EX-99.1 2 exc20180207991.htm EXHIBIT 99.1 Exhibit
Exhibit 99.1
News Release
exclogoa06.jpg
Contact:
  
Dan Eggers
Investor Relations
312-394-2345
 
Paul Adams
Corporate Communications
410-470-4167
EXELON REPORTS FOURTH QUARTER AND FULL YEAR 2017 RESULTS
AND INITIATES 2018 FINANCIAL OUTLOOK
Exelon reported GAAP Net Income of $1.94 per share and $3.97 per share for the fourth quarter and full year 2017, respectively, and Adjusted (non-GAAP) Operating Earnings of $0.55 per share and $2.60 per share for the fourth quarter and full year 2017, respectively.
Exelon introduces a 2018 Adjusted (non-GAAP) Operating Earnings guidance range of $2.90 - $3.20 per share, reflecting growth in Utilities, full year recognition of both Illinois and New York ZEC revenue and the impact of tax reform.
Exelon's Board of Directors increased the annual dividend growth rate to 5 percent from 2.5 percent, effective in the first quarter of 2018.
Exelon Utilities project capital expenditures of $21 billion over the next 4 years to improve service and benefit customers, supporting over 7 percent annual rate base growth.
Exelon Generation projects free cash flow before growth capex of $7.6 billion over the next 4 years, supporting Exelon's priorities of Utility reinvestment and debt reduction.
Quad Cities Units 1 & 2 and Clinton Unit 1 were winning bidders in Illinois ZEC procurement.
CHICAGO (February 7, 2018) Exelon Corporation (NYSE: EXC) today reported its financial results for the fourth quarter and full year 2017.
"Exelon had a strong 2017, with our utilities turning in first-quartile and in several cases best-ever performance in reliability and customer service, and our nuclear generation fleet producing the most power on record, all thanks to the great work of our people, who also set company records for volunteerism and charitable giving,” said Christopher M. Crane, Exelon’s president and CEO. “We will build on this momentum in 2018 with our new dividend growth rate of 5 percent annually over the next three years, tax reform that will benefit utility customers and reduce tax expenses at Generation, and movement on needed power price formation changes in PJM and broader resiliency reviews at FERC.”
“In 2017, Exelon delivered solid financial performance with $2.60 of Adjusted (non-GAAP) Operating Earnings, which is within our range,” said Jonathan W. Thayer, Exelon’s Senior Executive Vice President and CFO. “We are introducing 2018 operating earnings guidance of $2.90 - $3.20 per share which incorporates the benefits of U.S. tax reform, strong utility growth, a full-year of ZEC programs in New York and Illinois, and recognition of Illinois ZEC revenue from 2017.”






1


Fourth Quarter 2017
Exelon's GAAP Net Income for the fourth quarter 2017 increased to $1.94 per share from $0.22 per share in the fourth quarter of 2016; Adjusted (non-GAAP) Operating Earnings increased to $0.55 per share in the fourth quarter of 2017 from $0.44 per share in the fourth quarter of 2016. For the reconciliations of GAAP Net Income to Adjusted (non-GAAP) Operating Earnings, refer to the tables beginning on page 9.
Adjusted (non-GAAP) Operating Earnings in the fourth quarter of 2017 reflect higher utility earnings due to regulatory rate increases and weather, partially offset by a 2017 impairment of certain transmission-related income tax regulatory assets; and, at Generation, New York ZEC revenue and higher capacity prices, partially offset by lower realized energy prices.
Full Year 2017
For the full year 2017, Exelon's GAAP Net Income increased to $3.97 per share from $1.22 per share in 2016. Exelon's Adjusted (non-GAAP) Operating Earnings for 2017 decreased to $2.60 per share from $2.68 per share in 2016.
Adjusted (non-GAAP) Operating Earnings for the full year 2017 reflect higher utility earnings due to regulatory rate increases, partially offset by weather and a 2017 impairment of certain transmission-related income tax regulatory assets; and, at Generation, lower realized energy prices, the impacts of lower load volumes delivered due to mild weather in the third quarter 2017, the conclusion of the Ginna RSSA and the impact of declining natural gas prices on Generation's natural gas portfolio, partially offset by New York ZEC revenue and higher capacity prices.
Operating Company Results1 
ComEd2 
ComEd's fourth quarter 2017 GAAP Net Income was $120 million compared with $80 million in the fourth quarter of 2016. ComEd’s Adjusted (non-GAAP) Operating Earnings for the fourth quarter 2017 were $123 million compared with $81 million in the fourth quarter of 2016, primarily reflecting higher electric distribution and transmission formula rate earnings.
PECO
PECO’s fourth quarter 2017 GAAP Net Income was $107 million compared with $92 million in the fourth quarter of 2016. PECO’s fourth quarter 2017 Adjusted (non-GAAP) Operating Earnings of $95 million remained relatively consistent with fourth quarter 2016 Adjusted (non-GAAP) Operating Earnings of $94 million.
Heating degree days were up 6.1 percent relative to the same period in 2016 and were 7.2 percent below normal. Total retail electric deliveries were up 3.4 percent compared with the fourth quarter of 2016. Natural gas deliveries (including both retail and transportation segments) in the fourth quarter of 2017 were up 9.0 percent compared with the same period in 2016.
____________________
1Exelon’s five business units include ComEd, which consists of electricity transmission and distribution operations in northern Illinois; PECO, which consists of electricity transmission and distribution operations and retail natural gas distribution operations in southeastern Pennsylvania; BGE, which consists of electricity transmission and distribution operations and retail natural gas distribution operations in central Maryland; PHI, which consists of electricity transmission and distribution operations in the District of Columbia and portions of Maryland, Delaware, and New Jersey and retail natural gas distribution operations in northern Delaware; and Generation, which consists of owned and contracted electric generating facilities and wholesale and retail customer supply of electric and natural gas products and services, including renewable energy products and risk management services.
2For BGE, Pepco and DPL Maryland and beginning in 2017 for ComEd, customer rates are adjusted to eliminate the impacts of weather and customer usage on distribution volumes.






2


BGE2 
BGE’s fourth quarter 2017 GAAP Net Income was $76 million compared with $103 million in the fourth quarter of 2016. BGE’s Adjusted (non-GAAP) Operating Earnings for the fourth quarter 2017 were $82 million compared with $105 million in the fourth quarter of 2016, primarily due to a favorable 2016 settlement of a Baltimore City conduit fee dispute and a 2017 impairment of certain transmission-related income tax regulatory assets.
PHI2 
PHI’s fourth quarter 2017 GAAP Net Income was $4 million compared with $30 million in the fourth quarter of 2016. PHI’s Adjusted (non-GAAP) Operating Earnings for the fourth quarter 2017 were $48 million compared with $42 million in the fourth quarter of 2016, primarily due to regulatory rate increases, partially offset by a 2017 impairment of certain transmission-related income tax regulatory assets.
Generation
Generation's fourth quarter 2017 GAAP Net Income was $2,215 million compared with a GAAP Net Loss of $41 million in the fourth quarter of 2016. Generation’s Adjusted (non-GAAP) Operating Earnings for the fourth quarter 2017 were $252 million compared with $162 million in the fourth quarter of 2016, primarily reflecting New York ZEC revenue and higher capacity prices, partially offset by lower realized energy prices.
The proportion of expected generation hedged as of Dec. 31, 2017, was 85.0 percent to 88.0 percent for 2018, 55.0 percent to 58.0 percent for 2019 and 26.0 percent to 29.0 percent for 2020.
Initiates Annual Guidance for 2018
Exelon introduced a guidance range for 2018 Adjusted (non-GAAP) Operating Earnings of $2.90 to $3.20 per share. Adjusted (non-GAAP) Operating Earnings guidance is based on the assumption of normal weather, which is determined based on historical average heating and cooling degree days for a 30-year period in the respective utilities' service territories, except at PHI, where a 20-year period is used. The outlook for 2018 Adjusted (non-GAAP) Operating Earnings for Exelon and its subsidiaries excludes the following items:
Mark-to-market adjustments from economic hedging activities;
Unrealized gains and losses from NDT fund investments to the extent not offset by contractual accounting as described in the notes to the consolidated financial statements;
Non-cash amortization of intangible assets, net related to commodity contracts recorded at the date of the acquisition of ConEdison Solutions in 2016 and FitzPatrick in 2017;
Certain costs incurred related to the PHI and FitzPatrick acquisitions;
Certain costs incurred related to plant retirements;
Certain costs incurred to achieve cost management program savings;
Other unusual items;
Generation's noncontrolling interest related to CENG exclusion items; and
One-time impacts of adopting new accounting standards.
___________________
2For BGE, Pepco and DPL Maryland and beginning in 2017 for ComEd, customer rates are adjusted to eliminate the impacts of weather and customer usage on distribution volumes.






3


Recent Developments
Dividend Policy Update: On Jan. 30, 2018, the Board of Directors of Exelon announced an updated dividend policy targeting 5 percent annual dividend growth for the period covering 2018 through 2020. Since the last dividend policy of 2.5 percent annual growth was implemented in 2016, Exelon’s business position has continued to strengthen. The company has generated more earnings from regulated utilities following the PHI acquisition, recognized greater stability for its generation fleet with the Illinois and New York ZEC programs, and continued to focus on cost management and prudent balance sheet oversight. As a result of the strengthened outlook on earnings, Exelon is sharing the financial success with its shareholders through this updated dividend policy.
Utility Capex and Rate Base Update: Exelon Utilities plan to invest nearly $21 billion of capital to ensure reliable, more resilient and more efficient transmission and distribution of electricity and gas for our customers. The increased capital investments and impacts of tax reform are expected to drive annual rate base growth of 7.4 percent through 2021, exceeding the 6.5 percent growth expectations for 2017-2020 projected a year ago.
Generation and Free Cash Flow Outlook: Cumulatively from 2018 through 2021, Generation projects $7.6 billion of free cash flow before growth capex, which is $0.8 billion higher than the prior 4-year outlook from 2017 through 2020. This financial outlook accounts for the latest power price forwards, updated gross margins at Constellation, continued efforts to reduce O&M cost and capital expenditures, the planned closure of Three Mile Island and Oyster Creek, and the impact of tax reform.
Exelon Nuclear Plants Selected in Illinois ZEC Procurement Event: On Jan. 25, 2018, the ICC announced that Clinton Unit 1 and Quad Cities Units 1 & 2 were winning bidders through the Illinois Power Agency's ZEC procurement event, which entitles them to compensation for the sale of ZECs. Generation executed the ZEC procurement contracts with Illinois utilities, including ComEd, effective January 26, 2018, and will begin recognizing revenue. In addition to recognizing ZEC revenue generated in the first quarter of 2018, Generation will also recognize ZEC revenue retroactive to June 1, 2017, which will contribute approximately $0.11 to Adjusted (non-GAAP) Operating Earnings. The $0.11 contribution to Adjusted (non-GAAP) Operating Earnings is higher than the $0.09 originally expected in 2017 due to the lower tax rate in 2018 at Generation as a result of the Tax Cuts and Jobs Act (TCJA).
Early Retirement of Oyster Creek Nuclear Facility: On Feb. 2, 2018, Generation announced that it will permanently cease generation operations at Oyster Creek Generating Station (Oyster Creek) at the end of its current operating cycle in October 2018. In 2010, Generation announced that Oyster Creek would retire by the end of 2019 as part of an agreement with the State of New Jersey to avoid significant costs associated with the construction of cooling towers to meet the State’s then new environmental regulations. Since then, like other nuclear sites, Oyster Creek has continued to face rising operating costs amid a historically low wholesale power price environment. The decision to retire Oyster Creek in 2018 at the end of its current operating cycle involved consideration of several factors, including economics and operating efficiencies, and avoids a refueling outage scheduled for the fall of 2018 that would have required advanced purchasing of fuel fabrication and materials beginning in late February 2018. Because of the decision to retire Oyster Creek in 2018, Generation will recognize certain one-time charges in the first quarter of 2018 ranging from an estimated $25 million to $35 million (pre-tax) related to a materials and supplies inventory reserve adjustment, employee-related costs, and construction work-in-progress impairment, among other items. The






4


aforementioned one-time charges will be excluded from GAAP Net Income to arrive at Adjusted (non-GAAP) Operating Earnings in the first quarter 2018.
DOE Notice of Proposed Rulemaking: On Aug. 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 Sept. 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 Jan. 8, 2018, the FERC issued an order terminating the rulemaking docket that was initiated to address the proposed rule in the DOE NOPR, concluding the proposed rule did not sufficiently demonstrate there is a resiliency issue and that it proposed a remedy that did not appear to be just, reasonable and nondiscriminatory as required under the Federal Power Act. At the same time, the FERC initiated a new proceeding to consider resiliency challenges to the bulk power system and evaluate whether additional FERC action to address resiliency would be appropriate. Exelon has been and will continue to be an active participant in these proceedings, but cannot predict the final outcome or its potential impact, if any, on Exelon or Generation.
Fourth Quarter Highlights
Corporate Tax Reform: On Dec. 22, 2017, President Trump signed into law the TCJA. The Registrants remeasured their existing deferred income tax balances as of Dec. 31, 2017, to reflect the decrease in the corporate income tax rate from 35 percent to 21 percent, which resulted in a material decrease to their net deferred income tax liability balances. At Generation, this reduction in net deferred income tax liabilities resulted in a one-time credit to income tax expense of approximately $1.9 billion. The Utility Registrants offset virtually all similar reductions, totaling $7.3 billion, with net regulatory liabilities (rather than through earnings), given that changes in income taxes are generally passed through customer rates. The amount and timing of potential refunds of the established net regulatory liabilities will be determined by the Utility Registrants’ respective rate regulators, subject to certain IRS "normalization" rules.
Pursuant to TCJA, beginning in 2018, Generation is expected to have higher operating cash flows over the next five years reflecting the reduction in the corporate federal income tax rate and full expensing of capital investments. The TCJA is generally expected to result in lower operating cash flows for the Utility Registrants as a result of the elimination of bonus depreciation and lower customer rates. Increased operating cash flows for the Utility Registrants from lower corporate federal income tax rates is expected to be more than offset over time by lower customer rates resulting from lower income tax expense and the settlement of deferred income tax net regulatory liabilities established pursuant to TCJA, partially offset by the impacts of higher rate base. The Utility Registrants expect to fund any required incremental operating cash outflows using third party debt financings and equity funding from Exelon in combinations generally consistent with existing capitalization ratio structures. To fund any additional equity contributions to the Utility Registrants, Exelon would have available to it its typical sources, including, but not limited to, the increased operating cash flows at Generation referenced above, which over time are expected to exceed the incremental equity needs at the Utility Registrants.






5


The Utility Registrants continue to work with their state regulatory commissions to determine the amount and timing of the passing back of TCJA income tax savings benefits to customers; with filings either made, or expected to be made, at Pepco, DPL and ACE, and approved filings at ComEd and BGE. The amounts being passed back or proposed to be passed back to customers reflect the benefit of lower income tax expense beginning January 1, 2018 (Feb. 1, 2018 for DPL Delaware), and the settlement of a portion of deferred income tax regulatory liabilities established upon enactment of the TCJA. To date, neither the PAPUC nor FERC has yet issued guidance on how and when to reflect the impacts of the TCJA in customer rates.
EGTP Bankruptcy: On Nov. 7, 2017, EGTP and all of its wholly-owned subsidiaries filed voluntary petitions for relief under Chapter 11 of Title 11 of the United States Code in the United States Bankruptcy Court for the District of Delaware. As a result, Exelon and Generation deconsolidated EGTP’s net liabilities, which included the previously impaired assets and related debt, from their consolidated financial statements, resulting in a $213 million pre-tax gain. Concurrently with the Chapter 11 filings, Generation entered into an asset purchase agreement to acquire one of EGTP’s generating plants, the Handley Generating Station, for approximately $60 million, subject to a potential adjustment for fuel oil and assumption of certain liabilities. The acquisition was approved by the Bankruptcy Court in January 2018 and the transaction is expected to be completed in the first half of 2018.
Proposed Remedy for West Lake Landfill: On Feb. 1, 2018, the Environmental Protection Agency (EPA) announced a proposed remediation plan for the West Lake Landfill Superfund Site in Bridgeton, Missouri, for which Generation is one of the potentially responsible parties (PRPs). The proposed remediation plan includes a partial excavation of the site and an enhanced landfill cover and will be open for public comment through March 22, 2018, with the expectation that a Record of Decision will be issued during the third quarter of 2018. Thereafter, the EPA will seek to enter into a Consent Decree with the PRPs to effectuate the remedy, which Generation currently expects will occur in late 2018 or early 2019. The estimated total cost to fully execute the EPA’s proposed remedy is approximately $340 million, including cost escalation on an undiscounted basis, which will be allocated among the final group of PRPs. Generation increased its previous liability to reflect management’s best estimate of Generation’s allocable share of the cost of the proposed remedy among the PRPs, which could materially change in the future. The aforementioned 2017 charge has been excluded from GAAP Net Income to arrive at Adjusted (non-GAAP) Operating Earnings.
ComEd Electric Distribution Rate Case: On Dec. 6, 2017, the ICC issued its final order approving ComEd’s 2017 annual distribution formula rate update. The final order resulted in an increase to the revenue requirement of $96 million, reflecting an increase of $78 million for the initial revenue requirement for 2017 and an increase of $18 million related to the annual reconciliation for 2016. The increase was set using an allowed return on rate base of 6.47 percent for the initial revenue requirement and 6.45 percent for the annual reconciliation (inclusive of an allowed ROE of 8.40 percent for 2017 less a reliability performance metric penalty of 6 basis points for the 2016 reconciliation). The rates took effect in January 2018.
Pepco District of Columbia Electric Distribution Rate Case: On Dec. 19, 2017, Pepco filed an application with the DCPSC to increase its annual electric distribution base rates by $66 million, reflecting a requested ROE of 10.1 percent. By mid-February, Pepco will update its current distribution rate case to reflect the TCJA impacts. Pepco expects a decision in the matter in the fourth quarter of 2018, but cannot predict how much of the requested increase the DCPSC will approve.






6


Pepco Maryland Electric Distribution Rate Case: On Jan. 2, 2018, Pepco filed an application with the MDPSC to increase its annual electric distribution base rates by $41 million, reflecting a requested ROE of 10.1 percent. On Feb. 5, 2018, Pepco filed with the MDPSC an update to its current distribution rate case to reflect approximately $31 million in TCJA tax savings, thereby reducing the requested annual base rate increase to $11 million. Pepco expects a decision in the matter in the third quarter of 2018, but cannot predict how much of the requested increase the MDPSC will approve.
DPL Maryland Electric Distribution Rate Case: On July 14, 2017, DPL filed an application with the MDPSC to increase its annual electric distribution base rates by $27 million, which was updated to $19 million on Nov. 16, 2017, reflecting a requested ROE of 10.1 percent. On Dec. 18, 2017, DPL, the MDPSC Staff and Maryland’s Office of People’s Counsel filed a settlement agreement with the MDPSC that would provide DPL a rate increase of $13 million, and a ROE of 9.5 percent solely for purposes of calculating AFUDC and regulatory asset carrying costs. By mid-February, DPL is planning to file with the MDPSC seeking approval to pass back to customers beginning in 2018 approximately $13 million in annual tax savings resulting from the enactment of the TCJA through a reduction in electric distribution rates. DPL expects a decision in the matter in the first quarter of 2018, but cannot predict whether the MDPSC will approve the settlement agreement as filed or how much of the requested increase will be approved.
FERC Transmission-Related Regulatory Asset Order: On Nov. 16, 2017, FERC issued an order rejecting BGE’s proposed revisions to its transmission formula rate to recover certain transmission-related income tax regulatory assets. ComEd, Pepco, DPL and ACE have similar transmission-related income tax regulatory assets also requiring FERC approval separate from their transmission formula rate mechanisms. Pursuant to the FERC order, management of each company concluded that the portion of the total transmission-related income tax regulatory assets that would have been previously amortized and recovered through rates had the transmission formula rate provided for such recovery was no longer probable of recovery; and recorded impairment charges to Income tax expense of $35 million, $3 million, $5 million, $27 million, $14 million, $6 million and $7 million at Exelon, ComEd, BGE, PHI, Pepco, DPL and ACE, respectively. Nevertheless, each company believes there is sufficient basis to support full recovery of all existing transmission-related income tax regulatory assets, and intends to further pursue such full recovery with FERC.
Nuclear Operations: Generation’s nuclear fleet, including its owned output from the Salem Generating Station and 100 percent of the CENG units, produced 47,528 gigawatt-hours (GWhs) in the fourth quarter of 2017, compared with 44,834 GWhs in the fourth quarter of 2016. Excluding Salem, the Exelon-operated nuclear plants at ownership achieved a 95.3 percent capacity factor for the fourth quarter of 2017, compared with 94.2 percent for the fourth quarter of 2016. Excluding Salem, the number of planned refueling outage days in the fourth quarter of 2017 totaled 60, compared with 71 in the fourth quarter of 2016. There were 18 non-refueling outage days in the fourth quarter of 2017, compared with 32 days in the fourth quarter of 2016.
Fossil and Renewables Operations: The dispatch match rate for Generation’s gas and hydro fleet was 98.4 percent in the fourth quarter of 2017, compared with 99.7 percent in the fourth quarter of 2016. The lower performance in the quarter was primarily due to outages at gas units in Texas and Alabama. The reported performance includes the EGTP sites, which Exelon maintained and operated through the quarter, but does not include Wolf Hollow II or Colorado Bend II, the two new CCGT units that went into full commercial operation in the second quarter. Energy capture for the wind and solar fleet was 96.2 percent in the fourth quarter of 2017, compared with 95.7 percent in the fourth quarter of 2016.






7


Financing Activities:
On Nov. 28, 2017, ExGen Renewables IV, an indirect subsidiary of Exelon and Generation, entered into an $850 million non-recourse senior secured term loan credit facility agreement scheduled to mature on Nov. 28, 2024. The net proceeds of $785 million, after the initial funding of $50 million for debt service and liquidity reserves as well as deductions for original discount and issuance costs, were distributed to Generation for general corporate purposes. The term loan bears interest at a variable rate equal to LIBOR plus 3.00 percent, subject to a 1.00 percent LIBOR floor. As of Dec. 31, 2017, $850 million was outstanding. In addition to the financing, ExGen Renewables IV entered into interest rate swaps with an initial notional amount of $636 million at an interest rate of 2.32 percent to manage a portion of the interest rate exposure in connection with the financing.






8


GAAP/Adjusted (non-GAAP) Operating Earnings Reconciliations
Adjusted (non-GAAP) Operating Earnings for the fourth 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
$
1.94

$
1,871

$
120

$
107

$
76

$
4

$
2,215

Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $7 and $6, respectively)
0.01

8





9

Unrealized Gains Related to Nuclear Decommissioning Trust (NDT) Fund Investments (net of taxes of $67)
(0.12
)
(108
)




(108
)
Amortization of Commodity Contract Intangibles (net of taxes of $5)
0.01

8





8

Merger and Integration Costs (net of taxes of $1, $1 and $0, respectively)

1



1


1

Long-Lived Asset Impairments (net of taxes of $16, $9 and $8, respectively)
0.03

29




16

12

Plant Retirements and Divestitures (net of taxes of $45, respectively)
0.07

70





70

Cost Management Program (net of taxes of $6, $1, $1 and $5, respectively)
0.01

10


1

1


8

Reassessment of Deferred Income Taxes (entire amount represents tax expense)
(1.30
)
(1,257
)
3

(12
)
5

33

(1,874
)
Gain on Deconsolidation of Businesses (net of taxes of $83)
(0.14
)
(130
)




(130
)
Vacation Policy Change (net of taxes of $21, $1, $1, $3, and $16, respectively)
(0.03
)
(33
)

(1
)
(1
)
(5
)
(26
)
Change in Environmental Remediation Liabilities (net of taxes of $17)
0.03

27





27

Noncontrolling Interests (net of taxes of $8)
0.04

40





40

2017 Adjusted (non-GAAP) Operating Earnings
$
0.55

$
536

$
123

$
95

$
82

$
48

$
252







9


Adjusted (non-GAAP) Operating Earnings for the fourth 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
$
0.22

$
204

$
80

$
92

$
103

$
30

$
(41
)
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $28)
(0.05
)
(44
)




(44
)
Unrealized Losses Related to NDT Fund Investments (net of taxes of $13)
0.01

9





9

Amortization of Commodity Contract Intangibles (net of taxes of $16)
0.03

26





26

Merger and Integration Costs (net of taxes of $14, $0, $1, $1, $3 and $9, respectively)
0.02

23

1

1

1

4

15

Merger Commitments (net of taxes of $12, $2 and $9, respectively)
0.04

38




8

40

Long-Lived Asset Impairments (net of taxes of $1)

(1
)





Plant Retirements and Divestitures (net of taxes of $59)
0.10

94





94

Cost Management Program (net of taxes of $5, $1, $1 and $3, respectively)
0.01

8


1

1


6

Reassessment of State Deferred Income Taxes (entire amount represents tax expense)
0.01

10





14

Asset Retirement Obligation (net of taxes of $14)
(0.08
)
(75
)




(75
)
Curtailment of Generation Growth Development Activities (net of taxes of $35)
0.06

57





57

Noncontrolling Interests (net of taxes of $1)
0.07

61





61

2016 Adjusted (non-GAAP) Operating Earnings
$
0.44

$
410

$
81

$
94

$
105

$
42

$
162







10


Adjusted (non-GAAP) Operating Earnings for the full year 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
$
3.97

$
3,770

$
567

$
434

$
307

$
362

$
2,694

Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $68 and $66, respectively)
0.11

107





109

Unrealized Gains Related to NDT Fund Investments (net of taxes of $204)
(0.34
)
(318
)

 



(318
)
Amortization of Commodity Contract Intangibles (net of taxes of $22)
0.04

34





34

Merger and Integration Costs (net of taxes of $25, $0, $2, $2, $7 and $27, respectively)
0.04

40

1

2

2

(10
)
44

Merger Commitments (net of taxes of $137, $52 and $18, respectively)
(0.14
)
(137
)



(59
)
(18
)
Long-Lived Asset Impairments (net of taxes of $204, $9 and $194, respectively)
0.34

321




16

306

Plant Retirements and Divestitures (net of taxes of $134 and $133, respectively)
0.22

207





208

Reassessment of Deferred Income Taxes (entire amount represents tax expense)
(1.37
)
(1,299
)
1

(12
)
5

34

(1,856
)
Cost Management Program (net of taxes of $21, $3, $3 and $15 respectively)
0.04

34


4

5


25

Like-Kind Exchange Tax Position (net of taxes of $66 and $9, respectively)
(0.03
)
(26
)
23





Asset Retirement Obligation (net of taxes of $1)

(2
)




(2
)
Tax Settlements (net of taxes of $1)
(0.01
)
(5
)




(5
)
Bargain Purchase Gain (net of taxes of $0)
(0.25
)
(233
)




(233
)
Gain on Deconsolidation of Businesses (net of taxes of $83)
(0.14
)
(130
)




(130
)
Vacation Policy Change (net of taxes of $21, $1, $1, $3, and $16, respectively)
(0.03
)
(33
)

(1
)
(1
)
(5
)
(26
)
Change in Environmental Remediation Liabilities (net of taxes of $17)
0.03

27





27

Noncontrolling Interests (net of taxes of $24)
0.12

114





114

2017 Adjusted (non-GAAP) Operating Earnings
$
2.60

$
2,471

$
592

$
427

$
318

$
338

$
973







11


Adjusted (non-GAAP) Operating Earnings for the full year 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
$
1.22

$
1,134

$
378

$
438

$
286

$
(61
)
$
496

Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $18)
0.03

24





24

Unrealized Gains Related to NDT Fund Investments (net of taxes of $77)
(0.13
)
(118
)




(118
)
Amortization of Commodity Contract Intangibles (net of taxes of $22)
0.04

35





35

Merger and Integration Costs (net of taxes of $50, $2, $2, $28 and $22, respectively)
0.12

114

(3
)
3


42

35

Merger Commitments (net of taxes of $126, 77 and $10, respectively)
0.47

437




247

42

Long-Lived Asset Impairments (net of taxes of $68)
0.11

103





103

Plant Retirements and Divestitures (net of taxes of $273, respectively)
0.47

432





432

Reassessment of Deferred Income Taxes (entire amount represents tax expense)
0.01

10





20

Cost Management Program (net of taxes of $21, $2, $2 and $17 respectively)
0.04

34


3

3


28

Like-Kind Exchange Tax Position (net of taxes of $61 and $42, respectively)
0.21

199

149





Asset Retirement Obligation (net of taxes of $13)
(0.08
)
(75
)




(75
)
Curtailment of Generation Growth and Development Activities (net of taxes of $35)
0.06

57





57

Noncontrolling Interests (net of taxes of $9)
0.11

102





102

2016 Adjusted (non-GAAP) Operating Earnings
$
2.68

$
2,488

$
524

$
444

$
289

$
228

$
1,181


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






12


49.5 percent and 76.2 percent for the three months ended December 31, 2017 and 2016, respectively; and were 47.4 percent and 48.7 percent for the twelve months ended December 31, 2017 and 2016, respectively.
Webcast Information
Exelon will discuss fourth 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.
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 2017 revenue of $33.5 billion. Exelon’s six utilities deliver electricity and natural gas to approximately 9 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 35,168 megawatts of nuclear, gas, wind, solar and hydroelectric generating capacity comprising one of the nation’s cleanest and lowest-cost power generation fleets. The company’s Constellation business unit provides energy products and services to approximately 2 million residential, public sector and business customers, including 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 February 7, 2018.






13


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 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) 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.






14



Earnings Release Attachments
Table of Contents

 
 
Consolidating Statements of Operations - Three Months Ended December 31, 2017 and 2016
 
 
Consolidating Statements of Operations - Twelve Months Ended December 31, 2017 and 2016
 
 
Business Segment Comparative Statements of Operations - Generation and ComEd - Three and Twelve Months Ended December 31, 2017 and 2016
 
 
Business Segment Comparative Statements of Operations - PECO and BGE - Three and Twelve Months Ended December 31, 2017 and 2016
 
 
Business Segment Comparative Statements of Operations - PHI and Other - Three and Twelve Months Ended December 31, 2017 and 2016
 
 
Consolidated Balance Sheets - December 31, 2017 and December 31, 2016
 
 
Consolidated Statements of Cash Flows - Twelve Months Ended December 31, 2017 and 2016
 
 
GAAP Consolidated Statements of Operations and Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments - Exelon - three months ended December 31, 2017 and 2016
 
 
GAAP Consolidated Statements of Operations and Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments - Exelon - twelve months ended December 31, 2017 and 2016
 
 
Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Net Income - Three Months Ended December 31, 2017 and 2016
 
 
Reconciliation of Adjusted (non-GAAP) Operating Earnings to GAAP Net Income - Twelve Months Ended December 31, 2017 and 2016
 
 
GAAP Consolidated Statements of Operations and Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments - Generation - Three and Twelve Months Ended December 31, 2017 and 2016
 
 
GAAP Consolidated Statements of Operations and Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments - ComEd - Three and Twelve Months Ended December 31, 2017 and 2016
 
 
GAAP Consolidated Statements of Operations and Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments - PECO - Three and Twelve Months Ended December 31, 2017 and 2016
 
 
GAAP Consolidated Statements of Operations and Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments - BGE - Three and Twelve Months Ended December 31, 2017 and 2016
 
 
GAAP Consolidated Statements of Operations and Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments - PHI - Three and Twelve Months Ended December 31, 2017 and 2016
 
 
GAAP Consolidated Statements of Operations and Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments - Other - Three and Twelve Months Ended December 31, 2017 and 2016
 
 
Exelon Generation Statistics - Three Months Ended December 31, 2017, September 30, 2017, June 30, 2017, March 31, 2017 and December 31, 2016
 
 
Exelon Generation Statistics - Twelve Months Ended December 31, 2017 and 2016
 
 
ComEd Statistics - Three and Twelve Months Ended December 31, 2017 and 2016
 
 
PECO Statistics - Three and Twelve Months Ended December 31, 2017 and 2016
 
 
BGE Statistics - Three and Twelve Months Ended December 31, 2017 and 2016
 
 
Pepco Statistics - Three and Twelve Months Ended December 31, 2017 and 2016
 
 
DPL Statistics - Three and Twelve Months Ended December 31, 2017 and 2016
 
 
ACE Statistics - Three and Twelve Months Ended December 31, 2017 and 2016





EXELON CORPORATION
Consolidating Statements of Operations
(unaudited)
(in millions)
 
 
Three Months Ended December 31, 2017
 
 
Generation
 
ComEd
 
PECO
 
BGE
 
PHI (a)
 
Other (b)
 
Exelon
Consolidated
Operating revenues
 
$
4,654

 
$
1,309

 
$
729

 
$
813

 
$
1,121

 
$
(245
)
 
$
8,381

Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
2,403

 
399

 
250

 
280

 
398

 
(222
)
 
3,508

Operating and maintenance
 
1,421

 
332

 
211

 
184

 
292

 
(45
)
 
2,395

Depreciation and amortization
 
412

 
220

 
73

 
125

 
164

 
21

 
1,015

Taxes other than income
 
130

 
73

 
38

 
61

 
108

 
8

 
418

Total operating expenses
 
4,366

 
1,024

 
572

 
650

 
962

 
(238
)
 
7,336

Gain (Loss) on sales of assets
 

 
1

 

 

 

 
(1
)
 

Gain on deconsolidation of business
 
213

 

 

 

 

 

 
213

Operating income (loss)
 
501

 
286

 
157

 
163

 
159

 
(8
)
 
1,258

Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(98
)
 
(87
)
 
(33
)
 
(25
)
 
(62
)
 
(60
)
 
(365
)
Other, net
 
299

 
10

 
3

 
4

 
15

 

 
331

Total other income and (deductions)
 
201

 
(77
)
 
(30
)
 
(21
)
 
(47
)
 
(60
)
 
(34
)
Income (Loss) before income taxes
 
702

 
209

 
127

 
142

 
112

 
(68
)
 
1,224

Income taxes
 
(1,585
)
 
89

 
20

 
66

 
108

 
583

 
(719
)
Equity in (losses) earnings of unconsolidated affiliates
 
(7
)
 

 

 

 

 
1

 
(6
)
Net income (loss)
 
2,280

 
120

 
107

 
76

 
4

 
(650
)
 
1,937

Net income attributable to noncontrolling interests
 
65

 

 

 

 

 
1

 
66

Net income (loss) attributable to common shareholders
 
$
2,215

 
$
120

 
$
107

 
$
76

 
$
4

 
$
(651
)
 
$
1,871

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Three Months Ended December 31, 2016
 
 
Generation
 
ComEd
 
PECO
 
BGE
 
PHI (a)
 
Other (b)
 
Exelon Consolidated
Operating revenues
 
$
4,388

 
$
1,223

 
$
701

 
$
812

 
$
1,078

 
$
(327
)
 
$
7,875

Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
2,221

 
317

 
238

 
300

 
410

 
(308
)
 
3,178

Operating and maintenance
 
1,308

 
417

 
206

 
149

 
310

 
(19
)
 
2,371

Depreciation and amortization
 
550

 
201

 
69

 
115

 
160

 
20

 
1,115

Taxes other than income
 
126

 
71

 
38

 
58

 
107

 
8

 
408

Total operating expenses
 
4,205

 
1,006

 
551

 
622

 
987

 
(299
)
 
7,072

(Loss) Gain on sales of assets
 
(89
)
 

 

 

 
(1
)
 
1

 
(89
)
Operating income (loss)
 
94

 
217

 
150

 
190

 
90

 
(27
)
 
714

Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 

 
 
Interest expense, net
 
(92
)
 
(87
)
 
(31
)
 
(27
)
 
(61
)
 
(58
)
 
(356
)
Other, net
 
6

 
8

 
2

 
5

 
13

 
(1
)
 
33

Total other income and (deductions)
 
(86
)
 
(79
)
 
(29
)
 
(22
)
 
(48
)
 
(59
)
 
(323
)
Income (Loss) before income taxes
 
8

 
138

 
121

 
168

 
42

 
(86
)
 
391

Income taxes
 
(3
)
 
58

 
29

 
65

 
12

 
(25
)
 
136

Equity in (losses) earnings of unconsolidated affiliates
 
(9
)
 

 

 

 

 
1

 
(8
)
Net income (loss)
 
2

 
80

 
92

 
103

 
30

 
(60
)
 
247

Net income attributable to noncontrolling interests and preference stock dividends
 
43

 

 

 

 

 

 
43

Net (loss) income attributable to common shareholders
 
$
(41
)
 
$
80

 
$
92

 
$
103

 
$
30

 
$
(60
)
 
$
204

(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)
 
 
Twelve Months Ended December 31, 2017
 
 
Generation
 
ComEd
 
PECO
 
BGE
 
PHI
 
Other (a)
 
Exelon
Consolidated
Operating revenues
 
$
18,466

 
$
5,536

 
$
2,870

 
$
3,176

 
$
4,679

 
$
(1,196
)
 
$
33,531

Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
9,690

 
1,641

 
969

 
1,133

 
1,716

 
(1,114
)
 
14,035

Operating and maintenance
 
6,291

 
1,427

 
806

 
716

 
1,068

 
(182
)
 
10,126

Depreciation and amortization
 
1,457

 
850

 
286

 
473

 
675

 
87

 
3,828

Taxes other than income
 
555

 
296

 
154

 
240

 
452

 
34

 
1,731

Total operating expenses
 
17,993

 
4,214

 
2,215

 
2,562

 
3,911

 
(1,175
)
 
29,720

Gain (Loss) on sales of assets
 
2

 
1

 

 

 
1

 
(1
)
 
3

Bargain purchase gain
 
233

 

 

 

 

 

 
233

Gain on deconsolidation of business
 
213

 

 

 

 

 

 
213

Operating income (loss)
 
921

 
1,323

 
655

 
614

 
769

 
(22
)
 
4,260

Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(440
)
 
(361
)
 
(126
)
 
(105
)
 
(245
)
 
(283
)
 
(1,560
)
Other, net
 
948

 
22

 
9

 
16

 
54

 
7

 
1,056

Total other income and (deductions)
 
508

 
(339
)
 
(117
)
 
(89
)
 
(191
)
 
(276
)
 
(504
)
Income (Loss) before income taxes
 
1,429

 
984

 
538

 
525

 
578

 
(298
)
 
3,756

Income taxes
 
(1,375
)
 
417

 
104

 
218

 
217

 
294

 
(125
)
Equity in (losses) earnings of unconsolidated affiliates
 
(33
)
 

 

 

 
1

 

 
(32
)
Net income (loss)
 
2,771

 
567

 
434

 
307

 
362

 
(592
)
 
3,849

Net income attributable to noncontrolling interests
 
77

 

 

 

 

 
2

 
79

Net income (loss) attributable to common shareholders
 
$
2,694

 
$
567

 
$
434

 
$
307

 
$
362

 
$
(594
)
 
$
3,770

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Twelve Months Ended December 31, 2016
 
 
Generation
 
ComEd
 
PECO
 
BGE
 
PHI (b)
 
Other (a)
 
Exelon
Consolidated
Operating revenues
 
$
17,751

 
$
5,254

 
$
2,994

 
$
3,233

 
$
3,643

 
$
(1,515
)
 
$
31,360

Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
8,830

 
1,458

 
1,047

 
1,294

 
1,447

 
(1,436
)
 
12,640

Operating and maintenance
 
5,641

 
1,530

 
811

 
737

 
1,233

 
96

 
10,048

Depreciation and amortization
 
1,879

 
775

 
270

 
423

 
515

 
74

 
3,936

Taxes other than income
 
506

 
293

 
164

 
229

 
354

 
30

 
1,576

Total operating expenses
 
16,856

 
4,056

 
2,292

 
2,683

 
3,549

 
(1,236
)
 
28,200

(Loss) Gain on sales of assets
 
(59
)
 
7

 

 

 
(1
)
 
5

 
(48
)
Operating income (loss)
 
836

 
1,205

 
702

 
550

 
93

 
(274
)
 
3,112

Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(364
)
 
(461
)
 
(123
)
 
(103
)
 
(195
)
 
(290
)
 
(1,536
)
Other, net
 
401

 
(65
)
 
8

 
21

 
44

 
4

 
413

Total other income and (deductions)
 
37

 
(526
)
 
(115
)
 
(82
)
 
(151
)
 
(286
)
 
(1,123
)
Income (loss) before income taxes
 
873

 
679


587


468

 
(58
)
 
(560
)
 
1,989

Income taxes
 
290

 
301

 
149

 
174

 
3

 
(156
)
 
761

Equity in (losses) earnings of unconsolidated affiliates
 
(25
)
 

 

 

 

 
1

 
(24
)
Net income (loss)
 
558

 
378

 
438

 
294

 
(61
)
 
(403
)
 
1,204

Net income attributable to noncontrolling interests and preference stock dividends
 
62

 

 

 
8

 

 

 
70

Net income (loss) attributable to common shareholders
 
$
496

 
$
378

 
$
438

 
$
286

 
$
(61
)
 
$
(403
)
 
$
1,134

(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 December 31,
 
Twelve Months Ended December 31,
 
 
2017
 
2016
 
Variance
 
2017
 
2016
 
Variance
Operating revenues
 
$
4,654

 
$
4,388

 
$
266

 
$
18,466

 
$
17,751

 
$
715

Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
2,403

 
2,221

 
182

 
9,690

 
8,830

 
860

Operating and maintenance
 
1,421

 
1,308

 
113

 
6,291

 
5,641

 
650

Depreciation and amortization
 
412

 
550

 
(138
)
 
1,457

 
1,879

 
(422
)
Taxes other than income
 
130

 
126

 
4

 
555

 
506

 
49

Total operating expenses
 
4,366

 
4,205

 
161

 
17,993

 
16,856

 
1,137

(Loss) Gain on sales of assets
 

 
(89
)
 
89

 
2

 
(59
)
 
61

Bargain purchase gain
 

 

 

 
233

 

 
233

Gain on deconsolidation of business
 
213

 

 
213

 
213

 

 
213

Operating income
 
501

 
94

 
407

 
921

 
836

 
85

Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(98
)
 
(92
)
 
(6
)
 
(440
)
 
(364
)
 
(76
)
Other, net
 
299

 
6

 
293

 
948

 
401

 
547

Total other income and (deductions)
 
201

 
(86
)
 
287

 
508

 
37

 
471

Income before income taxes
 
702

 
8

 
694

 
1,429

 
873

 
556

Income taxes
 
(1,585
)
 
(3
)
 
(1,582
)
 
(1,375
)
 
290

 
(1,665
)
Equity in losses of unconsolidated affiliates
 
(7
)
 
(9
)
 
2

 
(33
)
 
(25
)
 
(8
)
Net income
 
2,280

 
2

 
2,278

 
2,771

 
558

 
2,213

Net income attributable to noncontrolling interests
 
65

 
43

 
22

 
77

 
62

 
15

Net income (loss) attributable to membership interest
 
$
2,215

 
$
(41
)
 
$
2,256

 
$
2,694

 
$
496

 
$
2,198

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
ComEd
 
 
Three Months Ended December 31,
 
Twelve Months Ended December 31,
 
 
2017
 
2016
 
Variance
 
2017
 
2016
 
Variance
Operating revenues
 
$
1,309

 
$
1,223

 
$
86

 
$
5,536

 
$
5,254

 
$
282

Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power
 
399

 
317

 
82

 
1,641

 
1,458

 
183

Operating and maintenance
 
332

 
417

 
(85
)
 
1,427

 
1,530

 
(103
)
Depreciation and amortization
 
220

 
201

 
19

 
850

 
775

 
75

Taxes other than income
 
73

 
71

 
2

 
296

 
293

 
3

Total operating expenses
 
1,024

 
1,006

 
18

 
4,214

 
4,056

 
158

Gain on sales of assets
 
1

 

 
1

 
1

 
7

 
(6
)
Operating income
 
286

 
217

 
69

 
1,323

 
1,205

 
118

Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(87
)
 
(87
)
 

 
(361
)
 
(461
)
 
100

Other, net
 
10

 
8

 
2

 
22

 
(65
)
 
87

Total other income and (deductions)
 
(77
)
 
(79
)
 
2

 
(339
)
 
(526
)
 
187

Income before income taxes
 
209

 
138

 
71

 
984

 
679

 
305

Income taxes
 
89

 
58

 
31

 
417

 
301

 
116

Net income
 
$
120

 
$
80

 
$
40

 
$
567

 
$
378

 
$
189

.







3



EXELON CORPORATION
Business Segment Comparative Statements of Operations
(unaudited)
(in millions)
 
 
PECO
 
 
Three Months Ended December 31,
 
Twelve Months Ended December 31,
 
 
2017
 
2016
 
Variance
 
2017
 
2016
 
Variance
Operating revenues
 
$
729

 
$
701

 
$
28

 
$
2,870

 
$
2,994

 
$
(124
)
Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
250

 
238

 
12

 
969

 
1,047

 
(78
)
Operating and maintenance
 
211

 
206

 
5

 
806

 
811

 
(5
)
Depreciation and amortization
 
73

 
69

 
4

 
286

 
270

 
16

Taxes other than income
 
38

 
38

 

 
154

 
164

 
(10
)
Total operating expenses
 
572

 
551

 
21

 
2,215

 
2,292

 
(77
)
Operating income
 
157

 
150

 
7

 
655

 
702

 
(47
)
Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(33
)
 
(31
)
 
(2
)
 
(126
)
 
(123
)
 
(3
)
Other, net
 
3

 
2

 
1

 
9

 
8

 
1

Total other income and (deductions)
 
(30
)
 
(29
)
 
(1
)
 
(117
)
 
(115
)
 
(2
)
Income before income taxes
 
127

 
121

 
6

 
538

 
587

 
(49
)
Income taxes
 
20

 
29

 
(9
)
 
104

 
149

 
(45
)
Net income
 
$
107

 
$
92

 
$
15

 
$
434

 
$
438

 
$
(4
)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
BGE
 
 
Three Months Ended December 31,
 
Twelve Months Ended December 31,
 
 
2017
 
2016
 
Variance
 
2017
 
2016
 
Variance
Operating revenues
 
$
813

 
$
812

 
$
1

 
$
3,176

 
$
3,233

 
$
(57
)
Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
280

 
300

 
(20
)
 
1,133

 
1,294

 
(161
)
Operating and maintenance
 
184

 
149

 
35

 
716

 
737

 
(21
)
Depreciation and amortization
 
125

 
115

 
10

 
473

 
423

 
50

Taxes other than income
 
61

 
58

 
3

 
240

 
229

 
11

Total operating expenses
 
650

 
622

 
28

 
2,562

 
2,683

 
(121
)
Operating income
 
163

 
190

 
(27
)
 
614

 
550

 
64

Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(25
)
 
(27
)
 
2

 
(105
)
 
(103
)
 
(2
)
Other, net
 
4

 
5

 
(1
)
 
16

 
21

 
(5
)
Total other income and (deductions)
 
(21
)
 
(22
)
 
1

 
(89
)
 
(82
)
 
(7
)
Income before income taxes
 
142

 
168

 
(26
)
 
525

 
468

 
57

Income taxes
 
66

 
65

 
1

 
218

 
174

 
44

Net income
 
76

 
103

 
(27
)
 
307

 
294

 
13

Preference stock dividends
 

 

 

 

 
8

 
(8
)
Net income attributable to common shareholder
 
$
76

 
$
103

 
$
(27
)
 
$
307

 
$
286

 
$
21








4



EXELON CORPORATION
Business Segment Comparative Statements of Operations
(unaudited)
(in millions)
 
 
PHI
 
 
Three Months Ended December 31,
 
Twelve Months Ended December 31,
 
 
2017
 
2016
 
Variance
 
2017
 
2016 (a)
 
Variance
Operating revenues
 
$
1,121

 
$
1,078

 
$
43

 
$
4,679

 
$
3,643

 
$
1,036

Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
398

 
410

 
(12
)
 
1,716

 
1,447

 
269

Operating and maintenance
 
292

 
310

 
(18
)
 
1,068

 
1,233

 
(165
)
Depreciation and amortization
 
164

 
160

 
4

 
675

 
515

 
160

Taxes other than income
 
108

 
107

 
1

 
452

 
354

 
98

Total operating expenses
 
962

 
987

 
(25
)
 
3,911

 
3,549

 
362

(Loss) Gain on sales of assets
 

 
(1
)
 
1

 
1

 
(1
)
 
2

Operating income
 
159

 
90

 
69

 
769

 
93

 
676

Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(62
)
 
(61
)
 
(1
)
 
(245
)
 
(195
)
 
(50
)
Other, net
 
15

 
13

 
2

 
54

 
44

 
10

Total other income and (deductions)
 
(47
)
 
(48
)
 
1

 
(191
)
 
(151
)
 
(40
)
Income (loss) before income taxes
 
112

 
42

 
70

 
578

 
(58
)
 
636

Income taxes
 
108

 
12

 
96

 
217

 
3

 
214

Equity in earnings of unconsolidated affiliates
 

 

 

 
1

 

 
1

Net income (loss)
 
$
4

 
$
30

 
$
(26
)
 
$
362

 
$
(61
)
 
$
423

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Other (b)
 
 
Three Months Ended December 31,
 
Twelve Months Ended December 31,
 
 
2017
 
2016
 
Variance
 
2017
 
2016
 
Variance
Operating revenues
 
$
(245
)
 
$
(327
)
 
$
82

 
$
(1,196
)
 
$
(1,515
)
 
$
319

Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
(222
)
 
(308
)
 
86

 
(1,114
)
 
(1,436
)
 
322

Operating and maintenance
 
(45
)
 
(19
)
 
(26
)
 
(182
)
 
96

 
(278
)
Depreciation and amortization
 
21

 
20

 
1

 
87

 
74

 
13

Taxes other than income
 
8

 
8

 

 
34

 
30

 
4

Total operating expenses
 
(238
)
 
(299
)
 
61

 
(1,175
)
 
(1,236
)
 
61

(Loss) Gain on sales of assets
 
(1
)
 
1

 
(2
)
 
(1
)
 
5

 
(6
)
Operating loss
 
(8
)
 
(27
)
 
19

 
(22
)
 
(274
)
 
252

Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(60
)
 
(58
)
 
(2
)
 
(283
)
 
(290
)
 
7

Other, net
 

 
(1
)
 
1

 
7

 
4

 
3

Total other income and (deductions)
 
(60
)
 
(59
)
 
(1
)
 
(276
)
 
(286
)
 
10

Loss before income taxes
 
(68
)
 
(86
)
 
18

 
(298
)
 
(560
)
 
262

Income taxes
 
583

 
(25
)
 
608

 
294

 
(156
)
 
450

Equity in earnings of unconsolidated affiliates
 
1

 
1

 

 

 
1

 
(1
)
Net loss
 
(650
)
 
(60
)
 
(590
)
 
$
(592
)
 
$
(403
)
 
$
(189
)
Net income attributable to noncontrolling interests and preference stock dividends
 
1

 

 
1

 
2

 

 
2

Net loss attributable to common shareholders
 
$
(651
)
 
$
(60
)
 
$
(591
)
 
$
(594
)
 
$
(403
)
 
$
(191
)
(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)
 
 
December 31, 2017
 
December 31, 2016
Assets
 
 
 
 
Current assets
 
 
 
 
Cash and cash equivalents
 
$
898

 
$
635

Restricted cash and cash equivalents
 
207

 
253

Deposit with IRS
 

 
1,250

Accounts receivable, net
 
 
 
 
Customer
 
4,401

 
4,158

Other
 
1,132

 
1,201

Mark-to-market derivative assets
 
976

 
917

Unamortized energy contract assets
 
60

 
88

Inventories, net
 
 
 
 
Fossil fuel and emission allowances
 
340

 
364

Materials and supplies
 
1,311

 
1,274

Regulatory assets
 
1,267

 
1,342

Other
 
1,242

 
930

Total current assets
 
11,834

 
12,412

Property, plant and equipment, net
 
74,202

 
71,555

Deferred debits and other assets
 
 
 
 
Regulatory assets
 
8,021

 
10,046

Nuclear decommissioning trust funds
 
13,272

 
11,061

Investments
 
640

 
629

Goodwill
 
6,677

 
6,677

Mark-to-market derivative assets
 
337

 
492

Unamortized energy contract assets
 
395

 
447

Pledged assets for Zion Station decommissioning
 

 
113

Other
 
1,322

 
1,472

Total deferred debits and other assets
 
30,664

 
30,937

Total assets
 
$
116,700

 
$
114,904

Liabilities and shareholders’ equity
 
 
 
 
Current liabilities
 
 
 
 
Short-term borrowings
 
$
929

 
$
1,267

Long-term debt due within one year
 
2,088

 
2,430

Accounts payable
 
3,532

 
3,441

Accrued expenses
 
1,835

 
3,460

Payables to affiliates
 
5

 
8

Regulatory liabilities
 
523

 
602

Mark-to-market derivative liabilities
 
232

 
282

Unamortized energy contract liabilities
 
231

 
407

Renewable energy credit obligation
 
352

 
428

PHI merger related obligation
 
87

 
151

Other
 
982

 
981

Total current liabilities
 
10,796

 
13,457

Long-term debt
 
32,176

 
31,575

Long-term debt to financing trusts
 
389

 
641

Deferred credits and other liabilities
 
 
 
 
Deferred income taxes and unamortized investment tax credits
 
11,222

 
18,138

Asset retirement obligations
 
10,029

 
9,111

Pension obligations
 
3,736

 
4,248

Non-pension postretirement benefit obligations
 
2,093

 
1,848

Spent nuclear fuel obligation
 
1,147

 
1,024

Regulatory liabilities
 
9,865

 
4,187

Mark-to-market derivative liabilities
 
409

 
392

Unamortized energy contract liabilities
 
609

 
830

Payable for Zion Station decommissioning
 

 
14

Other
 
2,097

 
1,827

Total deferred credits and other liabilities
 
41,207

 
41,619

Total liabilities
 
84,568

 
87,292

Commitments and contingencies
 
 
 
 
Shareholders’ equity
 
 
 
 
Common stock
 
18,964

 
18,794

Treasury stock, at cost
 
(123
)
 
(2,327
)
Retained earnings
 
13,503

 
12,030

Accumulated other comprehensive loss, net
 
(2,487
)
 
(2,660
)
Total shareholders’ equity
 
29,857

 
25,837

Noncontrolling interests
 
2,275

 
1,775

Total equity
 
32,132

 
27,612

Total liabilities and shareholders’ equity
 
$
116,700

 
$
114,904







6



EXELON CORPORATION
Consolidated Statements of Cash Flows
(unaudited)
(in millions)
 
 
Twelve Months Ended December 31,
 
 
2017
 
2016
Cash flows from operating activities
 
 
 
 
Net income
 
$
3,849

 
$
1,204

Adjustments to reconcile net income to net cash flows provided by operating activities:
 
 
 
 
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization
 
5,427

 
5,576

Impairments of long-lived assets, intangible assets, and losses on regulatory assets
 
573

 
306

Gain on deconsolidation of business
 
(213
)
 

(Gain) Loss on sales of assets
 
(3
)
 
48

Bargain purchase gain
 
(233
)
 

Deferred income taxes and amortization of investment tax credits
 
(361
)
 
664

Net fair value changes related to derivatives
 
151

 
24

Net realized and unrealized (gains) losses on nuclear decommissioning trust fund investments
 
(616
)
 
(229
)
Other non-cash operating activities
 
713

 
1,333

Changes in assets and liabilities:
 
 
 
 
Accounts receivable
 
(426
)
 
(432
)
Inventories
 
(72
)
 
7

Accounts payable and accrued expenses
 
(378
)
 
771

Option premiums (paid) received, net
 
28

 
(66
)
Collateral received (posted), net
 
(158
)
 
931

Income taxes
 
299

 
576

Pension and non-pension postretirement benefit contributions
 
(405
)
 
(397
)
Deposit with IRS
 

 
(1,250
)
Other assets and liabilities
 
(683
)
 
(621
)
Net cash flows provided by operating activities
 
7,492

 
8,445

Cash flows from investing activities
 
 
 
 
Capital expenditures
 
(7,584
)
 
(8,553
)
Proceeds from termination of direct financing lease investment
 

 
360

Proceeds from nuclear decommissioning trust fund sales
 
7,845

 
9,496

Investment in nuclear decommissioning trust funds
 
(8,113
)
 
(9,738
)
Acquisition of businesses, net
 
(208
)
 
(6,934
)
Proceeds from sales of long-lived assets
 
219

 
61

Change in restricted cash
 
(50
)
 
(42
)
Other investing activities
 
(55
)
 
(153
)
Net cash flows used in investing activities
 
(7,946
)
 
(15,503
)
Cash flows from financing activities
 
 
 
 
Changes in short-term borrowings
 
(261
)
 
(353
)
Proceeds from short-term borrowings with maturities greater than 90 days
 
621

 
240

Repayments on short-term borrowings with maturities greater than 90 days
 
(700
)
 
(462
)
Issuance of long-term debt
 
3,470

 
4,716

Retirement of long-term debt
 
(2,490
)
 
(1,936
)
Retirement of long-term debt to financing trust
 
(250
)
 

Restricted proceeds from issuance of long-term debt
 
(50
)
 

Redemption of preference stock
 

 
(190
)
Sale of noncontrolling interests
 
396

 
372

Dividends paid on common stock
 
(1,236
)
 
(1,166
)
Common stock issued from treasury
 
1,150

 

Proceeds from employee stock plans
 
150

 
55

Other financing activities
 
(83
)
 
(85
)
Net cash flows provided by financing activities
 
717

 
1,191

Increase (Decrease) in cash and cash equivalents
 
263

 
(5,867
)
Cash and cash equivalents at beginning of period
 
635

 
6,502

Cash and cash equivalents at end of period
 
$
898

 
$
635







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 
 December 31, 2017
 
 
 
Three Months Ended 
 December 31, 2016
 
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
Operating revenues
 
$
8,381

 
$
93

 
(b),(d)
 
$
7,875

 
$
177

 
(b),(d)
Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
3,508

 
61

 
(b),(d),(g)
 
3,178

 
184

 
(b),(d),(g)
Operating and maintenance
 
2,395

 
(53
)
 
(e),(f),(g),(h),(i),(k),(o)
 
2,371

 
107

 
(e),(g),(h),(l),(m),(n)
Depreciation and amortization
 
1,015

 
(109
)
 
(g)
 
1,115

 
(251
)
 
(g)
Taxes other than income
 
418

 
2

 
(k)
 
408

 

 
 
Total operating expenses
 
7,336

 
 
 
 
 
7,072

 
 
 
 
Loss on sales of assets
 

 

 
 
 
(89
)
 
89

 
(g),(n)
Gain on deconsolidation of business
 
213

 
(213
)
 
(j)
 

 
 
 
 
Operating income
 
1,258

 
 
 
 
 
714

 
 
 
 
Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(365
)
 

 
 
 
(356
)
 

 

Other, net
 
331

 
(244
)
 
(c),(i)
 
33

 
37

 
(c),(g),(n)
Total other income and (deductions)
 
(34
)
 
 
 
 
 
(323
)
 
 
 
 
Income before income taxes
 
1,224

 
 
 
 
 
391

 
 
 
 
Income taxes
 
(719
)
 
1,110

 
(b),(c),(d),(e),(f),(g),(h),(i),(j),(k),(o)
 
136

 
118

 
(b),(c),(d),(e),(g),(h),(i),(l),(m),(n)
Equity in losses of unconsolidated affiliates
 
(6
)
 

 
 
 
(8
)
 

 
 
Net income
 
1,937

 
 
 
 
 
247

 
 
 
 
Net income attributable to noncontrolling interests and preference stock dividends
 
66

 
(40
)
 
(p)
 
43

 
(61
)
 
(p)
Net income attributable to common shareholders
 
$
1,871

 


 
 
 
$
204

 


 
 
Effective tax rate(q)(r)
 
(58.7
)%
 
 
 
 
 
34.8
%
 
 
 
 
Earnings per average common share
 
 
 
 
 
 
 
 
 
 
 
 
Basic
 
$
1.94

 
 
 
 
 
$
0.22

 
 
 
 
Diluted
 
$
1.94

 
 
 
 
 
$
0.22

 
 
 
 
Average common shares outstanding
 
 
 
 
 
 
 
 
 
 
 
 
Basic
 
964

 
 
 
 
 
925

 
 
 
 
Diluted
 
967

 
 
 
 
 
928

 
 
 
 
Effect of adjustments on earnings per average diluted common share recorded in accordance with GAAP:
Mark-to-market impact of economic hedging activities (b)
 
$
0.01

 
 
 
 
 
$
(0.05
)
 
 
Unrealized (gains) losses related to NDT fund investments (c)
 
(0.12
)
 
 
 
 
 
0.01

 
 
Amortization of commodity contract intangibles (d)
 
0.01

 
 
 
 
 
0.03

 
 
Merger and integration costs (e)
 

 
 
 
 
 
0.02

 
 
Long-lived asset impairments (f)
 
0.03

 
 
 
 
 

 
 
Plant retirements and divestitures (g)
 
0.07

 
 
 
 
 
0.10

 
 
Cost management program (h)
 
0.01

 
 
 
 
 
0.01

 
 
Reassessment of deferred income taxes (i)
 
(1.30
)
 
 
 
 
 
0.01

 
 
Gain on deconsolidation of business (j)
 
(0.14
)
 
 
 
 
 

 
 
Vacation policy change (k)
 
(0.03
)
 
 
 
 
 

 
 
Merger commitments (l)
 

 
 
 
 
 
0.04

 
 
Asset retirement obligation (m)
 

 
 
 
 
 
(0.08
)
 
 
Curtailment of Generation growth and development activities (n)
 

 
 
 
 
 
0.06

 
 
Change in environmental remediation liabilities (o)
 
0.03

 
 
 
 
 

 
 
Noncontrolling interests (p)
 
0.04

 
 
 
 
 
0.07

 
 
Total adjustments
 
$
(1.39
)
 
 
 
 
 
$
0.22

 
 

(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 impact of 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.






8



(d)
Adjustment to exclude the non-cash amortization of intangible assets, net, primarily related to commodity contracts recorded at fair value related to, in 2016, the Integrys and ConEdison Solutions acquisitions, 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 and FitzPatrick acquisitions.
(f)
Adjustment to exclude charges to earnings related to the PHI 2017 impairment of the District of Columbia sponsorship intangible asset.
(g)
Adjustment to exclude in 2016, incremental accelerated depreciation and amortization expenses from June 2, 2016 through December 6, 2016 pursuant to the second quarter decision to early retire the Clinton and Quad Cities nuclear generation facilities, which decision was reversed in December 2016, partially offset by the reversal of certain one-time charges for materials & supplies inventory reserves and severance reserves upon Generation’s decision to continue operating the plants with the passage of the Illinois Zero Emission Standard, and in 2017, an adjustment to exclude accelerated depreciation and amortization expenses associated with Generation’s decision to early retire the Three Mile Island nuclear facility.
(h)
Adjustment to exclude severance and reorganization costs related to a cost management program.
(i)
Adjustment to exclude in 2016 the non-cash impact of the remeasurement of deferred income taxes as a result of changes in forecasted apportionment related to the PHI acquisition, and in 2017, the one-time non-cash impacts associated with the Tax Cuts and Jobs Act (including impacts on pension obligations).
(j)
Adjustment to exclude the gain recorded upon deconsolidation of EGTP's net liabilities, which included the previously impaired assets and related debt, as a result of the November 2017 bankruptcy filing.
(k)
Adjustment to exclude the reversal of previously accrued vacation expenses as a result of a change in Exelon's vacation vesting policy.
(l)
Adjustment to exclude costs incurred as part of the settlement orders approving the PHI acquisition and a charge related to a 2012 CEG merger commitment.
(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 the one-time recognition for a loss on sale of assets and asset impairment charges pursuant to Generation’s strategic decision in the fourth quarter of 2016 to narrow the scope and scale of its growth and development activities.
(o)
Represents charges to adjust the environmental reserve associated with future remediation of the West Lake Landfill Superfund Site.
(p)
Adjustment to exclude the 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.
(q)
The effective tax rate related to GAAP Net Income for the three months ended December 31, 2017 includes the impact of the Tax Cuts and Jobs Act.
(r)
The effective tax rate related to Adjusted (non-GAAP) Operating Earnings is 40.8% and 38.8% for the three months ended December 31, 2017 and 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)
 
 
Twelve Months Ended 
 December 31, 2017
 
 
 
Twelve Months Ended 
 December 31, 2016
 
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
Operating revenues
 
$
33,531

 
$
170

 
(b),(d)
 
$
31,360

 
$
545

 
(b),(d),(e)
Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
14,035

 
(72
)
 
(b),(d),(h)
 
12,640

 
395

 
(b),(d),(h)
Operating and maintenance
 
10,126

 
(686
)
 
(e),(g),(h),(i),(j),(l),(p),(r)
 
10,048

 
(849
)
 
(e),(f),(g),(h),(j),(l),(q)
Depreciation and amortization
 
3,828

 
(252
)
 
(d),(h)
 
3,936

 
(704
)
 
(e),(h)
Taxes other than income
 
1,731

 
2

 
(p)
 
1,576

 
(1
)
 
(j)
Total operating expenses
 
29,720

 
 
 
 
 
28,200

 
 
 
 
Gain (Loss) on sales of assets
 
3

 
1

 
(h)
 
(48
)
 
57

 
(h),(q)
Bargain purchase gain
 
233

 
(233
)
 
(n)
 

 

 
 
Gain on deconsolidation of business
 
213

 
(213
)
 
(o)
 

 

 
 
Operating income
 
4,260

 
 
 
 
 
3,112

 
 
 
 
Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(1,560
)
 
58

 
(g),(k),(m)
 
(1,536
)
 
153

 
(k)
Other, net
 
1,056

 
(638
)
 
(c),(i),(k)
 
413

 
(124
)
 
(c),(h),(k),(q)
Total other income and (deductions)
 
(504
)
 
 
 
 
 
(1,123
)
 
 
 
 
Income before income taxes
 
3,756

 
 
 
 
 
1,989

 
 
 
 
Income taxes
 
(125
)
 
1,566

 
(b),(c),(d),(e),(f),(g),(h),(i),(j),(k),(l),(m),(o),(p),(r)
 
761

 
538

 
(b),(c),(d),(e),(f),(g),(h),(i),(j),(k),(l),(q)
Equity in losses of unconsolidated affiliates
 
(32
)
 

 
 
 
(24
)
 

 
 
Net income
 
3,849

 
 
 
 
 
1,204

 
 
 
 
Net income attributable to noncontrolling interests and preference stock dividends
 
79

 
(114
)
 
(s)
 
70

 
(102
)
 
(s)
Net income attributable to common shareholders
 
$
3,770

 


 
 
 
$
1,134

 


 
 
Effective tax rate(t)(u)
 
(3.3
)%
 
 
 
 
 
38.3
%
 
 
 
 
Earnings per average common share
 
 
 
 
 
 
 
 
 
 
 
 
Basic
 
$
3.98

 
 
 
 
 
$
1.23

 
 
 
 
Diluted
 
$
3.97

 
 
 
 
 
$
1.22

 
 
 
 
Average common shares outstanding
 
 
 
 
 
 
 
 
 
 
 
 
Basic
 
947

 
 
 
 
 
924

 
 
 
 
Diluted
 
949

 
 
 
 
 
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)
 
$
0.11

 
 
 
 
 
$
0.03

 
 
Unrealized gains related to NDT fund investments (c)
 
(0.34
)
 
 
 
 
 
(0.13
)
 
 
Amortization of commodity contract intangibles (d)
 
0.04

 
 
 
 
 
0.04

 
 
Merger and integration costs (e)
 
0.04

 
 
 
 
 
0.12

 
 
Merger commitments (f)
 
(0.14
)
 
 
 
 
 
0.47

 
 
Long-lived asset impairments (g)
 
0.34

 
 
 
 
 
0.11

 
 
Plant retirements and divestitures (h)
 
0.22

 
 
 
 
 
0.47

 
 
Reassessment of deferred income taxes (i)
 
(1.37
)
 
 
 
 
 
0.01

 
 
Cost management program (j)
 
0.04

 
 
 
 
 
0.04

 
 
Like-kind exchange tax position (k)
 
(0.03
)
 
 
 
 
 
0.21

 
 
Asset retirement obligation (l)
 

 
 
 
 
 
(0.08
)
 
 
Tax settlements (m)
 
(0.01
)
 
 
 
 
 

 
 
Bargain purchase gain (n)
 
(0.25
)
 
 
 
 
 

 
 
Gain on Deconsolidation of Business (o)
 
(0.14
)
 
 
 
 
 

 
 
Vacation policy change (p)
 
(0.03
)
 
 
 
 
 

 
 
Curtailment of generation growth and development activities (q)
 

 
 
 
 
 
0.06

 
 
Change in environmental remediation liabilities (r)
 
0.03

 
 
 
 
 

 
 
Noncontrolling interests (s)
 
0.12

 
 
 
 
 
0.11

 
 
Total adjustments
 
$
(1.37
)
 
 
 
 
 
$
1.46

 
 






10



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 December 31, 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).
(b)
Adjustment to exclude the mark-to-market impact of Exelon’s economic hedging activities, net of intercompany eliminations.
(c)
Adjustment to exclude 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.
(d)
Adjustment to exclude the non-cash amortization of intangible assets, net, primarily related to commodity contracts recorded at fair value related to, in 2016, the Integrys and ConEdison Solutions acquisitions, 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 and FitzPatrick acquisitions.
(f)
Adjustment to exclude costs incurred as part of the settlement orders approving the PHI acquisition, and in 2016, a charge related to a 2012 CEG merger commitment, 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 of the ExGen Texas Power, LLC (EGTP) assets and PHI District of Columbia sponsorship intangible asset.
(h)
Adjustment to exclude in 2016, accelerated depreciation and amortization expenses through December 2016 and construction work in progress impairments associated with Generation’s previous decision to early retire the Clinton and Quad Cities nuclear facilities, partially offset by a gain associated with Generation’s sale of the New Boston generating site, and in 2017, primarily reflects accelerated depreciation and amortization expenses, increases to materials and supplies inventory reserves, construction work in progress impairments and charges for severance reserves associated with Generation’s decision to early retire the Three Mile Island nuclear facility.
(i)
Adjustment to exclude in 2016 the non-cash impact of the remeasurement of deferred income taxes as a result of changes in forecasted apportionment related to the PHI acquisition, and in 2017, one-time non-cash impacts associated with remeasurements of deferred income taxes as a result of the Tax Cuts and Jobs Act (including impacts on pension obligations), 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 in 2016 the recognition of a penalty and associated interest expense as a result of a tax court decision on Exelon’s like-kind exchange tax position, and in 2017, adjustments to income tax, penalties and interest expenses 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 the gain recorded upon deconsolidation of EGTP's net liabilities, which included the previously impaired assets and related debt, as a result of the November 2017 bankruptcy filing.
(p)
Adjustment to exclude the reversal of previously accrued vacation expenses as a result of a change in Exelon's vacation vesting policy.
(q)
Adjustment to exclude the one-time recognition for a loss on sale of assets and asset impairment charges pursuant to Generation’s strategic decision in the fourth quarter of 2016 to narrow the scope and scale of its growth and development activities.
(r)
Represents charges to adjust the environmental reserve associated with future remediation of the West Lake Landfill Superfund Site.
(s)
Adjustment to exclude the 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.
(t)
The effective tax rate related to GAAP Net Income for the twelve months ended December 31, 2017 includes the impact of the Tax Cuts and Jobs Act.
(u)
The effective tax rate related to Adjusted (non-GAAP) Operating Earnings is 36.9% and 34.4% for the twelve months ended December 31, 2017 and 2016, respectively.






11



EXELON CORPORATION
Reconciliation of Adjusted (non-GAAP) Operating
Earnings to GAAP Net Income (in millions)
Three Months Ended December 31, 2017 and 2016
(unaudited)
 
 
Exelon
Earnings per
Diluted Share
 
Generation
 
ComEd
 
PECO
 
BGE
 
PHI (a)
 
Other(b)
 
Exelon
2016 GAAP Net Income (Loss)
 
$
0.22

 
$
(41
)
 
$
80

 
$
92

 
$
103

 
$
30

 
$
(60
)
 
$
204

2016 Adjusted (non-GAAP) Operating (Earnings) Loss Adjustments:
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $28)
 
(0.05
)
 
(44
)
 

 

 

 

 

 
(44
)
Unrealized Losses Related to NDT Fund Investments (net of taxes of $13) (1)
 
0.01

 
9

 

 

 

 

 

 
9

Amortization of Commodity Contract Intangibles (net of taxes of $16) (2)
 
0.03

 
26

 

 

 

 

 

 
26

Merger and Integration Costs (net of taxes of $9, $0, $1, $1, $3, $0 and $14, respectively) (3)
 
0.02

 
15

 
1

 
1

 
1

 
4

 
1

 
23

Merger Commitments (net of taxes of $9, $2, $1 and $12, respectively) (4)
 
0.04

 
40

 

 

 

 
8

 
(10
)
 
38

Long-Lived Asset Impairments (net of taxes of $1) (5)
 

 

 

 

 

 

 
(1
)
 
(1
)
Plant Retirements and Divestitures (net of taxes of $59) (6)
 
0.10

 
94

 

 

 

 

 

 
94

Cost Management Program (net of taxes of $3, $1, $1 and $5, respectively) (7)
 
0.01

 
6

 

 
1

 
1

 

 

 
8

Reassessment of Deferred Income Taxes (entire amount represents tax expense) (8)
 
0.01

 
14

 

 

 

 

 
(4
)
 
10

Asset Retirement Obligation (net of taxes of $14) (9)
 
(0.08
)
 
(75
)
 

 

 

 

 

 
(75
)
Curtailment of Generation Growth and Development Activities (net of taxes of $35) (10)
 
0.06

 
57

 

 

 

 

 

 
57

Noncontrolling Interests (net of taxes of $1) (11)
 
0.07

 
61

 

 

 

 

 

 
61

2016 Adjusted (non-GAAP) Operating Earnings (Loss)
 
0.44


162


81


94


105

 
42

 
(74
)
 
410

Year Over Year Effects on Earnings:
ComEd, PECO, BGE and PHI Margins:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Weather
 
0.02

 

 

(c)
13

 

(c)
4

(c)

 
17

Load
 

 

 
4

(c)
(5
)
 

(c)
(1
)
(c)

 
(2
)
Other Energy Delivery (15)
 
0.04

 

 
(1
)
(d)
1

(d)
13

(d)
30

(d)

 
43

Generation Energy Margins, Excluding Mark-to-Market:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Nuclear Volume (16)
 
0.04

 
37

 

 

 

 

 

 
37

Nuclear Fuel Cost (17)
 

 

 

 

 

 

 

 

Capacity Pricing (18)
 
0.05

 
49

 

 

 

 

 

 
49

Zero Emission Credit Revenue (19)
 
0.08

 
74

 

 

 

 

 

 
74

Market and Portfolio Conditions (20)
 
(0.09
)
 
(83
)
 

 

 

 

 

 
(83
)
Operating and Maintenance Expense:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Labor, Contracting and Materials (21)
 
0.04

 
13

 
18

 
(1
)
 
6

 
(1
)
 

 
35

Planned Nuclear Refueling Outages (22)
 

 
(4
)
 

 

 

 

 

 
(4
)
Pension and Non-Pension Postretirement Benefits (23)
 

 
(4
)
 
(1
)
 

 
1

 
2

 
(1
)
 
(3
)
Other Operating and Maintenance (24)
 
0.05

 
25

 
33

 
(3
)
 
(28
)
 
8

 
19

 
54

Depreciation and Amortization Expense (25)
 
(0.03
)
 
(3
)
 
(11
)
 
(2
)
 
(6
)
 
(2
)
 
(1
)
 
(25
)
Interest Expense, Net
 

 
1

 

 
(2
)
 
1

 
(1
)
 
(2
)
 
(3
)
Income Taxes (26)
 
(0.04
)
 
10

 
(1
)
 
(1
)
 
(7
)
 
(32
)
 
(4
)
 
(35
)
Equity in Earnings of Unconsolidated Affiliates
 

 
1

 

 

 

 

 

 
1

Noncontrolling Interests (27)
 
(0.03
)
 
(27
)
 

 

 

 

 

 
(27
)
Other
 

 
1

 
1

 
1

 
(3
)
 
(1
)
 
(1
)
 
(2
)
Share Differential (28)
 
(0.02
)
 

 

 

 

 

 

 

2017 Adjusted (non-GAAP) Operating Earnings (Loss)
 
0.55

 
252

 
123

 
95

 
82

 
48

 
(64
)
 
536

2017 Adjusted (non-GAAP) Operating Earnings (Loss) Adjustments:
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $6, $1 and $7, respectively)
 
(0.01
)
 
(9
)
 

 

 

 

 
1

 
(8
)
Unrealized Gains Related to NDT Fund Investments (net of taxes of $67) (1)
 
0.12

 
108

 

 

 

 

 

 
108

Amortization of Commodity Contract Intangibles (net of taxes of $5) (2)
 
(0.01
)
 
(8
)
 

 

 

 

 

 
(8
)
Merger and Integration Costs (net of taxes of $0, $1, $0 and $1, respectively) (3)
 

 
(1
)
 

 

 
(1
)
 

 
1

 
(1
)
Long-Lived Asset Impairments (net of taxes of $8, $9, $1 and $16, respectively) (5)
 
(0.03
)
 
(12
)
 

 

 

 
(16
)
 
(1
)
 
(29
)
Plant Retirements and Divestitures (net of taxes of $45) (6)
 
(0.07
)
 
(70
)
 

 

 

 

 

 
(70
)
Cost Management Program (net of taxes of $5, $1, $0 and $6, respectively) (7)
 
(0.01
)
 
(8
)
 

 
(1
)
 
(1
)
 

 

 
(10
)
Reassessment of Deferred Income Taxes (entire amount represents tax expense) (8)
 
1.30

 
1,874

 
(3
)
 
12

 
(5
)
 
(33
)
 
(588
)
 
1,257

Gain on Deconsolidation of Business (net of taxes of $83) (12)
 
0.14

 
130

 

 

 

 

 

 
130

Vacation Policy Change (net of taxes of $16, $1, $1, $3 and $21, respectively) (13)
 
0.03

 
26

 

 
1

 
1

 
5

 

 
33

Change in Environmental Remediation Liabilities (net of taxes of $17) (14)
 
(0.03
)
 
(27
)
 

 

 

 

 

 
(27
)
Noncontrolling Interests (net of taxes of $8) (11)
 
(0.04
)
 
(40
)
 

 

 

 

 

 
(40
)
2017 GAAP Net Income (Loss)
 
$
1.94

 
$
2,215

 
$
120

 
$
107

 
$
76

 
$
4

 
$
(651
)
 
$
1,871







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 49.5 percent and 76.2 percent for the three months ended December 31, 2017 and 2016, respectively.

(a)
PHI consolidated results include 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)
For BGE, Pepco and DPL Maryland and beginning in 2017 for ComEd, customer rates are adjusted to eliminate the impacts of weather and customer usage 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 and losses 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, in 2016, the Integrys and ConEdison Solutions acquisitions, and in 2017, the ConEdison Solutions and FitzPatrick acquisitions.
(3)
Primarily 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 and FitzPatrick acquisitions.
(4)
Represents costs incurred as part of the settlement orders approving the PHI acquisition and a charge related to a 2012 CEG merger commitment.
(5)
Primarily reflects charges to earnings related to the PHI 2017 impairment of the District of Columbia sponsorship intangible asset.
(6)
In 2016, primarily reflects incremental accelerated depreciation and amortization expenses from June 2, 2016 through December 6, 2016 pursuant to the second quarter decision to early retire the Clinton and Quad Cities nuclear generation facilities, which decision was reversed in December 2016, partially offset by the reversal of certain one-time charges for materials & supplies inventory reserves and severance reserves upon Generation’s decision to continue operating the plants with the passage of the Illinois Zero Emission Standard. In 2017, primarily reflects accelerated depreciation and amortization expenses associated with Generation’s decision to early retire the Three Mile Island nuclear facility.
(7)
Represents severance and reorganization costs related to a cost management program.
(8)
Reflects in 2016 the non-cash impact of the remeasurement of deferred income taxes as a result of changes in forecasted apportionment related to the PHI acquisition, and in 2017, the one-time non-cash impacts associated with the Tax Cuts and Jobs Act (including impacts on pension obligations contained within Other).
(9)
Reflects a non-cash benefit pursuant to the annual update of the Generation nuclear decommissioning obligation related to the non-regulatory units.
(10)
Reflects the one-time recognition for a loss on sale of assets and asset impairment charges pursuant to Generation’s strategic decision in the fourth quarter of 2016 to narrow the scope and scale of its growth and development activities.
(11)
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.
(12)
Represents the gain recorded upon deconsolidation of EGTP's net liabilities, which included the previously impaired assets and related debt, as a result of the November 2017 bankruptcy filing.
(13)
Represents the reversal of previously accrued vacation expenses as a result of a change in Exelon's vacation vesting policy.
(14)
Represents charges to adjust the environmental reserve associated with future remediation of the West Lake Landfill Superfund Site.
(15)
For ComEd, primarily reflects lower revenues resulting from the change to defer and recover over time energy efficiency costs pursuant to the Illinois Future Energy Jobs Act, almost entirely offset by 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). For BGE and PHI, primarily reflects increased revenue as a result of rate increases.
(16)
Primarily reflects the acquisition of the FitzPatrick nuclear facility and increased nuclear output.
(17)
Primarily reflects a decrease in fuel prices, offset by increased nuclear output as a result of the FitzPatrick acquisition.
(18)
Primarily reflects increased capacity prices in the New England, Midwest and Mid-Atlantic regions.
(19)
Reflects the impact of the New York Clean Energy Standard.
(20)
Primarily reflects lower realized energy prices and the conclusion of the Ginna Reliability Support Services Agreement, partially offset by the addition of two combined-cycle gas turbines in Texas.
(21)
Primarily reflects decreased variable compensation costs across the operating companies, partially offset at Generation by increased costs related to the acquisition of the FitzPatrick nuclear facility.
(22)
Primarily reflects the impact of increased refueling outage costs given an increased scope of outage activities, despite decreased outage days excluding Salem.
(23)
Primarily reflects the unfavorable impact of lower pension and OPEB discount rates, partially offset by the favorable impact of lower health care claims experience.
(24)
For Generation, primarily reflects the impact of an increased NEIL insurance credit. For ComEd, primarily reflects the change to defer and recover over time energy efficiency costs pursuant to the Illinois Future Energy Jobs Act. For BGE, primarily reflects the favorable 2016 settlement of the Baltimore City conduit fee dispute and an increase in uncollectible accounts expense.
(25)
For Generation, reflects increased depreciation for the addition of two combined-cycle gas turbines in Texas, partially offset by the absence of depreciation related to EGTP assets. Additionally, primarily reflects increased depreciation from ongoing capital expenditures across all operating companies.
(26)
For Generation, primarily reflects the favorable change in one-time tax adjustments. Additionally, primarily reflects 2017 impairments at ComEd, BGE, and PHI of certain transmission-related income tax regulatory assets.
(27)
Reflects elimination from Generation’s results of activity attributable to noncontrolling interests, primarily for CENG and the Renewables Joint Venture.
(28)
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)
Twelve Months Ended December 31, 2017 and 2016
(unaudited)
 
 
Exelon
Earnings per
Diluted Share
 
Generation
 
ComEd
 
PECO
 
BGE
 
PHI (a)
 
Other (b)
 
Exelon (a)
2016 GAAP Net Income (Loss)
 
$
1.22

 
$
496

 
$
378

 
$
438

 
$
286

 
$
(61
)
 
$
(403
)
 
$
1,134

2016 Adjusted (non-GAAP) Operating (Earnings) Loss Adjustments:
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $18)
 
0.03

 
24

 

 

 

 

 

 
24

Unrealized Gains Related to NDT Fund Investments (net of taxes of $77) (1)
 
(0.13
)
 
(118
)
 

 

 

 

 

 
(118
)
Amortization of Commodity Contract Intangibles (net of taxes of $22) (2)
 
0.04

 
35

 

 

 

 

 

 
35

Merger and Integration Costs (net of taxes of $22, $2, $2, $28, $0, and $50, respectively) (3)
 
0.12

 
35

 
(3
)
 
3

 

 
42

 
37

 
114

Merger Commitments (net of taxes of $10, $77, $39 and $126, respectively) (4)
 
0.47

 
42

 

 

 

 
247

 
148

 
437

Long-Lived Asset Impairments (net of taxes of $68) (5)
 
0.11

 
103

 

 

 

 

 

 
103

Plant Retirements and Divestitures (net of taxes of $273) (6)
 
0.47

 
432

 

 

 

 

 

 
432

Reassessment of Deferred Income Taxes (entire amount represents tax expense) (7)
 
0.01

 
20

 

 

 

 

 
(10
)
 
10

Cost Management Program (net of taxes of $17, $2, $2 and $21, respectively) (8)
 
0.04

 
28

 

 
3

 
3

 

 

 
34

Like-Kind Exchange Tax Position (net of taxes of $42, $19 and $61, respectively) (9)
 
0.21

 

 
149

 

 

 

 
50

 
199

Asset Retirement Obligation (net of taxes of $13) (10)
 
(0.08
)
 
(75
)
 

 

 

 

 

 
(75
)
Curtailment of Generation Growth and Development Activities (net of taxes of $35) (11)
 
0.06

 
57

 

 

 

 

 

 
57

Noncontrolling Interests (net of taxes of $9) (12)
 
0.11

 
102

 

 

 

 

 

 
102

2016 Adjusted (non-GAAP) Operating Earnings (Loss)
 
2.68

 
1,181

 
524


444


289


228


(178
)
 
2,488

Year Over Year Effects on Earnings:
ComEd, PECO, BGE and PHI Margins:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Weather
 
(0.05
)
 

 
(21
)
(c)
(14
)
 

(c)
(8
)
(c)

 
(43
)
Load
 
(0.01
)
 

 
(3
)
(c)
(9
)
 

(c)
3

(c)

 
(9
)
Other Energy Delivery (18)
 
0.64

 

 
88

(d)
(4
)
(d)
62

(d)
462

(d)

 
608

Generation Energy Margins, Excluding Mark-to-Market:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Nuclear Volume (19)
 
0.11

 
106

 

 

 

 

 

 
106

Nuclear Fuel Cost (20)
 
0.01

 
12

 

 

 

 

 

 
12

Capacity Pricing (21)
 
0.07

 
64

 

 

 

 

 

 
64

Zero Emission Credit Revenue (22)
 
0.20

 
192

 

 

 

 

 

 
192

Market and Portfolio Conditions (23)
 
(0.43
)
 
(412
)
 

 

 

 

 

 
(412
)
Operating and Maintenance Expense:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 

Labor, Contracting and Materials (24)
 
(0.10
)
 
(32
)
 
24

 
(10
)
 
7

 
(85
)
 

 
(96
)
Planned Nuclear Refueling Outages (25)
 
(0.07
)
 
(69
)
 

 

 

 

 

 
(69
)
Pension and Non-Pension Postretirement Benefits (26)
 
(0.01
)
 
(6
)
 
(2
)
 
2

 
2

 
(4
)
 
(2
)
 
(10
)
Other Operating and Maintenance (27)
 
0.03

 
(12
)
 
38

 
11

 
7

 
(54
)
 
37

 
27

Depreciation and Amortization Expense (28)
 
(0.22
)
 
(19
)
 
(45
)
 
(9
)
 
(30
)
 
(95
)
 
(7
)
 
(205
)
Interest Expense, Net (29)
 
(0.08
)
 
(27
)
 
6

 
(2
)
 
(2
)
 
(29
)
 
(20
)
 
(74
)
Income Taxes (30)
 
(0.06
)
 
(16
)
 
(12
)
 
12

 
(17
)
 
(27
)
 

 
(60
)
Equity in Earnings of Unconsolidated Affiliates
 
(0.01
)
 
(5
)
 

 

 

 

 

 
(5
)
Noncontrolling Interests (31)
 

 
(2
)
 

 

 

 

 

 
(2
)
Other (32)
 
(0.04
)
 
18

 
(5
)
 
6

 

 
(53
)
 
(7
)
 
(41
)
Share Differential (33)
 
(0.06
)
 

 

 

 

 

 

 

2017 Adjusted (non-GAAP) Operating Earnings (Loss)
 
2.60

 
973

 
592


427


318


338


(177
)
 
2,471

2017 Adjusted (non-GAAP) Operating Earnings (Loss) Adjustments:
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $66, $2 and $68, respectively)
 
(0.11
)
 
(109
)
 

 

 

 

 
2

 
(107
)
Unrealized Gains Related to NDT Fund Investments (net of taxes of $204) (1)
 
0.34

 
318

 

 

 

 

 

 
318

Amortization of Commodity Contract Intangibles (net of taxes of $22) (2)
 
(0.04
)
 
(34
)
 

 

 

 

 

 
(34
)
Merger and Integration Costs (net of taxes of $27, $0, $2, $2, $7, $1 and $25, respectively) (3)
 
(0.04
)
 
(44
)
 
(1
)
 
(2
)
 
(2
)
 
10

 
(1
)
 
(40
)
Merger Commitments (net of taxes of $18, $52, $67 and $137, respectively) (4)
 
0.14

 
18

 

 

 

 
59

 
60

 
137

Long-Lived Asset Impairments (net of taxes of $194, $9, $1 and $204, respectively) (5)
 
(0.34
)
 
(306
)
 

 

 

 
(16
)
 
1

 
(321
)
Plant Retirements and Divestitures (net of taxes of $133, $1 and $134, respectively) (6)
 
(0.22
)
 
(208
)
 

 

 

 

 
1

 
(207
)
Reassessment of Deferred Income Taxes (entire amount represents tax expense) (7)
 
1.37

 
1,856

 
(1
)
 
12

 
(5
)
 
(34
)
 
(529
)
 
1,299

Cost Management Program (net of taxes of $15, $3, $3 and $21, respectively) (8)
 
(0.04
)
 
(25
)
 

 
(4
)
 
(5
)
 

 

 
(34
)
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) (10)
 

 
2

 

 

 

 

 

 
2

Tax Settlements (net of taxes of $1) (13)
 
0.01

 
5

 

 

 

 

 

 
5

Bargain Purchase Gain (net of taxes of $0) (14)
 
0.25

 
233

 

 

 

 

 

 
233

Gain on Deconsolidation of Business (net of taxes of $83) (15)
 
0.14

 
130

 

 

 

 

 

 
130

Vacation Policy Change (net of taxes of $16, $1, $1, $3 and $21, respectively) (16)
 
0.03

 
26

 

 
1

 
1

 
5

 

 
33

Change in Environmental Remediation Liabilities (net of taxes of $17) (17)
 
(0.03
)
 
(27
)
 

 

 

 

 

 
(27
)
Noncontrolling Interests (net of taxes of $24) (12)
 
(0.12
)
 
(114
)
 

 

 

 

 

 
(114
)
2017 GAAP Net Income (Loss)
 
$
3.97

 
$
2,694

 
$
567


$
434


$
307


$
362


$
(594
)
 
$
3,770







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 47.4 percent and 48.7 percent for the twelve months ended December 31, 2017 and 2016, respectively.

(a)
For the twelve months ended December 31, 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 include 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)
For BGE, Pepco and DPL Maryland and beginning in 2017 for ComEd, customer rates are adjusted to eliminate the impacts of weather and customer usage 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, in 2016, the Integrys and ConEdison Solutions acquisitions, and in 2017, the ConEdison Solutions and FitzPatrick acquisitions.
(3)
Primarily 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 and FitzPatrick acquisitions, partially offset in 2016 at ComEd, and in 2017 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, and in 2016, a charge related to a 2012 CEG merger commitment, 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 of the ExGen Texas Power, LLC (EGTP) assets and PHI District of Columbia sponsorship intangible asset.
(6)
In 2016, primarily reflects accelerated depreciation and amortization expenses through December 2016 and construction work in progress impairments associated with Generation’s previous decision to early retire the Clinton and Quad Cities nuclear facilities, partially offset by a gain associated with Generation’s sale of the New Boston generating site. In 2017, primarily reflects accelerated depreciation and amortization expenses, increases to materials and supplies inventory reserves, construction work in progress impairments and charges for severance reserves associated with Generation’s decision to early retire the Three Mile Island nuclear facility.
(7)
Reflects in 2016 the non-cash impact of the remeasurement of deferred income taxes as a result of changes in forecasted apportionment related to the PHI acquisition, and in 2017, one-time non-cash impacts associated with remeasurements of deferred income taxes as a result of the Tax Cuts and Jobs Act (including impacts on pension obligations contained within Other), 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 in 2016 the recognition of a penalty and associated interest expense as a result of a tax court decision on Exelon’s like-kind exchange tax position, and in 2017, adjustments to income tax, penalties and interest expenses as a result of the finalization of the IRS tax computation related to Exelon’s like-kind exchange tax position.
(10)
Reflects a non-cash benefit pursuant to the annual update of the Generation nuclear decommissioning obligation related to the non-regulatory units.
(11)
Reflects the one-time recognition for a loss on sale of assets and asset impairment charges pursuant to Generation’s strategic decision in the fourth quarter of 2016 to narrow the scope and scale of its growth and development activities.
(12)
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.
(13)
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.
(14)
Represents the excess of the fair value of assets and liabilities acquired over the purchase price for the FitzPatrick acquisition.
(15)
Represents the gain recorded upon deconsolidation of EGTP's net liabilities, which included the previously impaired assets and related debt, as a result of the November 2017 bankruptcy filing.
(16)
Represents the reversal of previously accrued vacation expenses as a result of a change in Exelon's vacation vesting policy.
(17)
Represents charges to adjust the environmental reserve associated with future remediation of the West Lake Landfill Superfund Site.
(18)
For ComEd, primarily reflects increased 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.
(19)
Primarily reflects the acquisition of the FitzPatrick nuclear facility.
(20)
Primarily reflects a decrease in fuel prices, partially offset by increased nuclear output as a result of the FitzPatrick acquisition.
(21)
Primarily reflects increased capacity prices in the New England region, partially offset by a decrease in January through May capacity prices in the Mid-Atlantic region.
(22)
Reflects the impact of the New York Clean Energy Standard.
(23)
Primarily reflects lower realized energy prices, the impacts of lower load volumes delivered due to mild weather in the third quarter 2017, the conclusion of the Ginna Reliability Support Services Agreement and the impact of declining natural gas prices on Generation’s natural gas portfolio, partially offset by the addition of two combined-cycle gas turbines in Texas.
(24)
For Generation, primarily reflects increased costs related to the acquisition of the FitzPatrick nuclear facility. Additionally, reflects decreased variable compensation costs across the operating companies.
(25)
Primarily reflects an increase in the number of nuclear outage days in 2017, excluding Salem.
(26)
Primarily reflects the unfavorable impact of lower pension and OPEB discount rates, partially offset by the favorable impact of lower health care claims experience.






15



(27)
For Generation, primarily reflects costs related to the acquisition of FitzPatrick, partially offset by the impact of an increased NEIL insurance credit. For ComEd, primarily reflects the change to defer and recover over time energy efficiency costs pursuant to the Illinois Future Energy Jobs Act. For BGE, primarily reflects certain disallowances contained in 2016 rate case orders and decreased storm costs in the BGE service territory, partially offset by the favorable 2016 settlement of the Baltimore City conduit fee dispute.
(28)
For Generation, reflects increased depreciation for the addition of two combined-cycle gas turbines in Texas, offset by the absence of depreciation related to the EGTP assets. For BGE, primarily reflects increased amortization due to the 2016 initiation of cost recovery of the AMI programs. Additionally, primarily reflects increased depreciation from ongoing capital expenditures across all operating companies.
(29)
For Generation, primarily reflects the impact of project in-service dates on the capitalization of interest. 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.
(30)
For Generation, primarily reflects the unfavorable change in one-time tax adjustments. For PECO, primarily reflects an increase in the repairs tax deduction. Additionally, primarily reflects 2016 favorable adjustments at ComEd and BGE and 2017 impairments at ComEd, BGE, and PHI of certain transmission-related income tax regulatory assets.
(31)
Reflects elimination from Generation’s results of activity attributable to noncontrolling interests, primarily for CENG and the Renewables Joint Venture.
(32)
For Generation, primarily reflects higher realized NDT fund gains, partially offset by increased real estate taxes as a result of the FitzPatrick acquisition.
(33)
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 
 December 31, 2017
 
 
 
Three Months Ended 
 December 31, 2016
 
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
Operating revenues
 
$
4,654

 
$
93

 
(b),(d)
 
$
4,388

 
$
177

 
(b),(d)
Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
2,403

 
61

 
(b),(d),(h)
 
2,221

 
184

 
(b),(h)
Operating and maintenance
 
1,421

 
(38
)
 
(e),(g),(j),(h),(o),(p)
 
1,308

 
123

 
(e),(f),(h),(j),(k),(r)
Depreciation and amortization
 
412

 
(109
)
 
(h)
 
550

 
(251
)
 
(h)
Taxes other than income
 
130

 
2

 
(o)
 
126

 

 
 
Total operating expenses
 
4,366

 
 
 
 
 
4,205

 
 
 
 
Loss on sales of assets
 

 

 
 
 
(89
)
 
89

 
(h),(r)
Gain on deconsolidation of business
 
213

 
(213
)
 
(n)
 

 

 
 
Operating income
 
501

 
 
 
 
 
94

 
 
 
 
Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(98
)
 

 
 
 
(92
)
 

 
 
Other, net
 
299

 
(244
)
 
(c),(i)
 
6

 
37

 
(c)
Total other income and (deductions)
 
201

 
 
 
 
 
(86
)
 
 
 
 
Income before income taxes
 
702

 
 
 
 
 
8

 
 
 
 
Income taxes
 
(1,585
)
 
1,724

 
(b),(c),(d),(e),(g),(h),(i),(j),(n),(o),(p)
 
(3
)
 
105

 
(b),(c),(d),(e),(f),(h),(i),(j),(k),(r)
Equity in losses of unconsolidated affiliates
 
(7
)
 

 
 
 
(9
)
 

 
 
Net income
 
2,280

 
 
 
 
 
2

 
 
 
 
Net income attributable to noncontrolling interests
 
65

 
(40
)
 
(q)
 
43

 
(61
)
 
(q)
Net income (loss) attributable to membership interest
 
$
2,215

 


 
 
 
$
(41
)
 


 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Twelve Months Ended 
 December 31, 2017
 
 
 
Twelve Months Ended 
 December 31, 2016
 
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
Operating revenues
 
$
18,466

 
$
170

 
(b),(d)
 
$
17,751

 
$
553

 
(b),(d)
Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
9,690

 
(72
)
 
(b),(d),(h)
 
8,830

 
395

 
(b),(d),(h)
Operating and maintenance
 
6,291

 
(669
)
 
(e),(g),(h),(j),(k),(o),(p)
 
5,641

 
(213
)
 
(e),(f),(g),(h),(j),(k),(r)
Depreciation and amortization
 
1,457

 
(252
)
 
(d),(h)
 
1,879

 
(704
)
 
(e),(h)
Taxes other than income
 
555

 
2

 
(o)
 
506

 
(1
)
 
(j)
Total operating expenses
 
17,993

 
 
 
 
 
16,856

 
 
 
 
Gain (Loss) on sales of assets
 
2

 
1

 
(h)
 
(59
)
 
57

 
(h),(r)
Bargain purchase gain
 
233

 
(233
)
 
(m)
 

 

 
 
Gain on deconsolidation of business
 
213

 
(213
)
 
(n)
 

 

 
 
Operating income
 
921

 
 
 
 
 
836

 
 
 
 
Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(440
)
 
17

 
(g),(l)
 
(364
)
 

 
 
Other, net
 
948

 
(636
)
 
(c),(i)
 
401

 
(230
)
 
(c)
Total other income and (deductions)
 
508

 
 
 
 
 
37

 
 
 
 
Income before income taxes
 
1,429

 
 
 
 
 
873

 
 
 
 
Income taxes
 
(1,375
)
 
1,932

 
(b),(c),(d),(e),(f),(g),(h),(i),(j),(k),(l),(n),(o),(p)
 
290

 
320

 
(b),(c),(d),(e),(f),(g),(h),(i),(j),(k),(r)
Equity in losses of unconsolidated affiliates
 
(33
)
 

 
 
 
(25
)
 

 
 
Net income
 
2,771

 
 
 
 
 
558

 
 
 
 
Net income attributable to noncontrolling interests
 
77

 
(114
)
 
(q)
 
62

 
(102
)
 
(q)
Net income attributable to membership interest
 
$
2,694

 


 
 
 
$
496

 


 
 






17




(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 impact of 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, in 2016, the Integrys and ConEdison Solutions acquisitions, 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 and FitzPatrick acquisitions.
(f)
Adjustment to exclude in 2016 a charge related to a 2012 CEG merger commitment, and in 2017, a decrease in reserves for uncertain tax positions related to the deductibility of certain merger commitments associated with the 2012 CEG acquisition.
(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 of the ExGen Texas Power, LLC assets.
(h)
Adjustment to exclude for the three months ended December 31, 2016, incremental accelerated depreciation and amortization expenses from June 2, 2016 through December 6, 2016 pursuant to the second quarter decision to early retire the Clinton and Quad Cities nuclear generation facilities, which decision was reversed in December 2016, partially offset by the reversal of certain one-time charges for materials & supplies inventory reserves and severance reserves upon Generation’s decision to continue operating the plants with the passage of the Illinois Zero Emission Standard; and for the twelve months ended December 31, 2016, accelerated depreciation and amortization expenses through December 2016 and construction work in progress impairments associated with Generation’s previous decision to early retire the Clinton and Quad Cities nuclear facilities, partially offset by a gain associated with Generation’s sale of the New Boston generating site. Additionally, reflects an adjustment to exclude in 2017 accelerated depreciation and amortization expenses, increases to materials and supplies inventory reserves, construction work in progress impairments and charges for severance reserves associated with Generation’s decision to early retire the Three Mile Island nuclear facility.
(i)
Adjustment to exclude in 2016 the non-cash impact of the remeasurement of deferred income taxes as a result of changes in forecasted apportionment related to the PHI acquisition, and in 2017, one-time non-cash impacts associated with remeasurements of deferred income taxes as a result of the Tax Cuts and Jobs Act, a change in the Illinois statutory tax rate and changes in forecasted apportionment.
(j)
Adjustment to exclude severance and reorganization costs related to a cost management program.
(k)
Adjustment to exclude a non-cash benefit pursuant to the annual update of the Generation nuclear decommissioning obligation related to the non-regulatory units.
(l)
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.
(m)
Adjustment to exclude the excess of the fair value of assets and liabilities acquired over the purchase price for the FitzPatrick acquisition.
(n)
Adjustment to exclude the gain recorded upon deconsolidation of EGTP's net liabilities, which included the previously impaired assets and related debt, as a result of the November 2017 bankruptcy filing.
(o)
Adjustment to exclude the reversal of previously accrued vacation expenses as a result of a change in Exelon's vacation vesting policy.
(p)
Represents charges to adjust the environmental reserve associated with future remediation of the West Lake Landfill Superfund Site.
(q)
Adjustment to exclude the 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.
(r)
Adjustment to exclude the one-time recognition for a loss on sale of assets and asset impairment charges pursuant to Generation’s strategic decision in the fourth quarter of 2016 to narrow the scope and scale of its growth and development activities.







18



EXELON CORPORATION
GAAP Consolidated Statements of Operations and
Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments
(unaudited)
(in millions)
 
 
ComEd
 
 
 
 
Three Months Ended 
 December 31, 2017
 
 
 
Three Months Ended 
 December 31, 2016
 
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
Operating revenues
 
$
1,309

 
$

 
 
 
$
1,223

 
$

 
 
Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
399

 

 
 
 
317

 

 
 
Operating and maintenance
 
332

 

 
 
 
417

 
(1
)
 
(d)
Depreciation and amortization
 
220

 

 
 
 
201

 

 
 
Taxes other than income
 
73

 

 
 
 
71

 

 
 
Total operating expenses
 
1,024

 
 
 
 
 
1,006

 
 
 
 
Gain on sales of assets
 
1

 

 
 
 

 

 
 
Operating income
 
286

 
 
 
 
 
217

 
 
 
 
Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(87
)
 

 
 
 
(87
)
 

 
 
Other, net
 
10

 

 
 
 
8

 

 
 
Total other income and (deductions)
 
(77
)
 
 
 
 
 
(79
)
 
 
 
 
Income before income taxes
 
209

 
 
 
 
 
138

 
 
 
 
Income taxes
 
89

 
(3
)
 
(b)
 
58

 

 
 
Net income
 
$
120

 


 
 
 
$
80

 


 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Twelve Months Ended 
 December 31, 2017
 
 
 
Twelve Months Ended 
 December 31, 2016
 
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
Operating revenues
 
$
5,536

 
$

 
 
 
$
5,254

 
$
(8
)
 
(d)
Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
1,641

 

 
 
 
1,458

 

 
 
Operating and maintenance
 
1,427

 
(2
)
 
(d)
 
1,530

 
(3
)
 
(d)
Depreciation and amortization
 
850

 

 
 
 
775

 

 
 
Taxes other than income
 
296

 

 
 
 
293

 

 
 
Total operating expenses
 
4,214

 
 
 
 
 
4,056

 
 
 
 
Gain on sales of assets
 
1

 

 
 
 
7

 

 
 
Operating income
 
1,323

 
 
 
 
 
1,205

 
 
 
 
Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(361
)
 
14

 
(c)
 
(461
)
 
105

 
(c)
Other, net
 
22

 

 
 
 
(65
)
 
86

 
(c)
Total other income and (deductions)
 
(339
)
 
 
 
 
 
(526
)
 
 
 
 
Income before income taxes
 
984

 
 
 
 
 
679

 
 
 
 
Income taxes
 
417

 
(9
)
 
(b),(c),(d)
 
301

 
40

 
(c),(d)
Net income
 
$
567

 


 
 
 
$
378

 


 
 

(a)
Results reported in accordance with accounting principles generally accepted in the United States (GAAP).
(b)
Adjustment to exclude one-time non-cash impacts associated with remeasurements of deferred income taxes as a result of the Tax Cuts and Jobs Act and a change in the Illinois statutory tax rate.
(c)
Adjustment to exclude in 2016 the recognition of a penalty and associated interest expense as a result of a tax court decision on Exelon's like-kind exchange tax position, and in 2017, adjustments to income tax and interest expenses as a result of the finalization of the IRS tax computation related to Exelon’s like-kind exchange tax position.






19



(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, partially offset in 2016 at ComEd by the anticipated recovery of previously incurred PHI acquisition costs.






20



EXELON CORPORATION
GAAP Consolidated Statements of Operations and
Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments
(unaudited)
(in millions)
 
 
PECO
 
 
 
 
Three Months Ended 
 December 31, 2017
 
 
 
Three Months Ended 
 December 31, 2016
 
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
Operating revenues
 
$
729

 
$

 
 
 
$
701

 
$

 
 
Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
250

 

 
 
 
238

 

 
 
Operating and maintenance
 
211

 
(1
)
 
(d),(e)
 
206

 
(3
)
 
(b),(d)
Depreciation and amortization
 
73

 

 
 
 
69

 

 
 
Taxes other than income
 
38

 

 
 
 
38

 

 
 
Total operating expenses
 
572

 
 
 
 
 
551

 
 
 
 
Operating income
 
157

 
 
 
 
 
150

 
 
 
 
Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(33
)
 

 
 
 
(31
)
 

 
 
Other, net
 
3

 

 
 
 
2

 

 
 
Total other income and (deductions)
 
(30
)
 
 
 
 
 
(29
)
 
 
 
 
Income before income taxes
 
127

 
 
 
 
 
121

 
 
 
 
Income taxes
 
20

 
13

 
(c),(d),(e)
 
29

 
1

 
(b),(d)
Net income
 
$
107

 


 
 
 
$
92

 


 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Twelve Months Ended 
 December 31, 2017
 
 
 
Twelve Months Ended 
 December 31, 2016
 
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
Operating revenues
 
$
2,870

 
$

 
 
 
$
2,994

 
$

 
 
Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
969

 

 
 
 
1,047

 

 
 
Operating and maintenance
 
806

 
(9
)
 
(b),(d),(e)
 
811

 
(10
)
 
(b),(d)
Depreciation and amortization
 
286

 

 
 
 
270

 

 
 
Taxes other than income
 
154

 

 
 
 
164

 

 
 
Total operating expenses
 
2,215

 
 
 
 
 
2,292

 
 
 
 
Operating income
 
655

 
 
 
 
 
702

 
 
 
 
Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(126
)
 

 
 
 
(123
)
 

 
 
Other, net
 
9

 

 
 
 
8

 

 
 
Total other income and (deductions)
 
(117
)
 
 
 
 
 
(115
)
 
 
 
 
Income before income taxes
 
538

 
 
 
 
 
587

 
 
 
 
Income taxes
 
104

 
16

 
(b),(c),(d),(e)
 
149

 
4

 
(b),(d)
Net income
 
$
434

 


 
 
 
$
438

 


 
 

(a)
Results reported in accordance with accounting principles generally accepted in the United States (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 one-time non-cash impacts associated with remeasurements of deferred income taxes as a result of the Tax Cuts and Jobs Act.
(d)
Adjustment to exclude reorganization costs related to a cost management program.
(e)
Adjustment to exclude the reversal of previously accrued vacation expenses as a result of a change in Exelon's vacation vesting policy.







21



EXELON CORPORATION
GAAP Consolidated Statements of Operations and
Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments
(unaudited)
(in millions)
 
 
BGE
 
 
 
 
Three Months Ended 
 December 31, 2017
 
 
 
Three Months Ended 
 December 31, 2016
 
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
Operating revenues
 
$
813

 
$

 
 
 
$
812

 
$

 
 
Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
280

 

 
 
 
300

 

 
 
Operating and maintenance
 
184

 
(2
)
 
(b),(d),(e)
 
149

 
(3
)
 
(b),(d)
Depreciation and amortization
 
125

 

 
 
 
115

 

 
 
Taxes other than income
 
61

 

 
 
 
58

 

 
 
Total operating expenses
 
650

 
 
 
 
 
622

 
 
 
 
Operating income
 
163

 
 
 
 
 
190

 
 
 
 
Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(25
)
 

 
 
 
(27
)
 

 
 
Other, net
 
4

 

 
 
 
5

 

 
 
Total other income and (deductions)
 
(21
)
 
 
 
 
 
(22
)
 
 
 
 
Income before income taxes
 
142

 
 
 
 
 
168

 
 
 
 
Income taxes
 
66

 
(4
)
 
(b),(c),(d),(e)
 
65

 
1

 
(b),(d)
Net income attributable to common shareholder
 
$
76

 


 
 
 
$
103

 


 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Twelve Months Ended 
 December 31, 2017
 
 
 
Twelve Months Ended 
 December 31, 2016
 
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
Operating revenues
 
$
3,176

 
$

 
 
 
$
3,233

 
$

 
 
Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
1,133

 

 
 
 
1,294

 

 
 
Operating and maintenance
 
716

 
(10
)
 
(b),(d),(e)
 
737

 
(5
)
 
(b),(d)
Depreciation and amortization
 
473

 

 
 
 
423

 

 
 
Taxes other than income
 
240

 

 
 
 
229

 

 
 
Total operating expenses
 
2,562

 
 
 
 
 
2,683

 
 
 
 
Operating income
 
614

 
 
 
 
 
550

 
 
 
 
Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(105
)
 

 
 
 
(103
)
 

 
 
Other, net
 
16

 

 
 
 
21

 

 
 
Total other income and (deductions)
 
(89
)
 
 
 
 
 
(82
)
 
 
 
 
Income before income taxes
 
525

 
 
 
 
 
468

 
 
 
 
Income taxes
 
218

 
(1
)
 
(b),(c),(d),(e)
 
174

 
2

 
(b),(d)
Net income
 
307

 


 
 
 
294

 
 
 
 
Preference stock dividends
 

 

 
 
 
8

 

 
 
Net income attributable to common shareholder
 
$
307

 


 
 
 
$
286

 


 
 

(a)
Results reported in accordance with accounting principles generally accepted in the United States (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 one-time non-cash impacts associated with remeasurements of deferred income taxes as a result of the Tax Cuts and Jobs Act.
(d)
Adjustment to exclude reorganization costs related to a cost management program.
(e)
Adjustment to exclude the reversal of previously accrued vacation expenses as a result of a change in Exelon's vacation vesting policy.






22



EXELON CORPORATION
GAAP Consolidated Statements of Operations and
Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments
(unaudited)
(in millions)
 
 
PHI
 
 
 
 
Three Months Ended 
 December 31, 2017
 
 
 
Three Months Ended 
 December 31, 2016
 
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
Operating revenues
 
$
1,121

 
$

 
 
 
$
1,078

 
$

 
 
Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
398

 

 
 
 
410

 

 
 
Operating and maintenance
 
292

 
(12
)
 
(e),(f),(g)
 
310

 
(17
)
 
(c),(d)
Depreciation and amortization
 
164

 

 
 
 
160

 

 
 
Taxes other than income
 
108

 

 
 
 
107

 

 
 
Total operating expenses
 
962

 
 
 
 
 
987

 
 
 
 
Loss on sales of assets
 

 

 
 
 
(1
)
 

 
 
Operating income
 
159

 
 
 
 
 
90

 
 
 
 
Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(62
)
 

 
 
 
(61
)
 

 
 
Other, net
 
15

 

 
 
 
13

 

 
 
Total other income and (deductions)
 
(47
)
 
 
 
 
 
(48
)
 
 
 
 
Income before income taxes
 
112

 
 
 
 
 
42

 
 
 
 
Income taxes
 
108

 
(33
)
 
(e),(f),(g)
 
12

 
5

 
(c),(d)
Net income
 
$
4

 


 
 
 
$
30

 


 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Twelve Months Ended 
 December 31, 2017
 
 
 
Twelve Months Ended 
 December 31, 2016 (b)
 
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
 
GAAP (a)
 
Non-GAAP Adjustments
 
 
Operating revenues
 
$
4,679

 
$

 
 
 
$
3,643

 
$

 
 
Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
1,716

 

 
 
 
1,447

 

 
 
Operating and maintenance
 
1,068

 
13

 
(c),(d),(e),(f),(g)
 
1,233

 
(392
)
 
(c),(d)
Depreciation and amortization
 
675

 

 
 
 
515

 

 
 
Taxes other than income
 
452

 

 
 
 
354

 

 
 
Total operating expenses
 
3,911

 
 
 
 
 
3,549

 
 
 
 
Gain (loss) on sales of assets
 
1

 

 
 
 
(1
)
 

 
 
Operating income (loss)
 
769

 
 
 
 
 
93

 
 
 
 
Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(245
)
 

 
 
 
(195
)
 

 
 
Other, net
 
54

 

 
 
 
44

 

 
 
Total other income and (deductions)
 
(191
)
 
 
 
 
 
(151
)
 
 
 
 
Income (Loss) before income taxes
 
578

 
 
 
 
 
(58
)
 
 
 
 
Income taxes
 
217

 
10

 
(c),(d),(e),(f),(g)
 
3

 
103

 
(c),(d)
Equity in earnings of unconsolidated affiliates
 
1

 
 
 
 
 

 
 
 
 
Net income (loss)
 
$
362

 


 
 
 
$
(61
)
 


 
 

(a)
Results reported in accordance with accounting principles generally accepted in the United States (GAAP).
(b)
For the twelve months ended December 31, 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 include Potomac Electric Power Company, Delmarva Power & Light Company, and Atlantic City Electric Company.






23



(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 2017 by the anticipated recovery of previously incurred PHI acquisition costs.
(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 impairment of the District of Columbia sponsorship intangible asset.
(f)
Adjustment to exclude to exclude one-time non-cash impacts associated with remeasurements of deferred income taxes as a result of the Tax Cuts and Jobs Act.
(g)
Adjustment to exclude the reversal of previously accrued vacation expenses as a result of a change in Exelon's vacation vesting policy.






24



EXELON CORPORATION
GAAP Consolidated Statements of Operations and
Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments
(unaudited)
(in millions)
 
 
Other (a)
 
 
 
 
Three Months Ended 
 December 31, 2017
 
 
 
Three Months Ended 
 December 31, 2016
 
 
 
 
GAAP (b)
 
Non-GAAP Adjustments
 
 
 
GAAP (b)
 
Non-GAAP Adjustments
 
 
Operating revenues
 
$
(245
)
 
$

 
 
 
$
(327
)
 
$

 
 
Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
(222
)
 

 
 
 
(308
)
 

 
 
Operating and maintenance
 
(45
)
 

 
 
 
(19
)
 
8

 
(d),(e)
Depreciation and amortization
 
21

 

 
 
 
20

 

 
 
Taxes other than income
 
8

 

 
 
 
8

 

 
 
Total operating expenses
 
(238
)
 
 
 
 
 
(299
)
 
 
 
 
(Loss) Gain on sales of assets
 
(1
)
 

 
 
 
1

 

 
 
Operating loss
 
(8
)
 
 
 
 
 
(27
)
 
 
 
 
Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(60
)
 

 
 
 
(58
)
 

 
 
Other, net
 

 

 
 
 
(1
)
 

 
 
Total other income and (deductions)
 
(60
)
 
 
 
 
 
(59
)
 
 
 
 
Loss before income taxes
 
(68
)
 
 
 
 
 
(86
)
 
 
 
 
Income taxes
 
583

 
(587
)
 
(c),(d),(f),(h)
 
(25
)
 
6

 
(d),(e),(f),(h)
Equity in earnings of unconsolidated affiliates
 
1

 

 
 
 
1

 

 
 
Net loss
 
(650
)
 


 
 
 
(60
)
 


 
 
Net income attributable to noncontrolling interests and preference stock dividends
 
1

 

 
 
 

 

 
 
Net loss attributable to common shareholders
 
$
(651
)
 


 
 
 
$
(60
)
 


 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Twelve Months Ended 
 December 31, 2017
 
 
 
Twelve Months Ended 
 December 31, 2016
 
 
 
 
GAAP (b)
 
Non-GAAP Adjustments
 
 
 
GAAP (b)
 
Non-GAAP Adjustments
 
 
Operating revenues
 
$
(1,196
)
 
$

 
 
 
$
(1,515
)
 
$

 
 
Operating expenses
 
 
 
 
 
 
 
 
 
 
 
 
Purchased power and fuel
 
(1,114
)
 

 
 
 
(1,436
)
 

 
 
Operating and maintenance
 
(182
)
 
(9
)
 
(d),(e)
 
96

 
(226
)
 
(d),(e)
Depreciation and amortization
 
87

 

 
 
 
74

 

 
 
Taxes other than income
 
34

 

 
 
 
30

 

 
 
Total operating expenses
 
(1,175
)
 
 
 
 
 
(1,236
)
 
 
 
 
(Loss) Gain on sales of assets
 
(1
)
 

 
 
 
5

 

 
 
Operating loss
 
(22
)
 
 
 
 
 
(274
)
 
 
 
 
Other income and (deductions)
 
 
 
 
 
 
 
 
 
 
 
 
Interest expense, net
 
(283
)
 
27

 
(g)
 
(290
)
 
48

 
(g)
Other, net
 
7

 
(2
)
 
(g)
 
4

 
20

 
(g)
Total other income and (deductions)
 
(276
)
 
 
 
 
 
(286
)
 
 
 
 
Loss before income taxes
 
(298
)
 
 
 
 
 
(560
)
 
 
 
 
Income taxes
 
294

 
(382
)
 
(c),(d),(e),(f),(g),(h)
 
(156
)
 
69

 
(d),(e),(f),(g)
Equity in earnings of unconsolidated affiliates
 

 

 
 
 
1

 

 
 
Net income (loss)
 
(592
)
 
 
 
 
 
(403
)
 
 
 
 
Net income attributable to noncontrolling interests and preference stock dividends
 
2

 

 
 
 

 

 
 
Net loss attributable to common shareholders
 
$
(594
)
 


 
 
 
$
(403
)
 
 
 
 
(a)
Other primarily includes eliminating and consolidating adjustments, Exelon’s corporate operations, shared service entities and other financing and investment activities.
(b)
Results reported in accordance with accounting principles generally accepted in the United States (GAAP).






25



(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 in 2016 the non-cash impact of the remeasurement of deferred income taxes as a result of changes in forecasted apportionment related to the PHI acquisition, and in 2017, one-time non-cash impacts associated with remeasurements of deferred income taxes as a result of the Tax Cuts and Jobs Act (including impacts on pension obligations), changes in the Illinois and District of Columbia statutory tax rates and changes in forecasted apportionment.
(g)
Adjustment to exclude in 2016 the recognition of a penalty and associated interest expense as a result of a tax court decision on Exelon’s like-kind exchange tax position, and in 2017, adjustments to income tax, penalties and interest expenses as a result of the finalization of the IRS tax computation related to Exelon’s like-kind exchange tax position.
(h)
Adjustment to exclude costs related to impairments at Corporate.






26



EXELON CORPORATION
Exelon Generation Statistics
 
 
Three Months Ended
 
 
December 31, 2017
 
September 30, 2017
 
June 30, 2017
 
March 31, 2017
 
December 31, 2016
Supply (in GWhs)
 
 
 
 
 
 
 
 
 
 
Nuclear Generation
 
 
 
 
 
 
 
 
 
 
Mid-Atlantic(a)
 
16,196

 
16,480

 
15,246

 
16,545

 
16,410

Midwest
 
23,922

 
24,362

 
22,592

 
22,468

 
23,743

New York(a)(e)
 
7,410

 
6,905

 
6,227

 
4,491

 
4,681

Total Nuclear Generation
 
47,528

 
47,747

 
44,065

 
43,504

 
44,834

Fossil and Renewables
 
 
 
 
 
 
 
 
 
 
Mid-Atlantic
 
459

 
596

 
899

 
836

 
442

Midwest
 
430

 
218

 
417

 
418

 
442

New England
 
1,258

 
1,919

 
1,925

 
2,077

 
1,142

New York
 
1

 
1

 
1

 
1

 
1

ERCOT
 
2,684

 
5,703

 
2,315

 
1,370

 
1,056

Other Power Regions(b)
 
1,213

 
2,149

 
2,084

 
1,423

 
1,935

Total Fossil and Renewables
 
6,045

 
10,586

 
7,641

 
6,125

 
5,018

Purchased Power
 
 
 
 
 
 
 
 
 
 
Mid-Atlantic
 
961

 
2,541

 
2,901

 
3,398

 
2,849

Midwest
 
355

 
217

 
413

 
388

 
400

New England
 
4,596

 
4,513

 
4,343

 
5,064

 
4,768

New York
 

 

 

 
28

 

ERCOT
 
1,622

 
1,199

 
1,871

 
2,655

 
3,189

Other Power Regions(b)
 
4,173

 
3,982

 
3,507

 
2,868

 
3,308

Total Purchased Power
 
11,707

 
12,452

 
13,035

 
14,401

 
14,514

Total Supply/Sales by Region
 
 
 
 
 
 
 
 
 
 
Mid-Atlantic(c)
 
17,616

 
19,617

 
19,046

 
20,779

 
19,701

Midwest(c)
 
24,707

 
24,797

 
23,422

 
23,274

 
24,585

New England
 
5,854

 
6,432

 
6,268

 
7,141

 
5,910

New York
 
7,411

 
6,906

 
6,228

 
4,520

 
4,682

ERCOT
 
4,306

 
6,902

 
4,186

 
4,025

 
4,245

Other Power Regions(b)
 
5,386

 
6,131

 
5,591

 
4,291

 
5,243

Total Supply/Sales by Region
 
65,280

 
70,785

 
64,741

 
64,030

 
64,366

 
 
Three Months Ended
 
 
December 31, 2017
 
September 30, 2017
 
June 30, 2017
 
March 31, 2017
 
December 31, 2016
Outage Days(d)
 
 
 
 
 
 
 
 
 
 
Refueling(e)
 
60

 
13

 
125

 
95

 
71

Non-refueling(e)
 
18

 
15

 
12

 
8

 
32

Total Outage Days
 
78

 
28

 
137

 
103

 
103

(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)
Includes affiliate sales to PECO, BGE, Pepco, DPL and ACE in the Mid-Atlantic region and affiliate sales to ComEd in the Midwest region.
(d)
Outage days exclude Salem.
(e)
Includes the ownership of the FitzPatrick nuclear facility from March 31, 2017.







27



EXELON CORPORATION
Exelon Generation Statistics
Twelve Months Ended December 31, 2017 and 2016
 
 
December 31, 2017
 
December 31, 2016
Supply (in GWhs)
 
 
 
 
Nuclear Generation
 
 
 
 
Mid-Atlantic(a)
 
64,466

 
63,447

Midwest
 
93,344

 
94,668

New York(a)(c)
 
25,033

 
18,684

Total Nuclear Generation
 
182,843

 
176,799

Fossil and Renewables
 
 
 
 
Mid-Atlantic
 
2,789

 
2,731

Midwest
 
1,482

 
1,488

New England
 
7,179

 
6,968

New York
 
3

 
3

ERCOT
 
12,072

 
6,785

Other Power Regions
 
6,869

 
8,179

Total Fossil and Renewables
 
30,394

 
26,154

Purchased Power
 
 
 
 
Mid-Atlantic
 
9,801

 
16,874

Midwest
 
1,373

 
2,255

New England
 
18,517

 
16,632

New York
 
28

 

ERCOT
 
7,346

 
10,637

Other Power Regions
 
14,530

 
13,589

Total Purchased Power
 
51,595

 
59,987

Total Supply/Sales by Region
 
 
 
 
Mid-Atlantic(b)
 
77,056

 
83,052

Midwest(b)
 
96,199

 
98,411

New England
 
25,696

 
23,600

New York
 
25,064

 
18,687

ERCOT
 
19,418

 
17,422

Other Power Regions
 
21,399

 
21,768

Total Supply/Sales by Region
 
264,832

 
262,940

(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)
Includes affiliate sales to PECO, BGE, Pepco, DPL and ACE in the Mid-Atlantic region and affiliate sales to ComEd in the Midwest region.
(c)
Includes the ownership of the FitzPatrick nuclear facility from March 31, 2017.
































28



EXELON CORPORATION
ComEd Statistics
Three Months Ended December 31, 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
 
6,128

 
6,052

 
1.3
 %
 
(0.6
)%
 
$
637

 
$
578

 
10.2
 %
Small Commercial & Industrial
 
7,698

 
7,527

 
2.3
 %
 
2.2
 %
 
326

 
310

 
5.2
 %
Large Commercial & Industrial
 
6,755

 
6,784

 
(0.4
)%
 
(0.4
)%
 
109

 
112

 
(2.7
)%
Public Authorities & Electric Railroads
 
359

 
351

 
2.3
 %
 
2.4
 %
 
11

 
12

 
(8.3
)%
Total Retail
 
20,940

 
20,714

 
1.1
 %
 
0.5
 %
 
1,083

 
1,012

 
7.0
 %
Other Revenue (b)
 
 
 
 
 
 
 
 
 
226

 
211

 
7.1
 %
Total Electric Revenue (c)
 
 
 
 
 
 
 
 
 
$
1,309

 
$
1,223

 
7.0
 %
Purchased Power
 
 
 
 
 
 
 
 
 
$
399

 
$
317

 
25.9
 %
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
% Change
Heating and Cooling Degree-Days
 
2017
 
2016
 
Normal
 
From 2016
 
From Normal
Heating Degree-Days
 
2,166

 
2,037

 
2,226

 
6.3
%
 
(2.7
)%
Cooling Degree-Days
 
29

 
27

 
11

 
7.4
%
 
163.6
 %
 
 
 
 
 
 
 
 
 
 
 

Twelve Months Ended December 31, 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
 
26,292

 
27,790

 
(5.4
)%
 
(0.9
)%
 
$
2,746

$
$
2,597

 
5.7
 %
Small Commercial & Industrial
 
31,332

 
31,975

 
(2.0
)%
 
(0.7
)%
 
1,376

 
1,316

 
4.6
 %
Large Commercial & Industrial
 
27,467

 
27,842

 
(1.3
)%
 
(0.5
)%
 
461

 
462

 
(0.2
)%
Public Authorities & Electric Railroads
 
1,286

 
1,298

 
(0.9
)%
 
(0.3
)%
 
44

 
45

 
(2.2
)%
Total Retail
 
86,377

 
88,905

 
(2.8
)%
 
(0.7
)%
 
4,627

 
4,420

 
4.7
 %
Other Revenue (b)
 
 
 
 
 
 
 
 
 
909

 
834

 
9.0
 %
Total Electric Revenue (c)
 
 
 
 
 
 
 
 
 
$
5,536

 
$
5,254

 
5.4
 %
Purchased Power
 
 
 
 
 
 
 
 
 
$
1,641

 
$
1,458

 
12.6
 %
 
 
 
 
 
 
 
 
% Change
Heating and Cooling Degree-Days
 
2017
 
2016
 
Normal
 
From 2016
 
From Normal
Heating Degree-Days
 
5,435

 
5,715

 
6,198

 
(4.9
)%
 
(12.3
)%
Cooling Degree-Days
 
991

 
1,157

 
893

 
(14.3
)%
 
11.0
 %
Number of Electric Customers
 
2017
 
2016
Residential
 
3,624,372

 
3,595,376

Small Commercial & Industrial
 
378,345

 
374,644

Large Commercial & Industrial
 
1,959

 
2,007

Public Authorities & Electric Railroads
 
4,775

 
4,750

Total
 
4,009,451

 
3,976,777

(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 $3 million for the three months ended December 31, 2017 and 2016, respectively, and $15 million and $15 million for the twelve months ended December 31, 2017 and 2016, respectively.






29



EXELON CORPORATION
PECO Statistics
Three Months Ended December 31, 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
 
3,084

 
2,982

 
3.4
 %
 
(3.3
)%
 
$
358

 
$
353

 
1.4
%
Small Commercial & Industrial
 
1,921

 
1,863

 
3.1
 %
 
(1.2
)%
 
98

 
96

 
2.1
%
Large Commercial & Industrial
 
3,833

 
3,665

 
4.6
 %
 
3.4
 %
 
55

 
52

 
5.8
%
Public Authorities & Electric Railroads
 
190

 
218

 
(12.8
)%
 
(12.8
)%
 
7

 
7

 
%
Total Retail
 
9,028

 
8,728

 
3.4
 %
 
(0.3
)%
 
518

 
508

 
2.0
%
Other Revenue (b)
 
 
 
 
 
 
 
 
 
55

 
52

 
5.8
%
Total Electric Revenue (d)
 
 
 
 
 
 
 
 
 
573

 
560

 
2.3
%
Natural Gas (in mmcfs)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Retail Deliveries and Sales
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Retail Sales (c)
 
19,632

 
17,959

 
9.3
 %
 
(2.0
)%
 
147

 
132

 
11.4
%
Transportation and Other
 
7,260

 
6,713

 
8.1
 %
 
8.7
 %
 
9

 
9

 
%
Total Natural Gas (d)
 
26,892

 
24,672

 
9.0
 %
 
2.1
 %
 
156

 
141

 
10.6
%
Total Electric and Natural Gas Revenues
 
 
 
 
 
$
729

 
$
701

 
4.0
%
Purchased Power and Fuel
 
 
 
 
 
 
 
 
 
$
250

 
$
238

 
5.0
%
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
% Change
Heating and Cooling Degree-Days
 
2017
 
2016
 
Normal
 
From 2016
 
From Normal
Heating Degree-Days
 
1,512

 
1,425

 
1,629

 
6.1
%
 
(7.2
)%
Cooling Degree-Days
 
86

 
42

 
19

 
104.8
%
 
352.6
 %
 
 
 
 
 
 
 
 
 
 
 

Twelve Months Ended December 31, 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
 
13,024

 
13,664

 
(4.7
)%
 
(1.8
)%
 
$
1,505

 
$
1,631

 
(7.7
)%
Small Commercial & Industrial
 
7,968

 
8,099

 
(1.6
)%
 
(1.1
)%
 
401

 
430

 
(6.7
)%
Large Commercial & Industrial
 
15,426

 
15,263

 
1.1
 %
 
1.4
 %
 
223

 
234

 
(4.7
)%
Public Authorities & Electric Railroads
 
809

 
890

 
(9.1
)%
 
(9.1
)%
 
30

 
32

 
(6.3
)%
Total Retail
 
37,227

 
37,916

 
(1.8
)%
 
(0.5
)%
 
2,159

 
2,327

 
(7.2
)%
Other Revenue (b)
 
 
 
 
 
 
 
 
 
216

 
204

 
5.9
 %
Total Electric Revenue (d)
 
 
 
 
 
 
 
 
 
2,375

 
2,531

 
(6.2
)%
Natural Gas (in mmcfs)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Retail Deliveries and Sales
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Retail Sales (c)
 
58,457

 
56,447

 
3.6
 %
 
1.2
 %
 
462

 
430

 
7.4
 %
Transportation and Other
 
26,382

 
27,630

 
(4.5
)%
 
(2.3
)%
 
33

 
33

 
 %
Total Natural Gas (d)
 
84,839

 
84,077

 
0.9
 %
 
0.1
 %
 
495

 
463

 
6.9
 %
Total Electric and Natural Gas Revenues
 
 
 
 
 
$
2,870

 
$
2,994

 
(4.1
)%
Purchased Power and Fuel
 
 
 
 
 
 
 
 
 
$
969

 
$
1,047

 
(7.4
)%
 
 
 
 
 
 
 
 
% Change
Heating and Cooling Degree-Days
 
2017
 
2016
 
Normal
 
From 2016
 
From Normal
Heating Degree-Days
 
3,949

 
4,041

 
4,603

 
(2.3
)%
 
(14.2
)%
Cooling Degree-Days
 
1,490

 
1,726

 
1,290

 
(13.7
)%
 
15.5
 %






30



Number of Electric Customers
 
2017
 
2016
 
Number of Natural Gas Customers
 
2017
 
2016
Residential
 
1,469,916

 
1,456,585

 
Residential
 
477,213

 
472,606

Small Commercial & Industrial
 
151,552

 
150,142

 
Commercial & Industrial
 
43,892

 
43,668

Large Commercial & Industrial
 
3,112

 
3,096

 
Total Retail
 
521,105

 
516,274

Public Authorities & Electric Railroads
 
9,569

 
9,823

 
Transportation
 
771

 
790

Total
 
1,634,149

 
1,619,646

 
Total
 
521,876

 
517,064

(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 $2 million for both three months ended December 31, 2017 and 2016, respectively, and $6 million and $7 million for the twelve months ended December 31, 2017 and 2016, respectively.  Total natural gas revenue includes operating revenues from affiliates totaling less than $1 million for both three months ended December 31, 2017 and 2016 and $1 million for both twelve months ended December 31, 2017 and 2016.







31



EXELON CORPORATION
BGE Statistics
Three Months Ended December 31, 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
 
2,968

 
2,744

 
8.2
 %
 
1.4
 %
 
$
333

 
$
350

 
(4.9
)%
Small Commercial & Industrial
 
711

 
697

 
2.0
 %
 
0.5
 %
 
64

 
65

 
(1.5
)%
Large Commercial & Industrial
 
3,267

 
3,330

 
(1.9
)%
 
(0.9
)%
 
106

 
112

 
(5.4
)%
Public Authorities & Electric Railroads
 
64

 
67

 
(4.5
)%
 
(4.6
)%
 
8

 
9

 
(11.1
)%
Total Retail
 
7,010

 
6,838

 
2.5
 %
 
0.1
 %
 
511

 
536

 
(4.7
)%
Other Revenue (b)(c)
 
 
 
 
 
 
 
 
 
83

 
75

 
10.7
 %
Total Electric Revenue
 
 
 
 
 
 
 
 
 
594

 
611

 
(2.8
)%
Natural Gas (in mmcfs)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Retail Deliveries and Sales (d)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Retail Sales
 
28,717

 
27,394

 
4.8
 %
 
(1.4
)%
 
210

 
190

 
10.5
 %
Transportation and Other (e)
 
1,152

 
1,898

 
(39.3
)%
 
n/a

 
9

 
11

 
(18.2
)%
Total Natural Gas (f)
 
29,869

 
29,292

 
2.0
 %
 
(1.4
)%
 
219

 
201

 
9.0
 %
Total Electric and Natural Gas Revenues
 
 
 
 
 
$
813

 
$
812

 
0.1
 %
Purchased Power and Fuel
 
 
 
 
 
 
 
 
 
$
280

 
$
300

 
(6.7
)%
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
% Change
Heating and Cooling Degree-Days
 
2017
 
2016
 
Normal
 
From 2016
 
From Normal
Heating Degree-Days
 
1,666

 
1,549

 
1,674

 
7.6
%
 
(0.5
)%
Cooling Degree-Days
 
63

 
32

 
25

 
96.9
%
 
152.0
 %
 
 
 
 
 
 
 
 
 
 
 

Twelve Months Ended December 31, 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
 
12,094

 
12,740

 
(5.1
)%
 
(2.8
)%
 
$
1,428

$
$
1,554

 
(8.1
)%
Small Commercial & Industrial
 
2,921

 
3,040

 
(3.9
)%
 
(4.9
)%
 
266

 
277

 
(4.0
)%
Large Commercial & Industrial
 
13,688

 
13,957

 
(1.9
)%
 
(2.4
)%
 
450

 
449

 
0.2
 %
Public Authorities & Electric Railroads
 
268

 
283

 
(5.3
)%
 
(3.0
)%
 
31

 
35

 
(11.4
)%
Total Retail
 
28,971

 
30,020

 
(3.5
)%
 
(2.8
)%
 
2,175

 
2,315

 
(6.0
)%
Other Revenue (b)(c)
 
 
 
 
 
 
 
 
 
314

 
294

 
6.8
 %
Total Electric Revenue
 
 
 
 
 
 
 
 
 
2,489

 
2,609

 
(4.6
)%
Natural Gas (in mmcfs)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Retail Deliveries and Sales (d)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Retail Sales
 
89,337

 
96,808

 
(7.7
)%
 
(4.2
)%
 
655

$
593

 
10.5
 %
Transportation and Other (e)
 
3,615

 
5,977

 
(39.5
)%
 
n/a

 
32

 
31

 
3.2
 %
Total Natural Gas (f)
 
92,952

 
102,785

 
(9.6
)%
 
(4.2
)%
 
687

 
624

 
10.1
 %
Total Electric and Natural Gas Revenues
 
 
 
 
 
$
3,176

 
$
3,233

 
(1.8
)%
Purchased Power and Fuel
 
 
 
 
 
 
 
 
 
$
1,133

 
$
1,294

 
(12.4
)%
 
 
 
 
 
 
 
 
% Change
Heating and Cooling Degree-Days
 
2017
 
2016
 
Normal
 
From 2016
 
From Normal
Heating Degree-Days
 
4,190

 
4,427

 
4,666

 
(5.4
)%
 
(10.2
)%
Cooling Degree-Days
 
940

 
998

 
875

 
(5.8
)%
 
7.4
 %
Number of Electric Customers
 
2017
 
2016
 
Number of Natural Gas Customers
 
2017
 
2016
Residential
 
1,160,783

 
1,150,096

 
Residential
 
629,690

 
623,647

Small Commercial & Industrial
 
113,594

 
113,230

 
Commercial & Industrial
 
44,247

 
44,255

Large Commercial & Industrial
 
12,155

 
12,053

 
Total Retail
 
673,937

 
667,902

Public Authorities & Electric Railroads
 
272

 
280

 
Transportation
 

 

Total
 
1,286,804

 
1,275,659

 
Total
 
673,937

 
667,902

 






32



(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 December 31, 2017 and 2016 and $5 million and $7 million for the twelve months ended December 31, 2017 and 2016, respectively.
(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 1,152 mmcfs ($6 million) and 1,898 mmcfs ($8 million) for the three months ended December 31, 2017 and 2016, respectively, and 3,615 mmcfs ($21 million) and 5,977 mmcfs ($23 million) for the twelve months ended December 31, 2017 and 2016, respectively.
(f)
Includes operating revenues from affiliates totaling $4 million for both the three months ended December 31, 2017 and 2016 and $11 million and $14 million for the twelve months ended December 31, 2017 and 2016, respectively.








33



EXELON CORPORATION
Pepco Statistics
Three Months Ended December 31, 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
 
1,793

1,608,000,000

1,720

 
4.2
 %
 
(1.7
)%
 
$
212

 
$
209

 
1.4
 %
Small Commercial & Industrial
 
304

321,000,000

335

 
(9.3
)%
 
(11.2
)%
 
34

 
34

 
 %
Large Commercial & Industrial
 
3,682

3,592,000,000

3,669

 
0.4
 %
 
(0.9
)%
 
202

 
190

 
6.3
 %
Public Authorities & Electric Railroads
 
192

174,000,000

180

 
6.7
 %
 
6.1
 %
 
9

 
9

 
 %
Total Retail
 
5,971

 
5,904

 
1.1
 %
 
(1.6
)%
 
457

 
442

 
3.4
 %
Other Revenue (b)
 
 
 
 
 
 
 
 
 
52

 
49

 
6.1
 %
Total Electric Revenue (c)
 
 
 
 
 
 
 
 
 
509

 
491

 
3.7
 %
Purchased Power
 
 
 
 
 
 
 
 
 
$
137

 
$
143

 
(4.2
)%
 
 
 
 
 
 
 
 
% Change
Heating and Cooling Degree-Days
 
2017
 
2016
 
Normal
 
From 2016
 
From Normal
Heating Degree-Days
 
1,350

 
1,217

 
1,392

 
10.9
%
 
(3.0
)%
Cooling Degree-Days
 
88

 
64

 
42

 
37.5
%
 
109.5
 %

Twelve Months Ended December 31, 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
 
7,831

8,452,000,000

8,372

 
(6.5
)%
 
(2.5
)%
 
$
956

 
$
1,000

 
(4.4
)%
Small Commercial & Industrial
 
1,303

1,471,000,000

1,459

 
(10.7
)%
 
(9.0
)%
 
147

 
150

 
(2.0
)%
Large Commercial & Industrial
 
14,988

15,351,000,000

15,559

 
(3.7
)%
 
(2.5
)%
 
810

 
803

 
0.9
 %
Public Authorities & Electric Railroads
 
734

714,000,000

724

 
1.4
 %
 
1.4
 %
 
33

 
32

 
3.1
 %
Total Retail
 
24,856

 
26,114

 
(4.8
)%
 
(2.8
)%
 
1,946

 
1,985

 
(2.0
)%
Other Revenue (b)
 
 
 
 
 
 
 
 
 
212

 
201

 
5.5
 %
Total Electric Revenue (c)
 
 
 
 
 
 
 
 
 
2,158

 
2,186

 
(1.3
)%
Purchased Power
 
 
 
 
 
 
 
 
 
$
614

 
$
706

 
(13.0
)%
 
 
 
 
 
 
 
 
% Change
Heating and Cooling Degree-Days
 
2017
 
2016
 
Normal
 
From 2016
 
From Normal
Heating Degree-Days
 
3,312

 
3,624

 
3,869

 
(8.6
)%
 
(14.4
)%
Cooling Degree-Days
 
1,767

 
1,936

 
1,653

 
(8.7
)%
 
6.9
 %
Number of Electric Customers
 
2017
 
2016
Residential
 
792,211

 
780,652

Small Commercial & Industrial
 
53,489

 
53,529

Large Commercial & Industrial
 
21,732

 
21,391

Public Authorities & Electric Railroads
 
144

 
130

Total
 
867,576

 
855,702

 
(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 $2 million and $1 million for the three months ended December 31, 2017 and 2016, respectively, and $6 million and $5 million for the twelve months ended December 31, 2017 and 2016, respectively.








34



EXELON CORPORATION
DPL Statistics
Three Months Ended December 31, 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
 
1,167

 
1,115

 
4.7
 %
 
(1.2
)%
 
$
154

 
$
147

 
4.8
 %
Small Commercial & Industrial
 
544

 
544

 
 %
 
(1.8
)%
 
47

 
45

 
4.4
 %
Large Commercial & Industrial
 
1,145

 
1,131

 
1.2
 %
 
0.2
 %
 
24

 
24

 
 %
Public Authorities & Electric Railroads
 
9

 
12

 
(25.0
)%
 
(18.2
)%
 
3

 
3

 
 %
Total Retail
 
2,865

 
2,802

 
2.2
 %
 
(0.8
)%
 
228

 
219

 
4.1
 %
Other Revenue (b)
 
 
 
 
 
 
 
 
 
46

 
38

 
21.1
 %
Total Electric Revenue (c)
 
 
 
 
 
 
 
 
 
274

 
257

 
6.6
 %
Natural Gas (in mmcfs)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Retail Deliveries and Sales (d)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Retail Sales
 
4,428

 
4,086

 
8.4
 %
 
2.3
 %
 
49

 
40

 
22.5
 %
Transportation and Other (e)
 
1,848

 
1,748

 
5.7
 %
 
4.2
 %
 
7

 
6

 
16.7
 %
Total Natural Gas
 
6,276

 
5,834

 
7.6
 %
 
2.8
 %
 
56

 
46

 
21.7
 %
Total Electric and Natural Gas Revenues
 
 
 
 
 
$
330

 
$
303

 
8.9
 %
Purchased Power and Fuel
 
 
 
 
 
 
 
 
 
$
133

 
$
135

 
(1.5
)%
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Electric Service Territory
 
 
 
 
 
 
 
% Change
Heating and Cooling Degree-Days
 
2017
 
2016
 
Normal
 
From 2016
 
From Normal
Heating Degree-Days
 
1,601

 
1,507

 
1,586

 
6.2
%
 
0.9
%
Cooling Degree-Days
 
72

 
43

 
26

 
67.4
%
 
176.9
%
Gas Service Territory
 
 
 
 
 
 
 
% Change
Heating Degree-Days
 
2017
 
2016
 
Normal
 
From 2016
 
From Normal
Heating Degree-Days
 
1,632

 
1,542

 
1,677

 
5.8
%
 
(2.7
)%

Twelve Months Ended December 31, 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
 
5,010

 
5,181

 
(3.3
)%
 
(0.3
)%
 
$
660

 
$
668

 
(1.2
)%
Small Commercial & Industrial
 
2,237

 
2,290

 
(2.3
)%
 
(0.9
)%
 
185

 
187

 
(1.1
)%
Large Commercial & Industrial
 
4,585

 
4,623

 
(0.8
)%
 
0.3
 %
 
102

 
98

 
4.1
 %
Public Authorities & Electric Railroads
 
44

 
46

 
(4.3
)%
 
(8.3
)%
 
14

 
13

 
7.7
 %
Total Retail
 
11,876

 
12,140

 
(2.2
)%
 
(0.2
)%
 
961

 
966

 
(0.5
)%
Other Revenue (b)
 
 
 
 
 
 
 
 
 
178

 
163

 
9.2
 %
Total Electric Revenue (c)
 
 
 
 
 
 
 
 
 
1,139

 
1,129

 
0.9
 %
Natural Gas (in mmcfs)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Retail Deliveries and Sales (d)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Retail Sales
 
13,107

 
13,341

 
(1.8
)%
 
5.2
 %
 
136

 
127

 
7.1
 %
Transportation and Other (e)
 
6,538


6,201

 
5.4
 %
 
6.9
 %
 
25

 
21

 
19.0
 %
Total Natural Gas
 
19,645

 
19,542

 
0.5
 %
 
5.7
 %
 
161

 
148

 
8.8
 %
Total Electric and Natural Gas Revenues
 
 
 
 
 
$
1,300

 
$
1,277

 
1.8
 %
Purchased Power and Fuel
 
 
 
 
 
 
 
 
 
$
532

 
$
583

 
(8.7
)%
Electric Service Territory
 
 
 
 
 
 
 
% Change
Heating and Cooling Degree-Days
 
2017
 
2016
 
Normal
 
From 2016
 
From Normal
Heating Degree-Days
 
4,077

 
4,319

 
4,519

 
(5.6
)%
 
(9.8
)%
Cooling Degree-Days
 
1,300

 
1,453

 
1,210

 
(10.5
)%
 
7.4
 %
Gas Service Territory
 
 
 
 
 
 
 
% Change
Heating Degree-Days
 
2017
 
2016
 
Normal
 
From 2016
 
From Normal
Heating Degree-Days
 
4,203

 
4,454

 
4,739

 
(5.6
)%
 
(11.3
)%






35



Number of Electric Customers
 
2017
 
2016
 
Number of Natural Gas Customers
 
2017
 
2016
Residential
 
459,389

 
456,181

 
Residential
 
122,347

 
120,951

Small Commercial & Industrial
 
60,697

 
60,173

 
Commercial & Industrial
 
9,853

 
9,801

Large Commercial & Industrial
 
1,400

 
1,411

 
Total Retail
 
132,200

 
130,752

Public Authorities & Electric Railroads
 
629

 
643

 
Transportation
 
154

 
156

Total
 
522,115

 
518,408

 
Total
 
132,354

 
130,908

 
(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 $1 million for the three months ended December 31, 2017 and 2016, respectively, and $8 million and $7 million for the twelve months ended December 31, 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.







36



EXELON CORPORATION
ACE Statistics
Three Months Ended December 31, 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
 
811

 
826

 
(1.8
)%
 
(6.9
)%
 
$
136

 
$
134

 
1.5
 %
Small Commercial & Industrial
 
294

 
457

 
(35.7
)%
 
(36.9
)%
 
37

 
50

 
(26.0
)%
Large Commercial & Industrial
 
842

 
697

 
20.8
 %
 
19.5
 %
 
46

 
43

 
7.0
 %
Public Authorities & Electric Railroads
 
14

 
14

 
 %
 
 %
 
3

 
3

 
 %
Total Retail
 
1,961

 
1,994

 
(1.7
)%
 
(4.5
)%
 
222

 
230

 
(3.5
)%
Other Revenue (b)
 
 
 
 
 
 
 
 
 
50

 
45

 
11.1
 %
Total Electric Revenue (c)
 
 
 
 
 
 
 
 
 
272

 
275

 
(1.1
)%
Purchased Power
 
 
 
 
 
 
 
 
 
$
128

155,000,000

$
133

 
(3.8
)%
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
% Change
Heating and Cooling Degree-Days
 
2017
 
2016
 
Normal
 
From 2016
 
From Normal
Heating Degree-Days
 
1,598

 
1,549

 
1,611

 
3.2
%
 
(0.8
)%
Cooling Degree-Days
 
75

 
36

 
23

 
108.3
%
 
226.1
 %

Twelve Months Ended December 31, 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
 
3,853

 
4,153

 
(7.2
)%
 
(6.2
)%
 
$
619

 
$
664

 
(6.8
)%
Small Commercial & Industrial
 
1,286

 
1,455

 
(11.6
)%
 
(11.1
)%
 
166

 
183

 
(9.3
)%
Large Commercial & Industrial
 
3,399

 
3,402

 
(0.1
)%
 
0.4
 %
 
189

 
201

 
(6.0
)%
Public Authorities & Electric Railroads
 
47

 
49

 
(4.1
)%
 
(4.1
)%
 
13

 
13

 
 %
Total Retail
 
8,585

 
9,059

 
(5.2
)%
 
(4.5
)%
 
987

 
1,061

 
(7.0
)%
Other Revenue (b)
 
 
 
 
 
 
 
 
 
199

 
196

 
1.5
 %
Total Electric Revenue (c)
 
 
 
 
 
 
 
 
 
1,186

 
1,257

 
(5.6
)%
Purchased Power
 
 
 
 
 
 
 
 
 
$
570

 
$
651

 
(12.4
)%
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
% Change
Heating and Cooling Degree-Days
 
2017
 
2016
 
Normal
 
From 2016
 
From Normal
Heating Degree-Days
 
4,206

 
4,487

 
4,713

 
(6.3
)%
 
(10.8
)%
Cooling Degree-Days
 
1,228

 
1,303

 
1,115

 
(5.8
)%
 
10.1
 %
Number of Electric Customers
 
2017
 
2016
Residential
 
487,168

 
484,240

Small Commercial & Industrial
 
61,013

 
61,008

Large Commercial & Industrial
 
3,684

 
3,763

Public Authorities & Electric Railroads
 
636

 
610

Total
 
552,501

 
549,621

 
(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 $1 million and $1 million for the three months ended December 31, 2017 and 2016, respectively, and $2 million and $3 million for the twelve months ended December 31, 2017 and 2016, respectively.








37