Earnings Release Highlights
- GAAP Net Income of $0.09 per share and
Adjusted Operating Earnings of $0.54 per share for the second
quarter of 2017
- Reaffirming full year 2017 Adjusted
Operating Earnings guidance of $2.50 to $2.80 per share
- Strong utility performance to the
benefit of our customers, with every utility achieving top quartile
CAIDI performance as well as BGE and ComEd achieving their best
ever SAIFI performance
- Courts grant motions to dismiss legal
challenges to the ZEC programs in Illinois and New York, preserving
the economic and environmental benefits of this carbon-free
generation
- Exelon Nuclear completed six refueling
outages with fewer unplanned outage days than a year ago
- Two new combined-cycle gas turbines
totaling nearly 2,200 MWs in Texas went into service, on-time and
on-budget
Exelon Corporation (NYSE: EXC) today reported its financial
results for the second quarter 2017.
“Exelon delivered a strong second quarter for our shareholders
and customers as we continued to make gains in reliability,
customer service and operational performance across our business,”
said Christopher M. Crane, Exelon’s president and CEO. “Exelon can
continue to provide reliable and affordable carbon-free power while
preserving high-value jobs thanks to the dismissal of challenges to
Zero Emissions Credit programs by courts in Illinois and New York,
a win for our customers, the economy and the environment. We also
were recognized with several leadership awards including being one
of only 27 companies in the Billion Dollar Roundtable, recognizing
our nearly $2 billion of spending with diverse and minority-owned
businesses. We were also named to the Points of Light Civic 50 list
of the most community-minded companies, a true credit to our people
who give back their time and resources volunteering in the
communities where we work and live.”
“Exelon once again delivered strong financial performance with
non-GAAP operating earnings of $0.54 per share, which is toward the
upper end of our guidance range,” said Jonathan W. Thayer, Exelon’s
senior executive vice president and CFO. “Exelon remains on
track to meet our full-year guidance of $2.50-2.80 per share as
well as our debt reduction targets.”
Second Quarter 2017
Exelon's GAAP Net Income for the second quarter 2017 decreased
to $0.09 per share from $0.29 per share in the second quarter of
2016; Adjusted (non-GAAP) Operating Earnings decreased to $0.54 per
share in the second quarter of 2017 from $0.65 per share in the
second quarter of 2016. For the reconciliations of GAAP to Adjusted
(non-GAAP) Operating Earnings, refer to the tables below.
Adjusted (non-GAAP) Operating Earnings in the second quarter of
2017 reflect the conclusion of the Ginna reliability support
services agreement, increased nuclear outage days and lower
realized energy prices, partially offset by Zero Emission Credit
revenue related to the New York Clean Energy Standard and higher
utility earnings due to regulatory rate increases.
Operating Company Results1
ComEd
ComEd's second quarter 2017 GAAP Net Income was $118 million
compared with $145 million in the second quarter of 2016. ComEd’s
Adjusted (non-GAAP) Operating Earnings for the second quarter 2017
were $141 million compared with $146 million in the second quarter
of 2016, primarily due to favorable weather conditions in 2016,
partially offset by higher electric distribution and transmission
formula rate earnings. Pursuant to the Illinois Future Energy Jobs
Act, beginning in 2017, customer rates for ComEd are adjusted to
eliminate the favorable and unfavorable impacts of weather and
customer usage patterns on distribution volumes.
PECO
PECO’s second quarter 2017 GAAP Net Income was $88 million
compared with $100 million in the second quarter of 2016. PECO’s
Adjusted (non-GAAP) Operating Earnings for the second quarter 2017
were $89 million compared with $101 million in the second quarter
of 2016, primarily due to unfavorable weather conditions and
volumes.
For the second quarter of 2017, heating degree days were down
29.9 percent relative to the same period in 2016 and were 28.9
percent below normal. Cooling degree days were up 6.1 percent
relative to the same period in 2016 and were 19.3 percent above
normal. Total retail electric deliveries remained relatively
consistent in the second quarter of 2017 compared with the same
period in 2016. Natural gas deliveries (including both retail and
transportation segments) in the second quarter of 2017 were down
3.0 percent compared with the same period in 2016.
Weather-normalized retail electric deliveries remained
relatively consistent, while weather-normalized natural gas
deliveries were up 5.3 percent in the second quarter of 2017
compared with the same period in 2016.
BGE
BGE’s second quarter 2017 GAAP Net Income was $45 million
compared with $31 million in the second quarter of 2016. BGE’s
Adjusted (non-GAAP) Operating Earnings for the second quarter 2017
were $46 million compared with $29 million in the second quarter of
2016, primarily due to the absence of 2016 charges for certain
disallowances contained in June and July 2016 rate case orders and
the net impact of approved rate increases. Due to revenue
decoupling, BGE is not affected by actual weather.
PHI
PHI’s second quarter 2017 GAAP Net Income was $66 million
compared with $52 million in the second quarter of 2016. PHI’s
Adjusted (non-GAAP) Operating Earnings for the second quarter 2017
were $63 million compared with $53 million in the second quarter of
2016, primarily due to the impact of approved rate increases in
2016 and 2017. Due to decoupling, PHI's revenues related to Pepco
and DPL Maryland are not affected by actual weather.
Generation
Generation's second quarter 2017 GAAP Net Loss was $250 million
compared with a GAAP Net Loss of $8 million in the second quarter
of 2016. Generation’s Adjusted (non-GAAP) Operating Earnings for
the second quarter 2017 were $202 million compared with $328
million in the second quarter of 2016, primarily reflecting the
conclusion of the Ginna reliability support services agreement,
increased nuclear outage days and lower realized energy prices,
partially offset by Zero Emission Credit revenue related to the New
York Clean Energy Standard.
The proportion of expected generation hedged as of June 30,
2017 was 96.0 percent to 99.0 percent for 2017, 71.0 percent to
74.0 percent for 2018 and 39.0 percent to 42.0 percent for
2019.
________________________
1 Exelon’s five business units include
ComEd, which consists of electricity transmission and distribution
operations in northern Illinois; PECO, which consists of
electricity transmission and distribution operations and retail
natural gas distribution operations in southeastern Pennsylvania,
BGE, which consists of electricity transmission and distribution
operations and retail natural gas distribution operations in
central Maryland; PHI, which consists of electricity transmission
and distribution operations in the District of Columbia and
portions of Maryland, Delaware, and New Jersey and retail natural
gas distribution operations in northern Delaware; and Generation,
which consists of owned and contracted electric generating
facilities and wholesale and retail customer supply of electric and
natural gas products and services, including renewable energy
products and risk management services.
Second Quarter and Recent Highlights
- Early Retirement of Three Mile
Island Facility: On May 30, 2017, Exelon announced it will
permanently cease generation operations at Three Mile Island
Generating Station (TMI) on or about September 30, 2019. In the
second quarter of 2017, Exelon and Generation recognized one-time
charges in Operating and maintenance expense of $71 million related
to materials and supplies inventory reserve adjustments,
employee-related costs and construction work-in-progress (CWIP)
impairments, among other items. In addition to these one-time
charges, there will be ongoing annual incremental non-cash charges
to earnings stemming from shortening the expected economic useful
life of TMI primarily related to accelerated depreciation of plant
assets (including any asset retirement costs (ARC)), accelerated
amortization of nuclear fuel, and additional asset retirement
obligation (ARO) accretion expense associated with the changes in
decommissioning timing and cost assumptions. Exelon’s and
Generation’s second quarter 2017 results include an incremental $37
million of pre-tax expense for these items. The aforementioned
one-time and incremental charges have been excluded from GAAP Net
Income to arrive at Adjusted (non-GAAP) Operating Earnings.
- EGTP Assets Held for Sale
Agreement: On May 2, 2017, EGTP entered into a consent
agreement with its lenders to permit EGTP to draw on its revolving
credit facility and initiate an orderly sales process to sell the
assets of its wholly-owned subsidiaries, the proceeds from which
will first be used to pay the administrative costs of the sale, the
normal and ordinary costs of operating the plants and repayment of
the secured debt of EGTP, including the revolving credit facility.
As a result, in the second quarter, Exelon and Generation
classified certain EGTP assets and liabilities as held for sale at
their respective fair values less costs to sell. At June 30, 2017,
a $418 million pre-tax impairment loss was recorded within
Operating and maintenance expense on Exelon's and Generation's
Consolidated Statements of Operations and Comprehensive
Income.
- District of Columbia Power Line
Undergrounding Initiative: The District of Columbia government
enacted on an emergency basis (effective May 17, 2017) and
thereafter on a permanent basis (effective July 11, 2017)
legislation to amend the Electric Company Infrastructure
Improvement Financing Act of 2014 (as amended) (the Infrastructure
Improvement Financing Act) to authorize the District of Columbia
Power Line Undergrounding (DC PLUG) initiative, a projected six
year, $500 million project to place underground some of the
District of Columbia’s most outage-prone power lines with $250
million of the project costs funded by Pepco and $250 million
funded by the District of Columbia. The $250 million of project
costs funded by Pepco will be recovered from Pepco's customers in
the District of Columbia. Pepco will earn a return on these project
costs. The $250 million of project costs funded by the District of
Columbia will come from two sources. Project costs of $187.5
million will be funded through a charge assessed on Pepco by the
District of Columbia; Pepco will recover this charge from
customers. The remaining costs up to $62.5 million are to be funded
by the existing capital projects program of the District Department
of Transportation (DDOT). Pepco will not recover or earn a return
on the cost of these assets.
- Like Kind Exchange: In the third
quarter 2016, the United States Tax Court rejected Exelon’s
like-kind exchange position and ruled that Exelon was not entitled
to defer the gain on the transaction. Exelon expects to timely
appeal this decision to the U.S. Court of Appeals for the Seventh
Circuit in the second half of 2017. In June of 2017, the IRS
finalized its computation of tax, penalties and interest owed by
Exelon pursuant to the Tax Court’s decision. As a result of the
IRS’s finalization of its computation in the second quarter 2017,
Exelon recorded a benefit to earnings of approximately $26 million,
consisting of an income tax benefit of $50 million and a reduction
of penalties of $2 million, partially offset by after-tax interest
expense of $26 million, while ComEd recorded a charge to earnings
of approximately $23 million, consisting of income tax expense of
$15 million and after-tax interest expense of $8 million. No
recovery will be sought from ComEd customers for any interest,
penalty or additional income tax payment amounts resulting from the
like-kind exchange tax position.
- DPL Delaware Electric and Natural
Gas Distribution Rates Case: On March 8, 2017, DPL entered into
a settlement agreement with the Division of the Public Advocate,
Delaware Electric Users Group and the DPSC Staff in its electric
distribution rate proceeding, which provides for an increase in DPL
annual electric distribution rates of $31.5 million based on an ROE
of 9.7 percent and compared to the $32.1 million increase
previously put into effect. On May 23, 2017, the DPSC issued an
order approving the settlement agreement, with the new rates
effective June 1, 2017. Pursuant to the settlement agreement, no
refund of any pre-settlement interim rates put into effect is
required.On April 6, 2017, DPL entered into a settlement agreement
with the Division of the Public Advocate and the DPSC Staff in its
natural gas distribution rate proceeding, which provides for an
increase in DPL annual natural gas distribution rates of $4.9
million based on an ROE of 9.7 percent. On June 6, 2017, the DPSC
issued an order approving the settlement agreement, with the new
rates effective July 1, 2017. Pursuant to the settlement agreement,
a rate refund plus interest of approximately $5 million will be
issued to customers beginning in August 2017 for which a regulatory
liability has been recorded as of June 30, 2017.
- DPL Maryland Electric Distribution
Rates: On July 14, 2017, DPL filed an application with the
MDPSC to increase its annual electric distribution base rates by
$27 million based on a requested ROE of 10.1 percent. DPL
expects a decision on the matter in the first quarter of 2018. DPL
cannot predict how much of the requested increase the MDPSC will
approve.
- Pepco District of Columbia Electric
Distribution Rate Case: On July 25, 2017, the DCPSC issued an
order granting Pepco an increase to its annual electric
distribution base rates of $36.9 million effective Aug. 15, 2017,
based on an ROE of 9.5 percent. In its decision, the DCPSC
ordered that the $25.6 million customer rate credit created as a
result of the Exelon and PHI merger will be provided primarily to
residential customers and some small commercial customers until
that amount has been exhausted, which is expected to be
approximately two years. Additionally, the Commission is holding
approximately $6 million to $7 million of the customer rate credit
for use toward a possible new class of customers for certain senior
citizens and disabled persons. The DCPSC also held that Pepco's
bill stabilization adjustment, which decouples distribution
revenues from utility customers from the amount of electricity
delivered, will continue to be in place and that no refund of
previously collected funds is required.
- Nuclear Operations: Generation’s
nuclear fleet, including its owned output from the Salem Generating
Station and 100 percent of the CENG units, produced 44,065
gigawatt-hours (GWhs) in the second quarter of 2017, compared with
42,453 GWhs in the second quarter of 2016. Excluding Salem, the
Exelon-operated nuclear plants at ownership achieved a 90.9 percent
capacity factor for the second quarter of 2017, compared with 92.3
percent for the second quarter of 2016. The number of planned
refueling outage days in the second quarter of 2017 totaled 125,
compared with 87 in the second quarter of 2016. There were 12
non-refueling outage days in the second quarter of 2017, compared
with 21 days in the second quarter of 2016.
- Fossil and Renewables
Operations: The dispatch match rate for Generation’s gas and
hydro fleet was 99.0 percent in the second quarter of 2017,
compared with 97.4 percent in the second quarter of 2016. Energy
capture for the wind and solar fleet was 95.5 percent in the second
quarter of 2017, equal to the performance in the second quarter of
2016.
- Financing Activities:
- On April 3, 2017, Exelon completed
the remarketing of $1.15 billion aggregate principal amount of its
2.500 percent Junior Subordinated Notes due 2024, originally
issued as components of its equity units issued in June 2014,
issuing $1.15 billion aggregate principal amount of
3.497 percent Junior Subordinated Notes due in 2022. Exelon
conducted the remarketing on behalf of the holders of equity units
and did not directly receive any proceeds therefrom. Instead,
Exelon received $1.15 billion on June 1, 2017 upon settlement of
the forward equity purchase contract and issued approximately 33
million shares of common stock from treasury stock at the time of
settlement.
- On May 22, 2017, Pepco issued $200
million aggregate principal amount of its 4.150 percent First
Mortgage Bonds due in 2043. The proceeds from the sale of the First
Mortgage Bonds were used to repay outstanding commercial paper and
for general corporate purposes.
GAAP/Adjusted (non-GAAP) Operating Earnings
Reconciliation
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 Earnings (Loss):
(in millions)
ExelonEarnings perDilutedShare
Exelon
ComEd
PECO
BGE
PHI
Generation
2017 GAAP Earnings (Loss)
$
0.09
$
80
$
118
$
88
$
45
$
66
$
(250
)
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 Integration Costs
(net of taxes of $9, $1 and $7, respectively) 0.01 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 — — — — CENG
Noncontrolling Interest (net of taxes of $5) 0.02
20 — —
— — 20
2017 Adjusted (non-GAAP) Operating
Earnings
$
0.54
$
509
$
141
$
89
$
46
$
63
$
202
Adjusted (non-GAAP) Operating Earnings for the second quarter of
2016 do not include the following items (after tax) that were
included in reported GAAP Earnings (Loss):
(in millions)
ExelonEarnings perDilutedShare
Exelon
ComEd
PECO
BGE
PHI
Generation
2016 GAAP Earnings (Loss)
$
0.29
$
267
$
145
$
100
$
31
$
52
$
(8
)
Mark-to-Market Impact of Economic Hedging Activities (net of taxes
of $120 and $119, respectively) 0.20 185 — — — — 185 Unrealized
Gains Related to NDT Fund Investments (net of taxes of $29) (0.03 )
(27 ) — — — — (27 ) Amortization of Commodity Contract Intangibles
(net of taxes of $4) 0.01 8 — — — — 8 Merger and Integrations Costs
(net of taxes of $0, $0, $2 and $2, respectively) — 1 1 — (3 ) — 3
Merger Commitments (entire amount represents tax expense) — 1 — — —
1 — Long-Lived Asset Impairments (net of taxes of $14) 0.02 22 — —
— — 22 Plant Retirements and Divestitures (net of taxes of $85)
0.14 133 — — — — 133 Cost Management Program (net of taxes of $3,
$0, $0 and $2, respectively) 0.01 6 — 1 1 — 4 CENG Noncontrolling
Interest (net of taxes of $1) 0.01
8 — — —
— 8
2016 Adjusted (non-GAAP) Operating
Earnings
$
0.65
$
604
$
146
$
101
$
29
$
53
$
328
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 percent to 41
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 31.4 percent and 47.5
percent for the three and six months ended June 30, 2017,
respectively, and 51.6 percent and 52.5 percent for the three and
six months ended June 30, 2016, respectively.
Webcast Information
Exelon will discuss second quarter 2017 earnings in a one-hour
conference call scheduled for today at 10 a.m. Central Time (11
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 2016 revenue of $31.4 billion. Exelon’s six utilities deliver
electricity and natural gas to approximately 10 million customers
in Delaware, the District of Columbia, Illinois, Maryland, New
Jersey and Pennsylvania through its Atlantic City Electric, BGE,
ComEd, Delmarva Power, PECO and Pepco subsidiaries. Exelon is one
of the largest competitive U.S. power generators, with more than
33,300 megawatts of nuclear, gas, wind, solar and hydroelectric
generating capacity comprising one of the nation’s cleanest and
lowest-cost power generation fleets. The company’s Constellation
business unit provides energy products and services to
approximately 2.2 million residential, public sector and business
customers, including more than two-thirds of the Fortune 100.
Follow Exelon on Twitter @Exelon.
Non-GAAP Financial Measures
In addition to net income as determined under generally accepted
accounting principles in the United States (GAAP), Exelon evaluates
its operating performance using the measure of Adjusted (non-GAAP)
Operating Earnings because management believes it represents
earnings directly related to the ongoing operations of the
business. Adjusted (non-GAAP) Operating Earnings exclude
certain costs, expenses, gains and losses and other specified
items. This measure is intended to enhance an investor’s overall
understanding of period over period operating results and provide
an indication of Exelon’s baseline operating performance excluding
items that are considered by management to be not directly related
to the ongoing operations of the business. In addition, this
measure is among the primary indicators management uses as a basis
for evaluating performance, allocating resources, setting incentive
compensation targets and planning and forecasting of future
periods. Adjusted (non-GAAP) Operating Earnings is not a
presentation defined under GAAP and may not be comparable to other
companies’ presentation. The Company has provided the non-GAAP
financial measure as supplemental information and in addition to
the financial measures that are calculated and presented in
accordance with GAAP. Adjusted (non-GAAP) Operating Earnings
should not be deemed more useful than, a substitute for, or an
alternative to the most comparable GAAP Net Income measures
provided in this earnings release and attachments. This press
release and earnings release attachments provide reconciliations of
adjusted (non-GAAP) Operating Earnings to the most directly
comparable financial measures calculated and presented in
accordance with GAAP, are posted on Exelon’s website: www.exeloncorp.com, and have been furnished to the
Securities and Exchange Commission on Form 8-K on Aug. 2, 2017.
Cautionary Statements Regarding Forward-Looking
Information
This press release contains certain
forward-looking statements within the meaning of the Private
Securities Litigation Reform Act of 1995, that are subject to risks
and uncertainties. The factors that could cause actual results to
differ materially from the forward-looking statements made by
Exelon Corporation, Exelon Generation Company, LLC, Commonwealth
Edison Company, PECO Energy Company, Baltimore Gas and Electric
Company, Pepco Holdings LLC, Potomac Electric Power Company,
Delmarva Power & Light Company, and Atlantic City Electric
Company (Registrants) include those factors discussed herein, as
well as the items discussed in (1) the Registrants' 2016 Annual
Report on Form 10-K in (a) ITEM 1A. Risk Factors, (b) ITEM 7.
Management’s Discussion and Analysis of Financial Condition and
Results of Operations and (c) ITEM 8. Financial Statements and
Supplementary Data: Note 24, Commitments and Contingencies; (2) the
Registrants' Second Quarter 2017 Quarterly Report on Form 10-Q (to
be filed on August 2, 2017) in (a) Part II, Other Information, ITEM
1A. Risk Factors; (b) Part 1, Financial Information, ITEM 2.
Management’s Discussion and Analysis of Financial Condition and
Results of Operations and (c) Part I, Financial Information, ITEM
1. Financial Statements: Note 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, 2017
Three Months Ended June 30, 2016 GAAP (a)
Non-GAAP
Adjustments
GAAP (a)
Non-GAAP
Adjustments
Operating revenues $ 7,623 $ 158 (b),(d) $ 6,910 $ 626
(b),(d),(e)
Operating expenses Purchased power and fuel
3,086 (48 ) (b),(d) 2,454 300 (b),(d),(h) Operating and maintenance
2,971 (524 )
(e),(f),(g),
(h),(i)
2,505 (172 )
(e),(g),(h),
(i)
Depreciation and amortization 915 (35 ) (h) 941 (114 ) (h) Taxes
other than income 420 394
Total operating
expenses 7,392 6,294
Gain on sales of assets 1 31
Operating income 232 647
Other
income and (deductions) Interest expense, net (436 ) 63 (g),(j)
(376 ) Other, net 205 (66 ) (c),(j) 144 (89 ) (c),(h)
Total other income and (deductions) (231 ) (232 )
Income
before income taxes 1 415
Income taxes (72 ) 353
(b),(c),(d),
(e),(f),(g),
(h),(i),(j)
102 194
(b),(c),(d),
(e),(f),(g),
(h),(i)
Equity in losses of unconsolidated affiliates (9 ) (7 )
Net income 64 306
Net income (loss) attributable to
noncontrolling interests and preference stock dividends (16 )
(20 ) (k) 39 (8 ) (k)
Net income attributable to common
shareholders $ 80 $ 267
Effective tax
rate(l) (7,200.0 )% 24.6 %
Earnings per average
common share Basic $ 0.09 $ 0.29 Diluted $ 0.09 $ 0.29
Average common shares outstanding Basic 934 924
Diluted 936 926
Effect of adjustments on earnings per average
diluted common share recorded in accordance with GAAP:
Mark-to-market impact of economic hedging activities (b) $ 0.12 $
0.20 Unrealized gains related to NDT fund investments (c) (0.05 )
(0.03 ) Amortization of commodity contract intangibles (d) 0.01
0.01 Merger and integration costs (e) 0.01 — Merger commitments (f)
— — Long-lived asset impairments (g) 0.29 0.02 Plant retirements
and divestitures (h) 0.07 0.14 Cost management program (i) 0.01
0.01 Like-kind exchange tax position (j) (0.03 ) — CENG
noncontrolling interest (k) 0.02 0.01 Total
adjustments $ 0.45 $ 0.36 (a) Results reported
in accordance with accounting principles generally accepted in the
United States (GAAP). (b) Adjustment to exclude the mark-to-market
impact of Exelon’s economic hedging activities, net of intercompany
eliminations. (c) Adjustment to exclude the unrealized gains and
losses on NDT fund investments to the extent not offset by
contractual accounting as described in the notes to the
consolidated financial statements. (d) Adjustment to exclude the
non-cash amortization of intangible assets, net, primarily related
to commodity contracts recorded at fair value related to the
Integrys acquisition in 2016, and in 2017, the ConEdison Solutions
and FitzPatrick acquisitions. (e) Adjustment to exclude certain
costs associated with mergers and acquisitions, including, if and
when applicable, professional fees, employee-related expenses and
integration activities related to the PHI acquisition in 2016,
partially offset in 2016 at BGE and PHI by the anticipated recovery
of previously incurred PHI acquisition costs, and in 2017, the PHI
and FitzPatrick acquisitions. (f) Adjustment to exclude costs
incurred as part of the settlement orders approving the PHI
acquisition. (g) Adjustment to exclude charges to earnings related
to the impairment of certain wind projects at Generation in 2016,
and in 2017, impairments as a result of the ExGen Texas Power, LLC
assets held for sale. (h) Adjustment to exclude accelerated
depreciation and amortization expenses, increases to materials and
supplies inventory reserves, charges for severance reserves and
construction work in progress impairments associated with
Generation's previous decision to early retire the Clinton and Quad
Cities nuclear facilities in 2016, and Generation's decision to
early retire the Three Mile Island nuclear facility in 2017,
partially offset in 2016 by a gain associated with Generation’s
sale of the New Boston generating site. (i) Adjustment to exclude
reorganization costs, and in 2016 severance costs, related to a
cost management program. (j) Adjustment to excluded 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. (k) Adjustment to
eliminate from Generation’s results of the noncontrolling interest
related to CENG exclusion items, primarily related to the impact of
unrealized gains and losses on NDT fund investments and
mark-to-market activity. (l) The effective tax rate related to
Adjusted (non-GAAP) Operating Earnings is 36.8% and 31.6% for the
three months ended June 30, 2017 and June 30, 2016, respectively.
The effective tax rate for the three months ended June 30, 2017 is
disproportionately impacted due to the decline in pre-tax GAAP
earnings and changes in other reconciling items.
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, 2017
Six Months Ended June 30, 2016 GAAP (a)
Non-GAAP
Adjustments
GAAP (a)
Non-GAAP
Adjustments
Operating revenues $ 16,381 $ 116 (b),(d) $ 14,485 $ 534
(b),(d),(e)
Operating expenses Purchased power and fuel
6,985 (141 ) (b),(d),(h) 5,708 338 (b),(d),(h) Operating and
maintenance 5,431 (572 ) (e),(f),(g),(h),(j) 5,341 (932 )
(e),(f),(g),(h),(j) Depreciation and amortization 1,811 (37 )
(d),(h) 1,626 (114 ) (h) Taxes other than income 857 720
(1 ) (j)
Total operating expenses 15,084 13,395
Gain on sales of assets 5 (1 ) (h) 40
Bargain purchase
gain 226 (226 ) (l) —
Operating income
1,528 1,130
Other income and (deductions)
Interest expense, net (809 ) 59 (g),(k),(m) (663 ) Other, net 488
(274 ) (c),(m) 258 (155 ) (c),(h)
Total other
income and (deductions) (321 ) (405 )
Income before income
taxes 1,207 725
Income taxes 143 441
(b),(c),(d),
(e),(f),(g),
(h),(i),(j),
(k),(m)
285 311
(b),(c),(d),
(e),(f),(g),
(h),(j)
Equity in losses of unconsolidated affiliates (18 ) (10 )
Net income 1,046 430
Net loss attributable to
noncontrolling interests and preference stock dividends (30 )
(55 ) (n) (10 ) (18 ) (n)
Net income attributable to common
shareholders $ 1,076 $ 440
Effective tax
rate(o) 11.8 % 39.3 %
Earnings per average common
share Basic $ 1.16 $ 0.48 Diluted $ 1.15 $ 0.48
Average common shares outstanding Basic 931 923 Diluted 932
926
Effect of adjustments on earnings per average diluted common
share recorded in accordance with GAAP: Mark-to-market impact
of economic hedging activities (b) $ 0.15 $ 0.12 Unrealized gains
related to NDT fund investments (c) (0.15 ) (0.07 ) Amortization of
commodity contract intangibles (d) 0.02 — Merger and integration
costs (e) 0.04 0.09 Merger commitments (f) (0.15 ) 0.43 Long-lived
asset impairments (g) 0.29 0.10 Plant retirements and divestitures
(h) 0.07 0.14 Reassessment of state deferred income taxes (i) (0.02
) — Cost management program (j) 0.01 0.02 Tax settlements (k) (0.01
) — Bargain purchase gain (l) (0.24 ) — Like-kind exchange tax
position (m) (0.03 ) — CENG noncontrolling interest (n) 0.06
0.02 Total adjustments $ 0.04 $ 0.85 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 June 30, 2017. Therefore, the results of operations from
2017 and 2016 are not comparable for Exelon. The explanations below
identify any other significant or unusual items affecting the
results of operations. (a) Results reported in
accordance with accounting principles generally accepted in the
United States (GAAP). (b) Adjustment to exclude the mark-to-market
impact of Exelon’s economic hedging activities, net of intercompany
eliminations. (c) Adjustment to exclude the unrealized gains and
losses on NDT fund investments to the extent not offset by
contractual accounting as described in the notes to the
consolidated financial statements. (d) Adjustment to exclude the
non-cash amortization of intangible assets, net, primarily related
to commodity contracts recorded at fair value related to the
Integrys acquisition in 2016, and in 2017, the ConEdison Solutions
and FitzPatrick acquisitions. (e) Adjustment to exclude certain
costs associated with mergers and acquisitions, including, if and
when applicable, professional fees, employee-related expenses and
integration activities related to the PHI acquisition in 2016,
partially offset in 2016 at ComEd, BGE and PHI by the anticipated
recovery of previously incurred PHI acquisition costs, and in 2017,
the PHI and FitzPatrick acquisitions, partially offset in 2017 at
PHI by the anticipated recovery of previously incurred PHI
acquisition costs. (f) Adjustment to exclude in 2016 costs incurred
as part of the settlement orders approving the PHI acquisition, and
in 2017, a decrease in reserves for uncertain tax positions related
to the deductibility of certain merger commitments associated with
the 2012 CEG and 2016 PHI acquisitions. (g) Adjustment to exclude
charges to earnings related to the impairment of upstream assets
and certain wind projects at Generation in 2016, and in 2017,
impairments as a result of the ExGen Texas Power, LLC assets held
for sale. (h) Adjustment to exclude accelerated depreciation and
amortization expenses, increases to materials and supplies
inventory reserves, charges for severance reserves and construction
work in progress impairments associated with Generation's previous
decision to early retire the Clinton and Quad Cities nuclear
facilities in 2016, and Generation's decision to early retire the
Three Mile Island nuclear facility in 2017, partially offset in
2016 by a gain associated with Generation’s sale of the New Boston
generating site. (i) Adjustment to exclude the non-cash impact of
the remeasurement of state deferred income taxes, primarily as a
result of changes in forecasted apportionment related to the PHI
acquisition in 2016, and in 2017, a change in the statutory tax
rate. (j) Adjustment to exclude reorganization costs, and in 2016
severance costs, related to a cost management program (k)
Adjustment to exclude benefits related to the favorable settlement
in 2017 of certain income tax positions related to PHI's
unregulated business interests (l) Adjustment to exclude the excess
of the fair value of assets and liabilities acquired over the
purchase price for the FitzPatrick acquisition. (m) Adjustment to
exclude 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 from Generation’s results of the
noncontrolling interest related to CENG exclusion items, primarily
related to the impact of unrealized gains and losses on NDT fund
investments and mark-to-market activity (o) The effective tax rate
related to Adjusted (non-GAAP) Operating Earnings is 35.8% and
32.9% for the six months ended June 30, 2017 and June 30, 2016,
respectively.
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version on businesswire.com: http://www.businesswire.com/news/home/20170802005392/en/
Exelon CorporationDan EggersInvestor Relations312-394-2345orPaul
AdamsCorporate Communications410-470-4167
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