  | 4,763 |  |  | 4,738 |
Total |  | 3,993,117 |  |  | 3,958,197 |

(a) | Reflects delivery volumes and 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, revenue also reflects the cost of energy and transmission.

(b) | Other revenue primarily includes transmission revenue from PJM. Other revenue includes rental revenues, revenues related to late payment charges, revenues from other utilities for mutual assistance programs and recoveries of remediation costs associated with MGP sites.

(c) | Includes operating revenues from affiliates totaling $3 million and $4 million for the three months ended September 30, 2017 and 2016, respectively, and $12 million and $12 million for the nine months ended September 30, 2017 and 2016, respectively.

30

EXELON CORPORATION
PECO Statistics
Three Months Ended September 30, 2017 and 2016

|  | Electric and Natural Gas Deliveries |  | Revenue (in millions)
|  | 2017 |  | 2016 |  | % Change |  | Weather- Normal % Change |  | 2017 |  | 2016 |  | % Change
Electric (in GWhs) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Deliveries and Sales (a) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Residential |  | 3,752 |  |  | 4,358 |  |  | (13.9 | )% |  | 0.2 | % |  | $ | 434 |  |  | $ | 513 |  |  | (15.4 | )%
Small Commercial & Industrial |  | 2,158 |  |  | 2,324 |  |  | (7.1 | )% |  | (1.0 | )% |  | 106 |  |  | 109 |  |  | (2.8 | )%
Large Commercial & Industrial |  | 4,137 |  |  | 4,234 |  |  | (2.3 | )% |  | 1.4 | % |  | 59 |  |  | 59 |  |  | — | %
Public Authorities & Electric Railroads |  | 198 |  |  | 240 |  |  | (17.5 | )% |  | (17.5 | )% |  | 7 |  |  | 8 |  |  | (12.5 | )%
Total Retail |  | 10,245 |  |  | 11,156 |  |  | (8.2 | )% |  | — | % |  | 606 |  |  | 689 |  |  | (12.0 | )%
Other Revenue (b) |  |  |  |  |  |  |  |  |  | 56 |  |  | 51 |  |  | 9.8 | %
Total Electric Revenue (d) |  |  |  |  |  |  |  |  |  | 662 |  |  | 740 |  |  | (10.5 | )%
Natural Gas (in mmcfs) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Deliveries and Sales |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Sales (c) |  | 3,993 |  |  | 3,494 |  |  | 14.3 | % |  | 9.4 | % |  | 46 |  |  | 41 |  |  | 12.2 | %
Transportation and Other |  | 5,674 |  |  | 7,315 |  |  | (22.4 | )% |  | (14.5 | )% |  | 7 |  |  | 7 |  |  | — | %
Total Natural Gas (d) |  | 9,667 |  |  | 10,809 |  |  | (10.6 | )% |  | (6.0 | )% |  | 53 |  |  | 48 |  |  | 10.4 | %
Total Electric and Natural Gas Revenues |  |  |  |  |  | $ | 715 |  |  | $ | 788 |  |  | (9.3 | )%
Purchased Power and Fuel |  |  |  |  |  |  |  |  |  | $ | 235 |  |  | $ | 272 |  |  | (13.6 | )%

|  |  |  |  |  |  |  | % Change
Heating and Cooling Degree-Days |  | 2017 |  | 2016 |  | Normal |  | From 2016 |  | From Normal
Heating Degree-Days |  | 14 |  |  | 10 |  |  | 35 |  |  | 40.0 | % |  | (60.0 | )%
Cooling Degree-Days |  | 989 |  |  | 1,288 |  |  | 923 |  |  | (23.2 | )% |  | 7.2 | %

Nine Months Ended September 30, 2017 and 2016

|  | Electric and Natural Gas Deliveries |  | Revenue (in millions)
|  | 2017 |  | 2016 |  | % Change |  | Weather- Normal % Change |  | 2017 |  | 2016 |  | % Change
Electric (in GWhs) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Deliveries and Sales (a) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Residential |  | 9,939 |  |  | 10,682 |  |  | (7.0 | )% |  | (1.4 | )% |  | $ | 1,147 |  |  | $ | 1,278 |  |  | (10.3 | )%
Small Commercial & Industrial |  | 6,048 |  |  | 6,236 |  |  | (3.0 | )% |  | (1.1 | )% |  | 303 |  |  | 334 |  |  | (9.3 | )%
Large Commercial & Industrial |  | 11,593 |  |  | 11,598 |  |  | — | % |  | 0.8 | % |  | 168 |  |  | 182 |  |  | (7.7 | )%
Public Authorities & Electric Railroads |  | 618 |  |  | 672 |  |  | (8.0 | )% |  | (8.0 | )% |  | 23 |  |  | 25 |  |  | (8.0 | )%
Total Retail |  | 28,198 |  |  | 29,188 |  |  | (3.4 | )% |  | (0.6 | )% |  | 1,641 |  |  | 1,819 |  |  | (9.8 | )%
Other Revenue (b) |  |  |  |  |  |  |  |  |  | 161 |  |  | 152 |  |  | 5.9 | %
Total Electric Revenue (d) |  |  |  |  |  |  |  |  |  | 1,802 |  |  | 1,971 |  |  | (8.6 | )%
Natural Gas (in mmcfs) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Deliveries and Sales |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Sales (c) |  | 38,825 |  |  | 38,488 |  |  | 0.9 | % |  | 2.7 | % |  | 315 |  |  | 298 |  |  | 5.7 | %
Transportation and Other |  | 19,122 |  |  | 20,917 |  |  | (8.6 | )% |  | (5.9 | )% |  | 24 |  |  | 24 |  |  | — | %
Total Natural Gas (d) |  | 57,947 |  |  | 59,405 |  |  | (2.5 | )% |  | (0.1 | )% |  | 339 |  |  | 322 |  |  | 5.3 | %
Total Electric and Natural Gas Revenues |  |  |  |  |  | $ | 2,141 |  |  | $ | 2,293 |  |  | (6.6 | )%
Purchased Power and Fuel |  |  |  |  |  |  |  |  |  | $ | 719 |  |  | $ | 809 |  |  | (11.1 | )%

|  |  |  |  |  |  |  | % Change
Heating and Cooling Degree-Days |  | 2017 |  | 2016 |  | Normal |  | From 2016 |  | From Normal
Heating Degree-Days |  | 2,437 |  |  | 2,616 |  |  | 2,974 |  |  | (6.8 | )% |  | (18.1 | )%
Cooling Degree-Days |  | 1,404 |  |  | 1,684 |  |  | 1,271 |  |  | (16.6 | )% |  | 10.5 | %

31

Number of Electric Customers |  | 2017 |  | 2016 |  | Number of Natural Gas Customers |  | 2017 |  | 2016
Residential |  | 1,463,906 |  |  | 1,451,533 |  |  | Residential |  | 474,766 |  |  | 470,024 |
Small Commercial & Industrial |  | 150,964 |  |  | 149,646 |  |  | Commercial & Industrial |  | 43,358 |  |  | 42,997 |
Large Commercial & Industrial |  | 3,112 |  |  | 3,094 |  |  | Total Retail |  | 518,124 |  |  | 513,021 |
Public Authorities & Electric Railroads |  | 9,665 |  |  | 9,820 |  |  | Transportation |  | 771 |  |  | 802 |
Total |  | 1,627,647 |  |  | 1,614,093 |  |  | Total |  | 518,895 |  |  | 513,823 |

(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, revenue also reflects the cost of energy and transmission.

(b) | Other revenue includes transmission revenue from PJM and wholesale electric revenues.

(c) | 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.

(d) | Total electric revenue includes operating revenues from affiliates totaling $1 million and $2 million for the three months ended September 30, 2017 and 2016, respectively, and $4 million and $5 million for the nine months ended September 30, 2017 and 2016, respectively. Total natural gas revenues includes operating revenues from affiliates totaling less than $1 million for both the three and nine months ended September 30, 2017 and 2016.

32

EXELON CORPORATION
BGE Statistics
Three Months Ended September 30, 2017 and 2016

|  | Electric and Natural Gas Deliveries |  |  |  | Revenue (in millions)
|  | 2017 |  | 2016 |  | % Change |  | Weather- Normal % Change |  | 2017 |  | 2016 |  | % Change
Electric (in GWhs) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Deliveries and Sales (a) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Residential |  | 3,370 |  |  | 3,900 |  |  | (13.6 | )% |  | (2.9 | )% |  | $ | 376 |  |  | $ | 451 |  |  | (16.6 | )%
Small Commercial & Industrial |  | 785 |  |  | 877 |  |  | (10.5 | )% |  | (9.0 | )% |  | 67 |  |  | 74 |  |  | (9.5 | )%
Large Commercial & Industrial |  | 3,781 |  |  | 3,992 |  |  | (5.3 | )% |  | (3.9 | )% |  | 120 |  |  | 123 |  |  | (2.4 | )%
Public Authorities & Electric Railroads |  | 64 |  |  | 72 |  |  | (11.1 | )% |  | (2.5 | )% |  | 8 |  |  | 9 |  |  | (11.1 | )%
Total Retail |  | 8,000 |  |  | 8,841 |  |  | (9.5 | )% |  | (4.0 | )% |  | 571 |  |  | 657 |  |  | (13.1 | )%
Other Revenue (b)(c) |  |  |  |  |  |  |  |  |  | 87 |  |  | 78 |  |  | 11.5 | %
Total Electric Revenue |  |  |  |  |  |  |  |  |  | 658 |  |  | 735 |  |  | (10.5 | )%
Natural Gas (in mmcfs) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Deliveries and Sales (d) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Sales |  | 11,221 |  |  | 13,159 |  |  | (14.7 | )% |  | (14.3 | )% |  | 77 |  |  | 71 |  |  | 8.5 | %
Transportation and Other (e) |  | 68 |  |  | 1,311 |  |  | (94.8 | )% |  | n/a |  |  | 3 |  |  | 6 |  |  | (50.0 | )%
Total Natural Gas (f) |  | 11,289 |  |  | 14,470 |  |  | (22.0 | )% |  | (14.3 | )% |  | 80 |  |  | 77 |  |  | 3.9 | %
Total Electric and Natural Gas Revenues |  |  |  |  |  | $ | 738 |  |  | $ | 812 |  |  | (9.1 | )%
Purchased Power and Fuel |  |  |  |  |  |  |  |  |  | $ | 269 |  |  | $ | 360 |  |  | (25.3 | )%

|  |  |  |  |  |  |  | % Change
Heating and Cooling Degree-Days |  | 2017 |  | 2016 |  | Normal |  | From 2016 |  | From Normal
Heating Degree-Days |  | 64 |  |  | 24 |  |  | 78 |  |  | 166.7 | % |  | (17.9 | )%
Cooling Degree-Days |  | 595 |  |  | 747 |  |  | 596 |  |  | (20.3 | )% |  | (0.2 | )%

Nine Months Ended September 30, 2017 and 2016

|  | Electric and Natural Gas Deliveries |  | Revenue (in millions)
|  | 2017 |  | 2016 |  | % Change |  | Weather- Normal % Change |  | 2017 |  | 2016 |  | % Change
Electric (in GWhs) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Deliveries and Sales (a) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Residential |  | 9,126 |  |  | 9,996 |  |  | (8.7 | )% |  | (4.3 | )% |  | $ | 1,096 |  |  | $ | 1,203 |  |  | (8.9 | )%
Small Commercial & Industrial |  | 2,210 |  |  | 2,343 |  |  | (5.7 | )% |  | (5.8 | )% |  | 202 |  |  | 212 |  |  | (4.7 | )%
Large Commercial & Industrial |  | 10,422 |  |  | 10,627 |  |  | (1.9 | )% |  | (2.6 | )% |  | 343 |  |  | 337 |  |  | 1.8 | %
Public Authorities & Electric Railroads |  | 204 |  |  | 215 |  |  | (5.1 | )% |  | (2.5 | )% |  | 23 |  |  | 27 |  |  | (14.8 | )%
Total Retail |  | 21,962 |  |  | 23,181 |  |  | (5.3 | )% |  | (3.7 | )% |  | 1,664 |  |  | 1,779 |  |  | (6.5 | )%
Other Revenue (b)(c) |  |  |  |  |  |  |  |  |  | 231 |  |  | 219 |  |  | 5.5 | %
Total Electric Revenue |  |  |  |  |  |  |  |  |  | 1,895 |  |  | 1,998 |  |  | (5.2 | )%
Natural Gas (in mmcfs) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Deliveries and Sales (d) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Sales |  | 60,620 |  |  | 69,415 |  |  | (12.7 | )% |  | (5.3 | )% |  | 445 |  |  | 403 |  |  | 10.4 | %
Transportation and Other (e) |  | 2,463 |  |  | 4,078 |  |  | (39.6 | )% |  | n/a |  |  | 23 |  |  | 20 |  |  | 15.0 | %
Total Natural Gas (f) |  | 63,083 |  |  | 73,493 |  |  | (14.2 | )% |  | (5.3 | )% |  | 468 |  |  | 423 |  |  | 10.6 | %
Total Electric and Natural Gas Revenues |  |  |  |  |  | $ | 2,363 |  |  | $ | 2,421 |  |  | (2.4 | )%
Purchased Power and Fuel |  |  |  |  |  |  |  |  |  | $ | 853 |  |  | $ | 994 |  |  | (14.2 | )%

|  |  |  |  |  |  |  | % Change
Heating and Cooling Degree-Days |  | 2017 |  | 2016 |  | Normal |  | From 2016 |  | From Normal
Heating Degree-Days |  | 2,524 |  |  | 2,878 |  |  | 2,992 |  |  | (12.3 | )% |  | (15.6 | )%
Cooling Degree-Days |  | 877 |  |  | 966 |  |  | 850 |  |  | (9.2 | )% |  | 3.2 | %

Number of Electric Customers |  | 2017 |  | 2016 |  | Number of Natural Gas Customers |  | 2017 |  | 2016
Residential |  | 1,156,659 |  |  | 1,145,020 |  |  | Residential |  | 626,039 |  |  | 619,837 |
Small Commercial & Industrial |  | 113,224 |  |  | 112,609 |  |  | Commercial & Industrial |  | 43,973 |  |  | 43,957 |
Large Commercial & Industrial |  | 12,144 |  |  | 12,030 |  |  | Total Retail |  | 670,012 |  |  | 663,794 |
Public Authorities & Electric Railroads |  | 274 |  |  | 282 |  |  | Transportation |  | — |  |  | — |
Total |  | 1,282,301 |  |  | 1,269,941 |  |  | Total |  | 670,012 |  |  | 663,794 |

33

(a) | Reflects delivery volumes and revenue 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, revenue also reflects the cost of energy and transmission.

(b) | Other revenue primarily includes wholesale transmission revenue and late payment charges.

(c) | Includes operating revenues from affiliates totaling $1 million for both the three months ended September 30, 2017 and 2016 and $5 million for both the nine months ended September 30, 2017 and 2016.

(d) | 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.

(e) | Transportation and other natural gas revenue includes off-system revenue of 68 mmcfs ($1 million) and 1,311 mmcfs ($4 million) for the three months ended September 30, 2017 and 2016, respectively, and 2,463 mmcfs ($15 million) and 4,078 mmcfs ($14 million) for the nine months ended September 30, 2017 and 2016, respectively.

(f) | Includes operating revenues from affiliates totaling $2 million and $6 million for the three months ended September 30, 2017 and 2016, respectively, and $7 million and $11 million for the nine months ended September 30, 2017 and 2016, respectively.

34

EXELON CORPORATION
PEPCO Statistics
Three Months Ended September 30, 2017 and 2016

|  | Electric Deliveries |  | Revenue (in millions)
|  | 2017 |  | 2016 |  | % Change |  | Weather - Normal % Change |  | 2017 |  | 2016 |  | % Change
Electric (in GWhs) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Deliveries and Sales (a) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Residential |  | 2,281 |  |  | 2,675 |  |  | (14.7 | )% |  | (5.2 | )% |  | $ | 283 |  |  | $ | 315 |  |  | (10.2 | )%
Small Commercial & Industrial |  | 347 |  |  | 394 |  |  | (11.9 | )% |  | (7.2 | )% |  | 38 |  |  | 43 |  |  | (11.6 | )%
Large Commercial & Industrial |  | 4,146 |  |  | 4,314 |  |  | (3.9 | )% |  | 0.8 | % |  | 221 |  |  | 219 |  |  | 0.9 | %
Public Authorities & Electric Railroads |  | 180 |  |  | 180 |  |  | — | % |  | 1.1 | % |  | 8 |  |  | 7 |  |  | 14.3 | %
Total Retail |  | 6,954 |  |  | 7,563 |  |  | (8.1 | )% |  | (1.7 | )% |  | 550 |  |  | 584 |  |  | (5.8 | )%
Other Revenue (b) |  |  |  |  |  |  |  |  |  | 54 |  |  | 51 |  |  | 5.9 | %
Total Electric Revenue (c) |  |  |  |  |  |  |  |  |  | 604 |  |  | 635 |  |  | (4.9 | )%
Purchased Power |  |  |  |  |  |  |  |  |  | $ | 168 |  |  | $ | 213 |  |  | (21.1 | )%

|  |  |  |  |  |  |  | % Change
Heating and Cooling Degree-Days |  | 2017 |  | 2016 |  | Normal |  | From 2016 |  | From Normal
Heating Degree-Days |  | 8 |  |  | 1 |  |  | 19 |  |  | 700.0 | % |  | (57.9 | )%
Cooling Degree-Days |  | 1,130 |  |  | 1,418 |  |  | 1,133 |  |  | (20.3 | )% |  | (0.3 | )%

Nine Months Ended September 30, 2017 and 2016

|  | Electric Deliveries |  | Revenue (in millions)
|  | 2017 |  | 2016 |  | % Change |  | Weather - Normal % Change |  | 2017 |  | 2016 |  | % Change
Electric (in GWhs) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Deliveries and Sales (a) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Residential |  | 6,038 |  |  | 6,652 |  |  | (9.2 | )% |  | (2.7 | )% |  | $ | 744 |  |  | $ | 791 |  |  | (5.9 | )%
Small Commercial & Industrial |  | 999 |  |  | 1,124 |  |  | (11.1 | )% |  | (8.4 | )% |  | 113 |  |  | 116 |  |  | (2.6 | )%
Large Commercial & Industrial |  | 11,306 |  |  | 11,890 |  |  | (4.9 | )% |  | (3.0 | )% |  | 608 |  |  | 613 |  |  | (0.8 | )%
Public Authorities & Electric Railroads |  | 542 |  |  | 544 |  |  | (0.4 | )% |  | (0.2 | )% |  | 24 |  |  | 23 |  |  | 4.3 | %
Total Retail |  | 18,885 |  |  | 20,210 |  |  | (6.6 | )% |  | (3.1 | )% |  | 1,489 |  |  | 1,543 |  |  | (3.5 | )%
Other Revenue (b) |  |  |  |  |  |  |  |  |  | 160 |  |  | 152 |  |  | 5.3 | %
Total Electric Revenue (c) |  |  |  |  |  |  |  |  |  | 1,649 |  |  | 1,695 |  |  | (2.7 | )%
Purchased Power |  |  |  |  |  |  |  |  |  | $ | 478 |  |  | $ | 563 |  |  | (15.1 | )%

|  |  |  |  |  |  |  | % Change
Heating and Cooling Degree-Days |  | 2017 |  | 2016 |  | Normal |  | From 2016 |  | From Normal
Heating Degree-Days |  | 1,963 |  |  | 2,408 |  |  | 2,477 |  |  | (18.5 | )% |  | (20.8 | )%
Cooling Degree-Days |  | 1,679 |  |  | 1,872 |  |  | 1,611 |  |  | (10.3 | )% |  | 4.2 | %

Number of Electric Customers |  | 2017 |  | 2016
Residential |  | 790,032 |  |  | 775,911 |
Small Commercial & Industrial |  | 53,543 |  |  | 53,425 |
Large Commercial & Industrial |  | 21,733 |  |  | 21,315 |
Public Authorities & Electric Railroads |  | 143 |  |  | 129 |
Total |  | 865,451 |  |  | 850,780 |

(a) | Reflects delivery volumes and 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, revenue also reflects the cost of energy and transmission.

(b) | Other revenue includes transmission revenue from PJM and wholesale electric revenues.

(c) | Includes operating revenues from affiliates totaling $1 million and $1 million for the three months ended September 30, 2017 and 2016, respectively, and $4 million and $3 million for the nine months ended September 30, 2017 and 2016, respectively.

35

EXELON CORPORATION
DPL Statistics
Three Months Ended September 30, 2017 and 2016

|  | Electric and Natural Gas Deliveries |  | Revenue (in millions)
|  | 2017 |  | 2016 |  | % Change |  | Weather - Normal % Change |  | 2017 |  | 2016 |  | % Change
Electric (in GWhs) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Deliveries and Sales (a) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Residential |  | 1,439 |  |  | 1,601 |  |  | (10.1 | )% |  | (2.2 | )% |  | $ | 183 |  |  | $ | 200 |  |  | (8.5 | )%
Small Commercial & Industrial |  | 636 |  |  | 642 |  |  | (0.9 | )% |  | 3.2 | % |  | 49 |  |  | 48 |  |  | 2.1 | %
Large Commercial & Industrial |  | 1,245 |  |  | 1,250 |  |  | (0.4 | )% |  | 4.1 | % |  | 26 |  |  | 24 |  |  | 8.3 | %
Public Authorities & Electric Railroads |  | 10 |  |  | 9 |  |  | 11.1 | % |  | 11.1 | % |  | 3 |  |  | 2 |  |  | 50.0 | %
Total Retail |  | 3,330 |  |  | 3,502 |  |  | (4.9 | )% |  | 1.2 | % |  | 261 |  |  | 274 |  |  | (4.7 | )%
Other Revenue (b) |  |  |  |  |  |  |  |  |  | 48 |  |  | 40 |  |  | 20.0 | %
Total Electric Revenue (c) |  |  |  |  |  |  |  |  |  | 309 |  |  | 314 |  |  | (1.6 | )%
Natural Gas (in mmcfs) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Deliveries and Sales (d) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Sales |  | 1,069 |  |  | 1,121 |  |  | (4.6 | )% |  | (6.4 | )% |  | 12 |  |  | 13 |  |  | (7.7 | )%
Transportation and Other (e) |  | 1,197 |  |  | 1,166 |  |  | 2.7 | % |  | 2.4 | % |  | 6 |  |  | 4 |  |  | 50.0 | %
Total Natural Gas |  | 2,266 |  |  | 2,287 |  |  | (0.9 | )% |  | (2.0 | )% |  | 18 |  |  | 17 |  |  | 5.9 | %
Total Electric and Natural Gas Revenues |  |  |  |  |  | $ | 327 |  |  | $ | 331 |  |  | (1.2 | )%
Purchased Power and Fuel |  |  |  |  |  |  |  |  |  | $ | 129 |  |  | $ | 150 |  |  | (14.0 | )%

Electric Service Territory |  |  |  |  |  |  |  | % Change
Heating and Cooling Degree-Days |  | 2017 |  | 2016 |  | Normal |  | From 2016 |  | From Normal
Heating Degree-Days |  | 24 |  |  | 14 |  |  | 33 |  |  | 71.4 | % |  | (27.3 | )%
Cooling Degree-Days |  | 867 |  |  | 1,103 |  |  | 856 |  |  | (21.4 | )% |  | 1.3 | %

Gas Service Territory |  |  |  |  |  |  |  | % Change
Heating Degree-Days |  | 2017 |  | 2016 |  | Normal |  | From 2016 |  | From Normal
Heating Degree-Days |  | 28 |  |  | 20 |  |  | 42 |  |  | 40.0 | % |  | (33.3 | )%

Nine Months Ended September 30, 2017 and 2016

|  | Electric and Natural Gas Deliveries |  | Revenue (in millions)
|  | 2017 |  | 2016 |  | % Change |  | Weather - Normal % Change |  | 2017 |  | 2016 |  | % Change
Electric (in GWhs) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Deliveries and Sales (a) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Residential |  | 3,843 |  |  | 4,066 |  |  | (5.5 | )% |  | 0.4 | % |  | $ | 508 |  |  | $ | 522 |  |  | (2.7 | )%
Small Commercial & Industrial |  | 1,693 |  |  | 1,746 |  |  | (3.0 | )% |  | (0.9 | )% |  | 138 |  |  | 143 |  |  | (3.5 | )%
Large Commercial & Industrial |  | 3,440 |  |  | 3,492 |  |  | (1.5 | )% |  | 0.3 | % |  | 77 |  |  | 74 |  |  | 4.1 | %
Public Authorities & Electric Railroads |  | 35 |  |  | 35 |  |  | — | % |  | — | % |  | 11 |  |  | 9 |  |  | 22.2 | %
Total Retail |  | 9,011 |  |  | 9,339 |  |  | (3.5 | )% |  | 0.1 | % |  | 734 |  |  | 748 |  |  | (1.9 | )%
Other Revenue (b) |  |  |  |  |  |  |  |  |  | 132 |  |  | 124 |  |  | 6.5 | %
Total Electric Revenue (c) |  |  |  |  |  |  |  |  |  | 866 |  |  | 872 |  |  | (0.7 | )%
Natural Gas (in mmcfs) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Deliveries and Sales (d) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Sales |  | 8,679 |  |  | 9,253 |  |  | (6.2 | )% |  | 6.5 | % |  | 87 |  |  | 87 |  |  | — | %
Transportation and Other (e) |  | 4,690 |  |  | 4,455 |  |  | 5.3 | % |  | 7.9 | % |  | 18 |  |  | 15 |  |  | 20.0 | %
Total Natural Gas |  | 13,369 |  |  | 13,708 |  |  | (2.5 | )% |  | 7.0 | % |  | 105 |  |  | 102 |  |  | 2.9 | %
Total Electric and Natural Gas Revenues |  |  |  |  |  | $ | 971 |  |  | $ | 974 |  |  | (0.3 | )%
Purchased Power and Fuel |  |  |  |  |  |  |  |  |  | $ | 399 |  |  | $ | 448 |  |  | (10.9 | )%

Electric Service Territory |  |  |  |  |  |  |  | % Change
Heating and Cooling Degree-Days |  | 2017 |  | 2016 |  | Normal |  | From 2016 |  | From Normal
Heating Degree-Days |  | 2,384 |  |  | 2,812 |  |  | 2,933 |  |  | (15.2 | )% |  | (18.7 | )%
Cooling Degree-Days |  | 1,228 |  |  | 1,410 |  |  | 1,184 |  |  | (12.9 | )% |  | 3.7 | %

Gas Service Territory |  |  |  |  |  |  |  | % Change
Heating Degree-Days |  | 2017 |  | 2016 |  | Normal |  | From 2016 |  | From Normal
Heating Degree-Days |  | 2,431 |  |  | 2,913 |  |  | 3,062 |  |  | (16.5 | )% |  | (20.6 | )%

36

Number of Electric Customers |  | 2017 |  | 2016 |  | Number of Natural Gas Customers |  | 2017 |  | 2016
Residential |  | 458,790 |  |  | 455,640 |  |  | Residential |  | 121,238 |  |  | 120,075 |
Small Commercial & Industrial |  | 60,542 |  |  | 60,034 |  |  | Commercial & Industrial |  | 9,700 |  |  | 9,656 |
Large Commercial & Industrial |  | 1,406 |  |  | 1,414 |  |  | Total Retail |  | 130,938 |  |  | 129,731 |
Public Authorities & Electric Railroads |  | 633 |  |  | 643 |  |  | Transportation |  | 155 |  |  | 157 |
Total |  | 521,371 |  |  | 517,731 |  |  | Total |  | 131,093 |  |  | 129,888 |

(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, revenue also reflects the cost of energy and transmission.

(b) | Other revenue includes transmission revenue from PJM and wholesale electric revenues.

(c) | Includes operating revenues from affiliates totaling $2 million and $2 million for the three months ended September 30, 2017 and 2016, respectively, and $6 million and $6 million for the nine months ended September 30, 2017 and 2016, respectively.

(d) | 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.

(e) | Transportation and other revenue includes off-system natural gas sales and the short-term release of interstate pipeline transportation and storage capacity not needed to serve customers.

37

EXELON CORPORATION
ACE Statistics
Three Months Ended September 30, 2017 and 2016

|  | Electric Deliveries |  | Revenue (in millions)
|  | 2017 |  | 2016 |  | % Change |  | Weather - Normal % Change |  | 2017 |  | 2016 |  | % Change
Electric (in GWhs) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Deliveries and Sales (a) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Residential |  | 1,349 |  |  | 1,575 |  |  | (14.3 | )% |  | (10.4 | )% |  | $ | 211 |  |  | $ | 249 |  |  | (15.3 | )%
Small Commercial & Industrial |  | 407 |  |  | 426 |  |  | (4.5 | )% |  | (1.9 | )% |  | 53 |  |  | 55 |  |  | (3.6 | )%
Large Commercial & Industrial |  | 939 |  |  | 1,032 |  |  | (9.0 | )% |  | (6.3 | )% |  | 49 |  |  | 57 |  |  | (14.0 | )%
Public Authorities & Electric Railroads |  | 9 |  |  | 11 |  |  | (18.2 | )% |  | (18.2 | )% |  | 3 |  |  | 4 |  |  | (25.0 | )%
Total Retail |  | 2,704 |  |  | 3,044 |  |  | (11.2 | )% |  | (7.8 | )% |  | 316 |  |  | 365 |  |  | (13.4 | )%
Other Revenue (b) |  |  |  |  |  |  |  |  |  | 54 |  |  | 56 |  |  | (3.6 | )%
Total Electric Revenue (c) |  |  |  |  |  |  |  |  |  | 370 |  |  | 421 |  |  | (12.1 | )%
Purchased Power |  |  |  |  |  |  |  |  |  | $ | 176 |  |  | $ | 221 |  |  | (20.4 | )%

|  |  |  |  |  |  |  | % Change
Heating and Cooling Degree-Days |  | 2017 |  | 2016 |  | Normal |  | From 2016 |  | From Normal
Heating Degree-Days |  | 23 |  |  | 17 |  |  | 42 |  |  | 35.3 | % |  | (45.2 | )%
Cooling Degree-Days |  | 830 |  |  | 1,006 |  |  | 806 |  |  | (17.5 | )% |  | 3.0 | %

Nine Months Ended September 30, 2017 and 2016

|  | Electric Deliveries |  | Revenue (in millions)
|  | 2017 |  | 2016 |  | % Change |  | Weather - Normal % Change |  | 2017 |  | 2016 |  | % Change
Electric (in GWhs) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Retail Deliveries and Sales (a) |  |  |  |  |  |  |  |  |  |  |  |  |  |
Residential |  | 3,042 |  |  | 3,327 |  |  | (8.6 | )% |  | (6.0 | )% |  | $ | 484 |  |  | $ | 530 |  |  | (8.7 | )%
Small Commercial & Industrial |  | 992 |  |  | 998 |  |  | (0.6 | )% |  | 0.8 | % |  | 129 |  |  | 133 |  |  | (3.0 | )%
Large Commercial & Industrial |  | 2,557 |  |  | 2,705 |  |  | (5.5 | )% |  | (4.6 | )% |  | 143 |  |  | 158 |  |  | (9.5 | )%
Public Authorities & Electric Railroads |  | 33 |  |  | 35 |  |  | (5.7 | )% |  | (5.7 | )% |  | 10 |  |  | 10 |  |  | — | %
Total Retail |  | 6,624 |  |  | 7,065 |  |  | (6.2 | )% |  | (4.5 | )% |  | 766 |  |  | 831 |  |  | (7.8 | )%
Other Revenue (b) |  |  |  |  |  |  |  |  |  | 149 |  |  | 151 |  |  | (1.3 | )%
Total Electric Revenue (c) |  |  |  |  |  |  |  |  |  | 915 |  |  | 982 |  |  | (6.8 | )%
Purchased Power |  |  |  |  |  |  |  |  |  | $ | 442 |  |  | $ | 520 |  |  | (15.0 | )%

|  |  |  |  |  |  |  | % Change
Heating and Cooling Degree-Days |  | 2017 |  | 2016 |  | Normal |  | From 2016 |  | From Normal
Heating Degree-Days |  | 2,608 |  |  | 2,938 |  |  | 3,103 |  |  | (11.2 | )% |  | (16.0 | )%
Cooling Degree-Days |  | 1,153 |  |  | 1,267 |  |  | 1,092 |  |  | (9.0 | )% |  | 5.6 | %

Number of Electric Customers |  | 2017 |  | 2016
Residential |  | 486,212 |  |  | 483,542 |
Small Commercial & Industrial |  | 60,982 |  |  | 60,875 |
Large Commercial & Industrial |  | 3,726 |  |  | 3,796 |
Public Authorities & Electric Railroads |  | 633 |  |  | 593 |
Total |  | 551,553 |  |  | 548,806 |

(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, revenue also reflects the cost of energy and transmission.

(b) | Other revenue includes transmission revenue from PJM and wholesale electric revenues.

(c) | Includes operating revenues from affiliates totaling $0 million and $1 million for the three months ended September 30, 2017 and 2016, respectively, and $2 million and $3 million for the nine months ended September 30, 2017 and 2016, respectively.

38