Market Overview

Exelon Reports Second Quarter 2018 Results

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Earnings Release Highlights

  • GAAP Net Income of $0.56 per share and Adjusted (non-GAAP) Operating
    Earnings of $0.71 per share for the second quarter of 2018
  • Reaffirming full year 2018 Adjusted Operating Earnings guidance of
    $2.90 to $3.20 per share
  • Strong utility operations with every utility achieving top decile
    CAIDI performance
  • Legislation passed in Pennsylvania and Delaware will support
    investment in the Utility of the Future
  • Customer savings from the Tax Cuts & Jobs Act (TCJA) are now projected
    to exceed $675 million annually across Exelon's electric and gas
    distribution and transmission customers
  • New Jersey zero emissions certificate (ZEC) legislation signed by Gov.
    Phil Murphy on May 23, 2018

Exelon Corporation (NYSE:EXC) today reported its financial results for
the second quarter of 2018.

This press release features multimedia. View the full release here:
https://www.businesswire.com/news/home/20180802005359/en/

Exelon second-quarter highlights (Graphic: Business Wire)

Exelon second-quarter highlights (Graphic: Business Wire)

"Exelon's utility and power businesses performed well operationally and
financially in the second quarter. Our strategy to accelerate investment
in advanced technology and infrastructure to improve customer service
gained momentum as lawmakers in Pennsylvania and Delaware passed
legislation that will support our initiatives to create the utility of
the future," said Christopher M. Crane, Exelon's President and CEO. "In
May, New Jersey Gov. Phil Murphy signed legislation creating a zero
emissions certificate program that will preserve the state's
emissions-free nuclear power plants and the economic and environmental
benefits they provide. Our commitment to the communities we serve
remains a core value, with our employees setting a new company record by
volunteering more than 18,000 hours in 104 cities across the U.S. as
part of National Volunteer Month."

"Exelon again delivered solid financial results with non-GAAP operating
earnings of $0.71 per share, which is above our guidance range of
$0.55-$0.65 per share," said Joseph Nigro, Exelon's Senior Executive
Vice President and CFO. "As we look ahead to the rest of the year, we
are on solid footing and will continue to focus on delivering strong
operational and financial results for our stakeholders. Exelon remains
on track to meet our full-year guidance of $2.90-$3.20 per share and
expects to earn $0.80-$0.90 per share in the third quarter."

Second Quarter 2018

Exelon's GAAP Net Income for the second quarter of 2018 increased to
$0.56 per share from $0.10 per share in the second quarter of 2017;
Adjusted (non-GAAP) Operating Earnings increased to $0.71 per share in
the second quarter of 2018 from $0.56 per share in the second quarter of
2017. For the reconciliations of GAAP Net Income to Adjusted (non-GAAP)
Operating Earnings, refer to the tables beginning on page 7.

Adjusted (non-GAAP) Operating Earnings in the second quarter of 2018
primarily reflect higher electric distribution earnings at ComEd,
regulatory rate increases at PHI, decreased nuclear outage days,
increased capacity prices, the favorable impacts of the Illinois Zero
Emission Standard (ZES), realized gains on nuclear decommissioning trust
fund investments and tax savings related to the TCJA at Generation,
partially offset by lower realized energy prices at Generation.

Operating Company Results1

ComEd

ComEd's second quarter of 2018 GAAP Net Income increased to $164 million
from $118 million in the second quarter of 2017. ComEd's Adjusted
(non-GAAP) Operating Earnings increased to $164 million for the second
quarter of 2018 from $141 million in the second quarter of 2017,
primarily reflecting higher electric distribution earnings. Due to
revenue decoupling, ComEd's distribution earnings are not affected by
actual weather or customer usage patterns.

PECO

PECO's second quarter of 2018 GAAP Net Income increased to $96 million
from $88 million in the second quarter of 2017. PECO's Adjusted
(non-GAAP) Operating Earnings for the second quarter of 2018 increased
to $97 million from $89 million in the second quarter of 2017, primarily
due to favorable weather conditions and volumes.

Heating degree days were up 46.5 percent relative to the same period in
2017 and were 9.3 percent above normal. Total retail electric deliveries
were up 1.4 percent compared with the second quarter of 2017. Natural
gas deliveries (including both retail and transportation segments) in
the second quarter of 2018 were up 15.7 percent compared with the same
period in 2017.

BGE

BGE's second quarter of 2018 GAAP Net Income increased to $51 million
from $45 million in the second quarter of 2017. BGE's Adjusted
(non-GAAP) Operating Earnings for the second quarter of 2018 increased
to $52 million from $46 million in the second quarter of 2017, primarily
reflecting transmission rate increases. Due to revenue decoupling, BGE's
distribution earnings are not affected by actual weather or customer
usage patterns.

______________

1Exelon's five business units include ComEd, which consists
of electricity transmission and distribution operations in northern
Illinois; PECO, which consists of electricity transmission and
distribution operations and retail natural gas distribution operations
in southeastern Pennsylvania; BGE, which consists of electricity
transmission and distribution operations and retail natural gas
distribution operations in central Maryland; PHI, which consists of
electricity transmission and distribution operations in the District of
Columbia and portions of Maryland, Delaware, and New Jersey and retail
natural gas distribution operations in northern Delaware; and
Generation, which consists of owned and contracted electric generating
facilities and wholesale and retail customer supply of electric and
natural gas products and services, including renewable energy products
and risk management services.

PHI

PHI's second quarter of 2018 GAAP Net Income increased to $84 million
from $66 million in the second quarter of 2017. PHI's Adjusted
(non-GAAP) Operating Earnings for the second quarter of 2018 increased
to $86 million from $63 million in the second quarter of 2017, primarily
reflecting regulatory rate increases. Due to revenue decoupling, PHI's
distribution earnings related to Pepco and DPL Maryland are not affected
by actual weather or customer usage patterns.

Generation

Generation's second quarter of 2018 GAAP Net Income increased to $178
million from a Net loss of $235 million in the second quarter of 2017.
Generation's Adjusted (non-GAAP) Operating Earnings for the second
quarter of 2018 increased to $331 million from $217 million in the
second quarter of 2017, primarily reflecting decreased nuclear outage
days, increased capacity prices, the favorable impacts of the Illinois
ZES, realized gains on nuclear decommissioning trust fund investments
and tax savings related to the TCJA, partially offset by lower realized
energy prices.

The proportion of expected generation hedged as of June 30, 2018, was 97
percent to 100 percent for 2018, 71 percent to 74 percent for 2019 and
41 percent to 44 percent for 2020.

Second Quarter and Recent Highlights

  • Tax Cuts and Jobs Act Tax Savings: The Utility Registrants have
    made filings with their respective regulators to begin passing back to
    customers the ongoing annual tax savings resulting from the TCJA. In
    total, the Utility Registrants project total annual savings of over
    $675 million across their electric and gas distribution customers and
    electric transmission customers. There were the following developments
    related to these filings in the second quarter of 2018:
    • Pursuant to a Pennsylvania Public Utility Commission (PAPUC) order
      issued on May 17, 2018, to all Pennsylvania utilities without an
      existing base rate case, PECO began passing back annual tax
      savings of $4 million to its natural gas distribution customers
      through a negative surcharge mechanism beginning July 1, 2018.
    • On May 31, 2018, Pepco received an order from the Maryland Public
      Service Commission (MDPSC) approving a settlement agreement for
      its 2018 electric distribution rate case, which included the
      annual ongoing TCJA tax savings and provides a one-time bill
      credit to customers of approximately $10 million representing the
      TCJA tax savings from January 1, 2018, through the effective date
      of June 1, 2018.
    • On June 27, 2018, DPL entered into a settlement agreement with
      parties in Delaware for its pending electric distribution rate
      case, which includes the annual ongoing TCJA tax savings and
      provides a one-time bill credit to customers of approximately $3
      million representing the TCJA tax savings from February 1, 2018,
      through March 17, 2018, when full interim rates were put into
      effect.
    • ComEd's, PECO's, BGE's, Pepco's, DPL's and ACE's electric
      transmission formula rate updates effective June 1, 2018, reflect
      the annual benefit of lower income tax rates from TCJA of $69
      million, $20 million, $18 million, $13 million, $12 million and
      $11 million, respectively.
  • New Jersey Clean Energy Legislation: On May 23, 2018, Governor
    Murphy of New Jersey signed new legislation, which became effective
    immediately, that will establish a ZEC program providing compensation
    for nuclear plants that demonstrate to the NJBPU that they meet
    certain requirements, including that they make a significant
    contribution to air quality in the state and that their revenues are
    insufficient to cover their costs and risks. Under the new
    legislation, the NJBPU will issue ZECs to qualifying nuclear power
    plants, and the electric distribution utilities in New Jersey,
    including ACE, will be required to purchase those ZECs and will be
    allowed to recover the associated costs from their retail distribution
    customers. The NJBPU has 180 days from the effective date to establish
    procedures for implementation of the ZEC program and 330 days from the
    effective date to determine which nuclear power plants are selected to
    receive ZECs under the program. The quantity of ZECs issued will be
    determined based on the greater of 40 percent of the total number of
    MWh of electricity distributed by the public electric distribution
    utilities in New Jersey in the prior year, or the total number of MWh
    of electricity generated in the prior year by the selected nuclear
    power plants. The ZEC price is approximately $10 per MWh during the
    first 3-year eligibility period. For eligibility periods following the
    first 3-year eligibility period, the NJBPU has discretion to reduce
    the ZEC price. Assuming the successful implementation of the New
    Jersey ZEC program and the selection of Salem as one of the qualifying
    facilities, the New Jersey ZEC program has the potential to mitigate
    the heightened risk of earlier retirement for Salem. On the same day,
    the Governor of New Jersey signed new legislation, which also became
    effective immediately, that establishes and modifies New Jersey's
    clean energy and energy efficiency programs and solar and renewable
    energy portfolio standards.
  • DPL Delaware Electric Distribution Base Rates: On June 27,
    2018, DPL entered into a non- unanimous settlement agreement with the
    majority of the parties in the proceeding related to its pending
    electric distribution base rate case. The settlement agreement
    provides for a net decrease to annual electric distribution base rates
    of $7 million, which includes annual ongoing TCJA tax savings, and
    reflects a ROE of 9.7 percent. A decision is expected on the matter in
    the third quarter of 2018, with a rate refund expected to be issued in
    the fourth quarter of 2018 if the Delaware Public Service Commission
    (DPSC) approves the settlement agreement as filed.
  • BGE Maryland Natural Gas Distribution Base Rates: On June 8,
    2018, BGE filed an application with the MDPSC to increase its annual
    natural gas distribution base rates by $63 million, reflecting a
    requested ROE of 10.5 percent. BGE expects a decision in the first
    quarter of 2019 but cannot predict what increase the MDPSC will
    approve.
  • Delaware Distribution System Investment Charge Legislation: On
    June 14, 2018, Governor Carney of Delaware signed new Distribution
    System Investment Charge (DSIC) legislation, which establishes a
    system improvement charge that provides a mechanism to recover
    infrastructure investments, allowing for gradual rate increases and
    limiting frequency of distribution base rate cases. DPL expects to
    make its first filing in Delaware in the fourth quarter of 2018, with
    the new charge effective in the first quarter of 2019. While this
    legislation is expected to support needed infrastructure investment
    and allow for more timely recovery of those investments, Exelon, PHI
    and DPL cannot predict the potential financial impact on Exelon, PHI
    or DPL.
  • Pennsylvania Alternative Ratemaking Legislation: On June
    28, 2018, Governor Wolf of Pennsylvania signed new legislation, which
    authorized the PAPUC to review and approve utility- proposed
    alternative rate designs, including options such as decoupling
    mechanisms, formula rates, multi-year rate plans, and performance
    based rates. Exelon and PECO cannot predict the outcome or the
    potential financial impact, if any, on Exelon or PECO.
  • PJM Transmission Order: On June 15, 2016, a number of parties,
    including the Utility Registrants, filed a proposed settlement with
    FERC to resolve outstanding issues related to cost responsibility for
    charges to transmission customers for certain transmission facilities
    that operate at or above 500 kV. The settlement included provisions
    for monthly credits or charges related to the periods prior to January
    1, 2016, that are expected to be refunded or recovered through PJM
    wholesale transmission rates through June 2025. On May 31, 2018, FERC
    issued an order approving the settlement. Pursuant to the order,
    similar charges for the period January 1, 2016, through June 30, 2018,
    will also be refunded or recovered through PJM wholesale transmission
    rates over the subsequent 12-month period. PJM will commence billing
    the refunds and charges associated with this settlement in August 2018.

    Pursuant
    to the FERC approval of the settlement in the second quarter of 2018,
    the Utility Registrants recorded gross payables to and receivables
    from PJM of $135 million and $197 million, respectively, which were
    offset by regulatory assets and liabilities, resulting in no earnings
    impact. In addition, Generation recorded a pre-tax charge and payable
    to PJM of $23 million in the second quarter of 2018.
  • FirstEnergy Solutions: On July 9, 2018, Generation entered into
    an agreement to purchase FirstEnergy Solutions Corporation's retail
    electricity and wholesale load serving contracts and certain other
    related commodity contracts for an all cash purchase price of $140
    million. The transaction is expected to close in the fourth quarter of
    2018. The closing of the transaction is subject to certain conditions,
    including Generation being the winning bidder after a court-supervised
    Section 363 bankruptcy auction, the approval of the Purchase Agreement
    by the United States Bankruptcy Court for the Northern District of
    Ohio following the auction, and the expiration or termination of the
    applicable waiting period under the Hart-Scott-Rodino Antitrust
    Improvements Act of 1976. Either party may terminate the Purchase
    Agreement if the transaction has not been consummated by December 31,
    2018.
  • Agreement for Sale and Decommissioning of Oyster Creek: On July
    31, 2018, Generation entered into an agreement with Holtec
    International (Holtec) and its indirect wholly owned subsidiary,
    Oyster Creek Environmental Protection, LLC (OCEP), for the sale and
    decommissioning of Oyster Creek. Generation will transfer to OCEP
    substantially all the assets associated with Oyster Creek, including
    assets held in nuclear decommissioning trust (NDT) funds valued at
    approximately $980 million as of June 30, 2018, along with the
    assumption of liability for all responsibility for the site, including
    full decommissioning and ongoing management of spent fuel until the
    spent fuel is moved offsite. In addition to the assumption of
    liability for the full decommissioning and ongoing management of spent
    fuel, other consideration to be received in the transaction is
    contingent on several factors, including a requirement that Generation
    deliver a minimum NDT fund balance at closing, subject to adjustment
    for specific terms that include income taxes that would be imposed on
    any net unrealized built-in gains and certain decommissioning
    activities to be performed during the pre-close period after the unit
    shuts down in the fall of 2018 and prior to the anticipated close of
    the transaction. Completion of the transaction contemplated by the
    sale agreement is subject to the satisfaction of several closing
    conditions, including approval of the license transfer from the NRC
    and other regulatory approvals, and the receipt of a private letter
    ruling from the IRS. Generation currently anticipates satisfaction of
    the closing conditions to occur in the second half of 2019.
  • Mystic Generating Station Early Retirement: On March 29, 2018,
    Generation announced it had formally notified grid operator ISO-NE of
    its plans to early retire its Mystic Generating Station assets on June
    1, 2022, absent any interim and long-term solutions for reliability
    and regional fuel security. On May 1, 2018, ISO-NE made a filing with
    FERC requesting waiver of certain tariff provisions to allow it to
    retain Mystic units 8 and 9 for fuel security for the 2022 - 2024
    planning years. On May 16, 2018, Generation made a filing with FERC to
    establish cost-of-service compensation and terms and conditions of
    service for Mystic units 8 and 9 for the period between June 1, 2022 -
    May 31, 2024. On July 2, 2018, FERC issued an order denying ISO-NE's
    May 1, 2018, waiver request on procedural grounds but accepting
    ISO-NE's conclusions that retirement of Mystic units 8 and 9 could
    cause a violation of mandatory reliability standards as soon as 2022.
    Accordingly, FERC ordered ISO-NE to (i) make a filing within 60 days
    providing for the filing of a short-term cost-of-service agreement to
    address demonstrated fuel security concerns and (ii) make a filing by
    July 1, 2019, proposing permanent tariff revisions that would improve
    its market design to better address regional fuel security concerns.
    FERC also extended the deadline by which Generation must make a
    retirement decision for Mystic units 8 and 9 to January 4, 2019. On
    July 13, 2018, FERC issued an order accepting the cost-of-service
    agreement for filing, making findings on certain issues and
    establishing hearing procedures on an expedited schedule. Exelon and
    Generation cannot predict the final outcome of these proceedings or
    the potential financial impact, if any, on Exelon or Generation.
  • Nuclear Operations: Generation's nuclear fleet, including its
    owned output from the Salem Generating Station and 100 percent of the
    CENG units, produced 45,723 gigawatt-hours (GWhs) in the second
    quarter of 2018, compared with 44,065 GWhs in the second quarter of
    2017. Excluding Salem, the Exelon-operated nuclear plants at ownership
    achieved a 93.2 percent capacity factor for the second quarter of
    2018, compared with 90.9 percent for the second quarter of 2017. The
    number of planned refueling outage days in the second quarter of 2018
    totaled 94, compared with 125 in the second quarter of 2017. There
    were 2 non-refueling outage days in the second quarter of 2018,
    compared with 12 in the second quarter of 2017.
  • Fossil and Renewables Operations: The Dispatch Match rate for
    Generation's gas and hydro fleet was 97.8 percent in the second
    quarter of 2018, compared with 99.0 percent in the second quarter of
    2017. The lower performance in the quarter was primarily due to
    outages at gas cycle units in Massachusetts and Texas.

    Energy
    Capture for the wind and solar fleet was 95.1 percent in the second
    quarter of 2018, compared with 95.5 percent in the second quarter of
    2017. The lower performance in the quarter was driven by equipment
    issues at wind farms in Texas.
  • Financing Activities:
    • On May 23, 2018, ACE entered into two term loan agreements in the
      aggregate amount of $125 million, which expire on May 22, 2019.
      Pursuant to the term loan agreements, loans made thereunder bear
      interest at a variable rate equal to LIBOR plus 0.55 percent and
      all indebtedness thereunder is unsecured.
    • On June 21, 2018, Pepco issued $100 million aggregate principal
      amount of its First Mortgage Bonds, 4.27 percent due June 15,
      2048. Pepco used the proceeds to repay existing indebtedness and
      for general corporate purposes.
    • On June 21, 2018, DPL issued $200 million in aggregate principal
      amount of its First Mortgage Bonds, 4.27 percent due June 15,
      2048. DPL used the proceeds to repay indebtedness and for general
      corporate purposes.

GAAP/Adjusted (non-GAAP) Operating Earnings Reconciliation

Adjusted (non-GAAP) Operating Earnings for the second quarter of 2018 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

2018 GAAP Net Income

$

0.56

$

539

$

164

$ 96   $ 51   $ 84   $ 178

Mark-to-Market Impact of Economic Hedging Activities (net of taxes
of $23)

(0.07

)

(67

)

(67

)

Unrealized Losses Related to Nuclear Decommissioning Trust (NDT)
Fund Investments (net of taxes of $77)

0.08

81

 

 

81

Merger and Integration Costs (net of taxes of $0)

1

1

Long-Lived Asset Impairments (net of taxes of $11)

0.03

30

30

Plant Retirements and Divestitures (net of taxes of $47)

0.14

127

127

Cost Management Program (net of taxes of $4, $0, $0, $0 and $4,
respectively)

0.01 12 1 1 1 9
Change in Environmental Liabilities (net of taxes of $2)

0.01

5

5

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

(0.01 ) (8 ) 1 1

Noncontrolling Interests (net of taxes of $7)

   

(0.04

)

(34

)

 

   

   

   

   

(34

)

2018 Adjusted (non-GAAP) Operating Earnings

$

0.71

$

686

$

164

$

97

$

52

$

86

$

331

 

Adjusted (non-GAAP) Operating Earnings for the second 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 Income1

$

      0.10

 

$

      95

 

$

    118

 

$

      88

 

$

      45

 

$

      66

 

$

          (235

)

Mark-to-Market Impact of Economic Hedging Activities (net of taxes
of $72 and $71, respectively)

0.12

113

114

 

Unrealized Gains Related to NDT Fund Investments (net of taxes of
$20)

(0.05

)

(45

)

(45

)

Amortization of Commodity Contract Intangibles (net of taxes of $8)

0.01

12

12

Merger and Integrations Costs (net of taxes of $9, $1 and $7,
respectively)

0.02

15

1

12

Merger Commitments (net of taxes of $3)

(4

)

Long-Lived Asset Impairments (net of taxes of $172 and $171,
respectively)

0.29

268

269

Plant Retirements and Divestitures (net of taxes of $42)

0.07

66

66

Cost Management Program (net of taxes of $4, $1, $1 and $3,
respectively)

0.01

6

1

1

4

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

(0.03

)

(26

)

23

Noncontrolling Interests (net of taxes of $5)

   

0.02

     

20

     

   

   

   

     

20

 

2017 Adjusted (non-GAAP) Operating Earnings

 

$

0.56

   

$

524

   

$

141

 

$

89

 

$

46

 

$

63

   

$

217

 
 

(1) Certain immaterial prior year amounts in the Registrants'
Consolidated Statements of Operations and Comprehensive Income
have been recasted to reflect new accounting standards issued by
the FASB and adopted as of January 1, 2018.

 

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 for 2018 and 2017
ranged from 26.0 percent to 29.0 percent and 39.0 percent to 41.0
percent, respectively. Under IRS regulations, NDT fund investment
returns are taxed at different rates for investments if they are in
qualified or non-qualified funds. The effective tax rates for the
unrealized gains and losses related to NDT fund investments were 48.9
percent and 31.4 percent for the three months ended June 30, 2018 and
2017, respectively.

Webcast Information

Exelon will discuss second quarter 2018 earnings in a one-hour
conference call scheduled for today at 9 a.m. Central Time (10 a.m.
Eastern Time). The webcast and associated materials can be accessed at www.exeloncorp.com/investor-relations.

About Exelon

Exelon Corporation (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 10 million customers in Delaware, the District of
Columbia, Illinois, Maryland, New Jersey and Pennsylvania through its
Atlantic City Electric, BGE, ComEd, Delmarva Power, PECO and Pepco
subsidiaries. Exelon is one of the largest competitive U.S. power
generators, with more than 32,700 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 August 2, 2018.

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 the Registrants include those factors discussed herein, as well
as the items discussed in (1) the Registrants' 2017 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 23,
Commitments and Contingencies; (2) the Registrants' Second Quarter 2018
Quarterly Report on Form 10-Q (to be filed on August 2, 2018) 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 17, 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.

 

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
June 30, 2018

 

Three Months Ended
June 30, 2017 (a)

GAAP (b)  

Non-GAAP
Adjustments

  GAAP (b)  

Non-GAAP
Adjustments

 
Operating revenues $ 8,076 $ 5 (c) $ 7,665 $ 158 (c),(e)
Operating expenses
Purchased power and fuel 3,315 76 (c),(i) 3,086 (48 ) (c),(e)
Operating and maintenance 2,307 (68 ) (f),(h),(i),(j),(k) 2,945 (524 ) (f),(g),(h),(i),(j)
Depreciation and amortization 1,088 (152 ) (i) 915 (35 ) (i)
Taxes other than income 428     420  
Total operating expenses 7,138 7,366
Gain on sales of assets and businesses 4   (1 ) (i) 1  
Operating income 942   300  
Other income and (deductions)
Interest expense, net (373 ) (436 ) 63 (h),(m)
Other, net 44   158 (d) 177   (66 ) (d),(m)
Total other income and (deductions) (329 ) (259 )
Income before income taxes 613 41
Income taxes 66 126 (c),(d),(h),(i),(j),(k),(l) (62 ) 353 (c),(d),(e),(f),(g),(h),(i),(j),(m)
Equity in losses of unconsolidated affiliates (5 ) (9 )
Net income 542 94
Net income (loss) attributable to noncontrolling interests 3   33 (n) (1 ) (20 ) (n)
Net income attributable to common shareholders $ 539   $ 95  
Effective tax rate(o) 10.8 % (151.2 )%
Earnings per average common share
Basic $ 0.56 $ 0.10
Diluted $ 0.56   $ 0.10  
Average common shares outstanding
Basic 967 934
Diluted 969 936
Effect of adjustments on earnings per average diluted common
share recorded in accordance with GAAP:
Mark-to-market impact of economic hedging activities (c) $ (0.07 ) $ 0.12
Unrealized gains (losses) related to NDT fund investments (d) 0.08 (0.05 )

Amortization of commodity contract intangibles (e)

0.01
Merger and integration costs (f) 0.02
Merger commitments (g)
Long-lived asset impairments (h) 0.03 0.29
Plant retirements and divestitures (i) 0.14 0.07
Cost management program (j) 0.01 0.01
Change in environmental liabilities (k) 0.01
Reassessment of deferred income taxes (l) (0.01 )
Like-kind exchange tax position (m) (0.03 )
Noncontrolling interests (n) (0.04 ) 0.02  
Total adjustments $ 0.15   $ 0.46  
 
(a)   Certain immaterial prior year amounts in the Registrants'
Consolidated Statements of Operations and Comprehensive Income have
been recasted to reflect new accounting standards issued by the FASB
and adopted as of January 1, 2018.
(b) Results reported in accordance with accounting principles generally
accepted in the United States (GAAP).
(c) Adjustment to exclude the mark-to-market impact of Exelon's economic
hedging activities, net of intercompany eliminations.
(d) Adjustment to exclude the impact of net unrealized gains and losses
on Generation's NDT fund investments for Non-Regulatory and
Regulatory Agreement Units. The impacts of the Regulatory Agreement
Units, including the associated income taxes, are contractually
eliminated, resulting in no earnings impact.
(e) Adjustment to exclude the non-cash amortization of intangible
assets, net, primarily related to commodity contracts recorded at
fair value related to the ConEdison Solutions and FitzPatrick
acquisitions.
(f) Adjustment to exclude certain costs associated with mergers and
acquisitions, including, if and when applicable, professional fees,
employee-related expenses and integration activities. In 2017,
reflects costs related to the PHI and FitzPatrick acquisitions, and
in 2018, reflects costs related to the PHI acquisition.
(g) Adjustment to exclude costs incurred as part of the settlement
orders approving the PHI acquisition.
(h) Adjustment to exclude charges to earnings related to the impairment
of the ExGen Texas Power, LLC (EGTP) assets held for sale in 2017,
and in 2018 the impairment of certain wind projects at Generation.
(i) Adjustment to exclude, in 2017, primarily reflects accelerated
depreciation and amortization expenses and one-time charges
associated with Generation's decision to early retire the Three Mile
Island nuclear facility. In 2018, primarily reflects accelerated
depreciation and amortization expense associated with Generation's
decision to early retire the Oyster Creek and Three Mile Island
nuclear facilities and a loss associated with Generation's sale of
Residential Solar Holding, LLC, partially offset by a gain
associated with Generation's sale of its electrical contracting
business.
(j) Adjustment to exclude severance and reorganization costs related to
a cost management program.
(k) Adjustment to exclude charges to adjust the environmental reserve
associated with Cotter.
(l) Adjustment to exclude an adjustment to the remeasurement of deferred
income taxes as a result of the Tax Cuts and Jobs Act (TCJA).
(m) Adjustment to exclude adjustments to income tax, penalties and
interest expenses in the second quarter of 2017 as a result of the
finalization of the IRS tax computation related to Exelon's
like-kind exchange tax position.
(n) Adjustment to exclude elimination from Generation's results of the
noncontrolling interest related to certain exclusion items,
primarily related to the impact of unrealized gains and losses on
NDT fund investments at CENG.
(o) The effective tax rate related to Adjusted (non-GAAP) Operating
Earnings is 20.9% and 36.2% for the three months ended June 30, 2018
and June 30, 2017, respectively.
 

EXELON CORPORATION

GAAP Consolidated Statements of Operations and

Adjusted (non-GAAP) Operating Earnings Reconciling Adjustments

(unaudited)

(in millions, except per share data)

 
  Six Months Ended June 30, 2018   Six Months Ended June 30, 2017 (a)
GAAP (b)  

Non-GAAP
Adjustments

  GAAP (b)  

Non-GAAP
Adjustments

 
Operating revenues $ 17,769 $ 102 (c) $ 16,413 $ 116 (c),(e)
Operating expenses
Purchased power and fuel 8,042 (107 ) (c),(i) 6,985 (141 ) (c),(e),(i)
Operating and maintenance 4,691 (104 ) (f),(h),(i),(j),(l) 5,383 (572 ) (f),(g),(h),(i),(j)
Depreciation and amortization 2,179 (289 ) (i) 1,811 (37 ) (e),(i)
Taxes other than income 874   857  
Total operating expenses 15,786 15,036
Gain on sales of assets and businesses 60 (54 ) (i) 5 (1 ) (i)
Bargain purchase gain   226   (226 )

(k)

Operating income 2,043   1,608  
Other income and (deductions)
Interest expense, net (745 ) (809 ) 59

(h),(o),(m)

Other, net 17   269 (d) 434   (274 ) (d),(m)
Total other income and (deductions) (728 ) (375 )
Income before income taxes 1,315 1,233
Income taxes 125 274

(c),(d),(f),(h),(i),(j),(l),(n)

149 441 (c),(d),(e),(f),(g),(h),(i),(j),(m),(n),(o)
Equity in losses of unconsolidated affiliates (11 ) (18 )
Net income 1,179 1,066
Net income (loss) attributable to noncontrolling interests 54   57 (p) (20 ) (55 ) (p)
Net income attributable to common shareholders $ 1,125   $ 1,086  
Effective tax rate(q) 9.5 % 12.1 %
Earnings per average common share
Basic $ 1.16 $ 1.17
Diluted $ 1.16   $ 1.17  
Average common shares outstanding
Basic 967 931
Diluted 968 932
Effect of adjustments on earnings per average diluted common
share recorded in accordance with GAAP:
Mark-to-market impact of economic hedging activities (c) $ 0.13 $ 0.15
Unrealized gains (losses) related to NDT fund investments (d) 0.15 (0.15 )
Amortization of commodity contract intangibles (e) 0.02
Merger and integration costs (f) 0.04
Merger commitments (g) (0.15 )
Long-lived asset impairments (h) 0.03 0.29
Plant retirements and divestitures (i) 0.23 0.07
Cost management program (j) 0.02 0.01
Bargain purchase gain (k) (0.24 )
Change in environmental liabilities (l) 0.01
Like-kind exchange tax position (m) (0.03 )
Reassessment of deferred income taxes (n) (0.01 ) (0.02 )
Tax settlements (o) (0.01 )
Noncontrolling interests (p) (0.06 ) 0.06  
Total adjustments $ 0.50   $ 0.04  
 
(a)   Certain immaterial prior year amounts in the Registrants'
Consolidated Statements of Operations and Comprehensive Income have
been recasted to reflect new accounting standards issued by the FASB
and adopted as of January 1, 2018.
(b) Results reported in accordance with accounting principles generally
accepted in the United States (GAAP).
(c) Adjustment to exclude the mark-to-market impact of Exelon's economic
hedging activities, net of intercompany eliminations.
(d) Adjustment to exclude the impact of net unrealized gains and losses
on Generation's NDT fund investments for Non-Regulatory and
Regulatory Agreement Units. The impacts of the Regulatory Agreement
Units, including the associated income taxes, are contractually
eliminated, resulting in no earnings impact.
(e) Adjustment to exclude the non-cash amortization of intangible
assets, net, primarily related to commodity contracts recorded at
fair value related to the ConEdison Solutions and FitzPatrick
acquisitions.
(f) Adjustment to exclude certain costs associated with mergers and
acquisitions, including, if and when applicable, professional fees,
employee-related expenses and integration activities. In 2017,
reflects costs related to the PHI and FitzPatrick acquisitions,
offset at PHI by the anticipated recovery of previously incurred PHI
acquisition costs, and in 2018, reflects costs related to the PHI
acquisition.
(g) Adjustment to exclude 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.
(h) Adjustment to exclude charges to earnings related to the impairment
of the ExGen Texas Power, LLC (EGTP) assets held for sale in 2017,
and in 2018 the impairment of certain wind projects at Generation.
(i) Adjustment to exclude accelerated depreciation and amortization
expenses and one-time charges associated with Generation's decision
to early retire the Three Mile Island nuclear facility in 2017. In
2018, primarily reflects accelerated depreciation and amortization
expenses and one-time charges associated with Generation's decision
to early retire the Oyster Creek nuclear facility, as well as
accelerated depreciation and amortization expenses associated with
the 2017 decision to early retire the Three Mile Island nuclear
facility and a loss associated with Generation's sale of Residential
Solar Holding, LLC, partially offset by a gain associated with
Generation's sale of its electrical contracting business.
(j) Adjustment to exclude severance and reorganization costs related to
a cost management program.
(k) Adjustment to exclude the excess of the fair value of assets and
liabilities acquired over the purchase price for the FitzPatrick
acquisition.
(l) Adjustment to exclude charges to adjust the environmental reserve
associated with Cotter.
(m) Adjustment to exclude adjustments to income tax, penalties and
interest expenses in the second quarter of 2017 as a result of the
finalization of the IRS tax computation related to Exelon's
like-kind exchange tax position.
(n) Adjustment to exclude the change in the District of Columbia
statutory tax rate in 2017, and in 2018, an adjustment to the
remeasurement of deferred income taxes as a result of the Tax Cuts
and Jobs Act (TCJA).
(o) Adjustment to exclude benefits related to the favorable settlement
in 2017 of certain income tax positions related to PHI's unregulated
business interests.
(p) Adjustment to exclude elimination from Generation's results of the
noncontrolling interest 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 Adjusted (non-GAAP) Operating
Earnings is 18.7% and 35.6% for the six months ended June 30, 2018
and June 30, 2017, respectively.

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