•GAAP Net Income of $0.41 per share and Adjusted (non-GAAP) Operating Earnings of $0.89 per share for the second quarter of 2021
•Reaffirming range for full year 2021 Adjusted (non-GAAP) Operating Earnings guidance of $2.60-$3.00
•Exelon utilities announced the "path to clean" goal to reduce operations-driven emissions 50% by 2030 against a 2015 baseline and achieve net-zero by 2050
•Strong utility reliability performance -- all gas utilities achieved top decile in gas odor response and every utility achieved top quartile in outage frequency and outage duration
•Generation’s nuclear fleet capacity factor was 93.7% (owned and operated units)
•Orders in Pepco Maryland's electric multi-year plan, Pepco DC's electric multi-year plan, and PECO's gas rate cases were received in June. A settlement was also approved in the ACE electric rate case in July.
CHICAGO (Aug. 4, 2021) — Exelon Corporation (Nasdaq: EXC) today reported its financial results for the second quarter of 2021.
“Ongoing investments in technology and infrastructure continue to drive high reliability and customer satisfaction across our six utilities, and today we announced a new ‘path to clean’ goal that will put Exelon utilities on course to achieve net-zero emissions from operations by 2050,” said Christopher Crane, president and CEO of Exelon. “We also are encouraged to see growing support at the federal level for policies that would value the clean energy from our nuclear fleet, but passage of legislation remains uncertain and, regardless, will come too late to save our Byron and Dresden plants from early retirement this fall. While we remain hopeful that a state solution will pass in time to save the plants, clean energy legislation in Illinois remains caught in negotiations over unrelated policy matters, leaving us no choice but to continue down the path of closing the plants. Looking ahead, we continue to execute our plan to separate our utility and generation businesses into two financially strong, independent companies, and we remain on track to close in the first quarter of 2022.”
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“Adjusted (non-GAAP) Operating Earnings of $0.89 per share in the second quarter was $0.34 ahead of the same period last year, driven in part by the absence of storm costs at Exelon utilities and the recovery of costs associated with ongoing investments to improve reliability and service for customers,” said Joseph Nigro, senior executive vice president and CFO of Exelon. “Exelon Generation also had a strong quarter, with year-over-year earnings up $0.14 per share due to unrealized and realized gains on Constellation’s Technology Venture investments, fewer planned nuclear outage days and realized gains in our nuclear decommissioning trust funds. As a result of these and other factors, we are reaffirming our full-year Adjusted (non-GAAP) Operating Earnings guidance range of $2.60-$3.00 per share.”
Second Quarter 2021
Exelon's GAAP Net Income for the second quarter of 2021 decreased to $0.41 per share from $0.53 GAAP Net Income per share in the second quarter of 2020. Adjusted (non-GAAP) Operating Earnings for the second quarter of 2021 increased to $0.89 per share from $0.55 per share in the second quarter of 2020. For the reconciliations of GAAP Net Income to Adjusted (non-GAAP) Operating Earnings, refer to the tables beginning on page 5.
Adjusted (non-GAAP) Operating Earnings in the second quarter of 2021 primarily reflect:
•Higher utility earnings primarily due to higher electric distribution earnings at ComEd from higher rate base and higher allowed ROE due to an increase in treasury rates; the favorable impacts of the multi-year plan at BGE; regulatory rate increases at PHI; favorable volume at PECO and PHI; and lower storm costs at PECO due to the absence of the June 2020 storms.
•Higher Generation earnings primarily due to higher net unrealized and realized gains on equity investments; higher realized gains on nuclear decommissioning trust (NDT) funds; and decreased nuclear outage days.
Operating Company Results1
ComEd
ComEd's second quarter of 2021 GAAP Net Income increased to $192 million from a GAAP Net Loss of $(61) million in the second quarter of 2020. ComEd's Adjusted (non-GAAP) Operating Earnings for the second quarter of 2021 increased to $195 million from $150 million in the second quarter of 2020, primarily due to higher electric distribution earnings from higher rate base and higher allowed ROE due to an increase in treasury rates. Due to revenue decoupling, ComEd's distribution earnings are not affected by actual weather or customer usage patterns.
PECO
PECO’s second quarter of 2021 GAAP Net Income increased to $104 million from $39 million in the second quarter of 2020. PECO's Adjusted (non-GAAP) Operating Earnings for the second quarter of 2021 increased to $107 million from $44 million in the second quarter of 2020, primarily due to lower storm costs due to the absence of the June 2020 storms and favorable volume.
___________
1Exelon’s five business units include ComEd, which consists of electricity transmission and distribution operations in northern Illinois; PECO, which consists of electricity transmission and distribution operations and retail natural gas distribution operations in southeastern Pennsylvania; BGE, which consists of electricity transmission and distribution operations and retail natural gas distribution operations in central Maryland; PHI, which consists of electricity transmission and distribution operations in the District of Columbia and portions of Maryland, Delaware, and New Jersey and retail natural gas distribution operations in northern Delaware; and Generation, which consists of owned and contracted electric generating facilities and wholesale and retail customer supply of electric and natural gas products and services, including renewable energy products and risk management services.
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BGE
BGE’s second quarter of 2021 GAAP Net Income increased to $45 million from $39 million in the second quarter of 2020. BGE's Adjusted (non-GAAP) Operating Earnings for the second quarter of 2021 increased to $48 million from $43 million in the second quarter of 2020, primarily due to the favorable impacts of the multi-year plan. Due to revenue decoupling, BGE's distribution earnings are not affected by actual weather or customer usage patterns.
PHI
PHI’s second quarter of 2021 GAAP Net Income increased to $141 million from $94 million in the second quarter of 2020. PHI’s Adjusted (non-GAAP) Operating Earnings for the second quarter of 2021 increased to $144 million from $98 million in the second quarter of 2020, primarily due to distribution and transmission rate increases at DPL and ACE, favorable volume at ACE, and lower credit loss expense in 2021 due to an increase in 2020 as a result of COVID-19. Due to revenue decoupling, PHI's distribution earnings related to Pepco Maryland, DPL Maryland and Pepco District of Columbia are not affected by actual weather or customer usage patterns.
Generation
Generation had a GAAP Net Loss of $(61) million in the second quarter of 2021 compared with GAAP Net Income of $476 million in the second quarter of 2020. Generation's Adjusted (non-GAAP) Operating Earnings for the second quarter of 2021 increased to $393 million from $252 million in the second quarter of 2020, primarily due to net unrealized and realized gains on equity investments, higher realized gains on NDT funds, and decreased nuclear outage days.
As of June 30, 2021, the percentage of expected generation hedged is 98%-101% for 2021.
Recent Developments and Second Quarter Highlights
•Exelon Utilities “Path to Clean”: Today, the Exelon utilities announced a “path to clean” goal to collectively reduce their operations-driven emissions 50% by 2030 against a 2015 baseline and to reach net zero operations-driven emissions by 2050. This goal builds upon Exelon’s long-standing commitment to reducing our greenhouse gas emissions. The Exelon utilities “path to clean” will include efficiency and clean electricity for operations, vehicle fleet electrification, equipment and processes to reduce sulfur hexafluoride (SF6) leakage, modern natural gas infrastructure to minimize methane leaks and increase safety and reliability, and investment and collaboration to develop new technologies.
•PECO Pennsylvania Natural Gas Distribution Base Rate Case: On June 22, 2021, the Pennsylvania Public Utility Commission (PAPUC) issued an order approving a $29 million increase in PECO's annual natural gas distribution revenues, reflecting a ROE of 10.24%. The rates were effective on July 1, 2021.
•Pepco District of Columbia Electric Distribution Base Rate Case: On June 8, 2021, the Public Service Commission of the District of Columbia (DCPSC) approved Pepco’s multi-year plan for the 18-months remaining in 2021 through 2022. The order approved an incremental increase in Pepco’s electric distribution rates of $42 million and $67 million, before offsets, for the remainder of 2021 and 2022, respectively, reflecting an ROE of 9.275%. However, the DCPSC utilized the acceleration of refunds for certain tax benefits along with other rate relief to partially offset the customer rate increases by $22 million and $40 million for the remainder of 2021 and 2022, respectively. These rates were effective on July 1, 2021.
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•Pepco Maryland Electric Distribution Base Rate Case: On June 28, 2021, the Maryland Public Service Commission (MDPSC) approved Pepco’s three-year multi-year plan for April 1, 2021 through March 31, 2024. The order approved an incremental increase in Pepco’s electric distribution rates of $21 million, $16 million, and $15 million, before offsets, for the 12-month periods ending March 31, 2022, 2023, and 2024, respectively, reflecting an ROE of 9.55%. However, the MDPSC utilized the acceleration of refunds for certain tax benefits to fully offset the increases such that customer rates remain unchanged through March 31, 2022. The MDPSC has deferred a decision on whether to use additional tax benefits to offset the customer rate increases for periods after March 31, 2022. These rates were effective on June 28, 2021.
•ACE New Jersey Electric Distribution Base Rate Case: On July 14, 2021, the New Jersey Board of Public Utilities (NJBPU) approved an increase in ACE's annual electric distribution base rates of $41 million (before New Jersey sales and use tax), reflecting an ROE of 9.6%. The order allows ACE to retain approximately $11 million of certain tax benefits which will result in a decrease to income tax expense in the third quarter of 2021. These rates are effective on Jan. 1, 2022.
•Nuclear Operations: Generation’s nuclear fleet, including its owned output from the Salem Generating Station and 100% of the CENG units, produced 43,575 gigawatt-hours (GWhs) in the second quarter of 2021, compared with 43,416 GWhs in the second quarter of 2020. Excluding Salem, the Exelon-operated nuclear plants at ownership achieved a 93.7% capacity factor for the second quarter of 2021, compared with 95.4% for the second quarter of 2020. The number of planned refueling outage days in the second quarter of 2021 totaled 66, compared with 92 in the second quarter of 2020. There were seven non-refueling outage days in the second quarter of 2021 and none in the second quarter of 2020.
•Fossil and Renewables Operations: The Dispatch Match rate for Generation’s gas and hydro fleet was 99.5% in the second quarter of 2021, compared with 97.4% in the second quarter of 2020.
Energy Capture for the wind and solar fleet was 96.0% in the second quarter of 2021, compared with 92.7% in the second quarter of 2020.
•Financing Activities:
◦On June 10, 2021, BGE issued $600 million of its 2.25% notes due June 15, 2031. BGE used the proceeds to repay a portion of outstanding commercial paper obligations, repay existing indebtedness, and to fund other general corporate purposes.
◦On May 13, 2021, West Medway II, LLC (West Medway II), an indirect subsidiary of Generation, entered into a financing agreement for a $150 million nonrecourse senior secured term loan credit facility scheduled to mature on March 31, 2026. The term loan bears interest at an average blended interest rate of LIBOR plus 3%. Generation used the proceeds for general corporate purposes. In addition to the financing, West Medway II entered into interest rate swaps with an initial notional amount of $113 million at an interest rate of 0.61% to manage a portion of the interest rate exposure in connection with financing.
Adjusted (non-GAAP) Operating Earnings for the second quarter of 2021 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
2021 GAAP Net Income (Loss)
$
0.41
$
401
$
192
$
104
$
45
$
141
$
(61)
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $79)
(0.24)
(231)
—
—
—
—
(234)
Unrealized Gains Related to NDT Fund Investments (net of taxes of $134)
(0.13)
(130)
—
—
—
—
(130)
Asset Impairments (net of taxes of $124)
0.38
368
—
—
—
—
368
Plant Retirements and Divestitures (net of taxes of $116)
0.35
344
—
—
—
—
344
Cost Management Program (net of taxes of $1)
—
2
—
—
—
—
2
COVID-19 Direct Costs (net of taxes of $3, $0, $0, $1, and $2, respectively)
0.01
9
—
1
1
2
5
Acquisition Related Costs (net of taxes of $1)
—
2
—
—
—
—
2
ERP System Implementation Costs (net of taxes of $1)
—
2
—
—
—
—
2
Planned Separation Costs (net of taxes of $7, $1, $1, $1, $1, and $2, respectively)
0.01
13
2
1
1
2
5
Costs Related to Suspension of Contractual Offset (net of taxes of $12)
0.04
41
—
—
—
—
41
Income Tax-Related Adjustments (entire amount represents tax expense)
—
(2)
—
—
—
—
—
Noncontrolling Interests (net of taxes of $8)
0.05
50
—
—
—
—
50
2021 Adjusted (non-GAAP) Operating Earnings
$
0.89
$
869
$
195
$
107
$
48
$
144
$
393
5
Adjusted (non-GAAP) Operating Earnings for the second quarter of 2020 do not include the following items (after tax) that were included in reported GAAP Net Income:
(in millions)
Exelon Earnings per Diluted Share
Exelon
ComEd
PECO
BGE
PHI
Generation
2020 GAAP Net Income (Loss)
$
0.53
$
521
$
(61)
$
39
$
39
$
94
$
476
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $18 and $20, respectively)
(0.05)
(51)
—
—
—
—
(60)
Unrealized Gains Related to NDT Fund Investments (net of taxes of $275)
(0.31)
(305)
—
—
—
—
(305)
Asset Impairments (net of taxes of $7, $4, and $3, respectively)
0.02
19
11
—
—
—
8
Plant Retirements and Divestitures (net of taxes of $2)
0.01
7
—
—
—
—
7
Cost Management Program (net of taxes of $3, $1, and $2, respectively)
0.01
6
—
—
—
1
5
Change in Environmental Liabilities (net of taxes of $0)
—
1
—
—
—
—
1
COVID-19 Direct Costs (net of taxes of $10, $2, $1, $1, and $6, respectively)
0.03
27
—
5
4
3
16
Deferred Prosecution Agreement Payments (net of taxes of $0)
0.20
200
200
—
—
—
—
Income Tax-Related Adjustments (entire amount represents tax expense)
0.01
5
—
—
—
—
—
Noncontrolling Interests (net of taxes of $20)
0.11
104
—
—
—
—
104
2020 Adjusted (non-GAAP) Operating Earnings
$
0.55
$
536
$
150
$
44
$
43
$
98
$
252
Note:
Amounts may not sum due to rounding.
Unless otherwise noted, the income tax impact of each reconciling item between GAAP Net Income (Loss) and Adjusted (non-GAAP) Operating Earnings 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 2021 and 2020 ranged from 25.0% to 29.0%. Under IRS regulations, NDT fund investment returns are taxed at different rates for investments if they are in qualified or non-qualified funds. The effective tax rates for the unrealized losses related to NDT fund investments were 50.6% and 47.4% for the three months ended June 30, 2021 and 2020, respectively.
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Webcast Information
Exelon will discuss second quarter 2021 earnings in a conference call scheduled for today at 9 a.m. Central Time (10 a.m. Eastern Time). The webcast and associated materials can be accessed at www.exeloncorp.com/investor-relations.
About Exelon
Exelon Corporation (Nasdaq: EXC) is a Fortune 100 energy company with the largest number of electricity and natural gas customers in the U.S. Exelon does business in 48 states, the District of Columbia, and Canada and had 2020 revenue of $33 billion. Exelon serves approximately 10 million customers in Delaware, the District of Columbia, Illinois, Maryland, New Jersey, and Pennsylvania through its Atlantic City Electric, BGE, ComEd, Delmarva Power, PECO, and Pepco subsidiaries. Exelon is one of the largest competitive U.S. power generators, with more than 31,000 megawatts of nuclear, gas, wind, solar and hydroelectric generating capacity comprising one of the nation’s cleanest and lowest-cost power generation fleets. The company’s Constellation business unit provides energy products and services to approximately 2 million residential, public sector, and business customers, including three fourths of the Fortune 100. Follow Exelon on Twitter @Exelon.
Non-GAAP Financial Measures
In addition to net income as determined under generally accepted accounting principles in the United States (GAAP), Exelon evaluates its operating performance using the measure of Adjusted (non-GAAP) Operating Earnings because management believes it represents earnings directly related to the ongoing operations of the business. Adjusted (non-GAAP) Operating Earnings exclude certain costs, expenses, gains and losses, and other specified items. This measure is intended to enhance an investor’s overall understanding of period over period operating results and provide an indication of Exelon’s baseline operating performance excluding items that are considered by management to be not directly related to the ongoing operations of the business. In addition, this measure is among the primary indicators management uses as a basis for evaluating performance, allocating resources, setting incentive compensation targets, and planning and forecasting of future periods. Adjusted (non-GAAP) Operating Earnings is not a presentation defined under GAAP and may not be comparable to other companies’ presentation. The Company has provided the non-GAAP financial measure as supplemental information and in addition to the financial measures that are calculated and presented in accordance with GAAP. Adjusted (non-GAAP) Operating Earnings should not be deemed more useful than, a substitute for, or an alternative to the most comparable GAAP Net Income measures provided in this earnings release and attachments. This press release and earnings release attachments provide reconciliations of Adjusted (non-GAAP) Operating Earnings to the most directly comparable financial measures calculated and presented in accordance with GAAP, are posted on Exelon’s website: www.exeloncorp.com, and have been furnished to the Securities and Exchange Commission on Form 8-K on Aug. 4, 2021.
Cautionary Statements Regarding Forward-Looking Information
This press release contains certain forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995 that are subject to risks and uncertainties including, among others, those related to the timing, manner, tax-free nature, and expected benefits associated with the potential separation of Exelon’s competitive power generation and customer-facing energy business from its six regulated electric and gas utilities. Words such as “could,” “may,” “expects,” “anticipates,” “will,” “targets,” “goals,” “projects,” “intends,” “plans,” “believes,” “seeks,” “estimates,” “predicts,” and variations on such words, and similar expressions that reflect our current views with respect to future
7
events and operational, economic, and financial performance, are intended to identify such forward-looking statements.
The factors that could cause actual results to differ materially from the forward-looking statements made by Exelon Corporation, Exelon Generation Company, LLC, Commonwealth Edison Company, PECO Energy Company, Baltimore Gas and Electric Company, Pepco Holdings LLC, Potomac Electric Power Company, Delmarva Power & Light Company, and Atlantic City Electric Company (Registrants) include those factors discussed herein, as well as the items discussed in (1) the Registrants' 2020 Annual Report on Form 10-K in (a) Part I, ITEM 1A. Risk Factors, (b) Part II, ITEM 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations, and (c) Part II, ITEM 8. Financial Statements and Supplementary Data: Note 19, Commitments and Contingencies; (2) the Registrants' Second Quarter 2021 Quarterly Report on Form 10-Q (to be filed on Aug. 4, 2021) in (a) Part II, ITEM 1A. Risk Factors, (b) Part I, ITEM 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations, and (c) Part I, ITEM 1. Financial Statements: Note 15, Commitments and Contingencies; and (3) other factors discussed in filings with the SEC by the Registrants.
Investors are cautioned not to place undue reliance on these forward-looking statements, whether written or oral, which apply only as of the date of this press release. None of the Registrants undertakes any obligation to publicly release any revision to its forward-looking statements to reflect events or circumstances after the date of this press release.
Equity in (losses) earnings of unconsolidated affiliates
—
—
—
1
(3)
—
(2)
Net income (loss)
390
271
254
269
(756)
(217)
211
Net income attributable to noncontrolling interests
—
—
—
—
98
1
99
Net income (loss) attributable to common shareholders
$
390
$
271
$
254
$
269
$
(854)
$
(218)
$
112
Six Months Ended June 30, 2020
Operating revenues
$
2,856
$
1,493
$
1,554
$
2,187
$
8,613
$
(634)
$
16,069
Operating expenses
Purchased power and fuel
951
499
483
810
4,646
(598)
6,791
Operating and maintenance
853
492
376
538
2,451
(73)
4,637
Depreciation and amortization
547
173
272
385
604
42
2,023
Taxes other than income taxes
146
78
132
222
246
23
847
Total operating expenses
2,497
1,242
1,263
1,955
7,947
(606)
14,298
Gain (loss) on sales of assets and businesses
—
—
—
2
12
(1)
13
Operating income
359
251
291
234
678
(29)
1,784
Other income and (deductions)
Interest expense, net
(192)
(71)
(64)
(134)
(197)
(179)
(837)
Other, net
22
7
10
26
(168)
35
(68)
Total other income and (deductions)
(170)
(64)
(54)
(108)
(365)
(144)
(905)
Income (loss) before income taxes
189
187
237
126
313
(173)
879
Income taxes
82
9
18
(76)
(59)
(49)
(75)
Equity in losses of unconsolidated affiliates
—
—
—
—
(4)
—
(4)
Net income (loss)
107
178
219
202
368
(124)
950
Net loss attributable to noncontrolling interests
—
—
—
—
(153)
—
(153)
Net income (loss) attributable to common shareholders
$
107
$
178
$
219
$
202
$
521
$
(124)
$
1,103
Change in Net income from 2020 to 2021
$
283
$
93
$
35
$
67
$
(1,375)
$
(94)
$
(991)
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(a)Other primarily includes eliminating and consolidating adjustments, Exelon’s corporate operations, shared service entities, and other financing and investment activities.
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 2021 and 2020 ranged from 25.0% to 29.0%. Under IRS regulations, NDT fund investment returns are taxed at different rates for investments if they are in qualified or non-qualified funds. The effective tax rates for the unrealized gains and losses related to NDT fund investments were 50.6% and 47.4% for the three months ended June 30, 2021 and 2020, respectively.
(a)Other primarily includes eliminating and consolidating adjustments, Exelon’s corporate operations, shared service entities, and other financing and investment activities.
(b)For ComEd, BGE, Pepco, and DPL Maryland, customer rates are adjusted to eliminate the impacts of weather and customer usage on distribution volumes.
(c)For regulatory recovery mechanisms, including ComEd’s distribution formula rate, ComEd, PECO, BGE, and PHI utilities transmission formula rates, and riders across all utilities, revenues increase and decrease i) as fully recoverable costs fluctuate (with no impact on net earnings), and ii) pursuant to changes in rate base, capital structure and ROE (which impact net earnings).
(1)Reflects the impact of net unrealized gains on Generation’s NDT fund investments for Non-Regulatory Agreement Units.
(2)In 2020, reflects an impairment at ComEd related to the acquisition of transmission assets and the impairment of certain wind assets at Generation. In 2021, reflects an impairment in the New England asset group and an impairment recorded as a result of the agreement to sell the Albany Green Energy biomass facility.
(3)In 2020, primarily reflects accelerated depreciation and amortization expenses associated with the early retirement of certain fossil sites. In 2021, primarily reflects accelerated depreciation and amortization associated with Generation's decision in the third quarter of 2020 to early retire Byron and Dresden nuclear facilities in 2021 and Mystic Units 8 and 9 in 2024.
(4)Primarily represents reorganization costs related to cost management programs.
(5)Represents direct costs related to COVID-19 consisting primarily of costs to acquire personal protective equipment, costs for cleaning supplies and services, and costs to hire healthcare professionals to monitor the health of employees.
(6)Reflects the payments made by ComEd under the Deferred Prosecution Agreement, which ComEd entered in July 2020 with the U.S. Attorney’s Office for the Northern District of Illinois.
(7)Represents elimination from Generation’s results of the noncontrolling interests related to certain exclusion items, primarily related to unrealized gains and losses on NDT fund investments for CENG units.
(8)Reflects costs related to the acquisition of Electricite de France SA's (EDF's) interest in CENG.
(9)Reflects costs related to a multi-year Enterprise Resource Program (ERP) system implementation.
(10)Represents costs related to the planned separation primarily comprised of system-related costs, third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the planned separation, and employee-related severance costs.
(11)Decommissioning-related activities for the former ComEd and PECO units (Regulatory Agreement Units), net of applicable taxes, including realized and unrealized gains and losses on the NDT funds, depreciation of the ARC, and accretion of the decommissioning obligation, are generally offset within Exelon’s and Generation’s consolidated statements of operations. These costs reflect the impact of suspension of contractual offset for the Byron units in the second quarter of 2021.
(12)For ComEd, reflects increased electric distribution and energy efficiency revenues (due to higher rate base, higher electric distribution ROE due to increased treasury rates, and higher fully recoverable costs). For PHI, reflects increased revenue primarily due to rate increases. For BGE and PHI, primarily reflects an increase in revenue as a result of the reduction in revenue in 2020 due to the settlement agreement of ongoing transmission related income tax regulatory liabilities. For BGE, also reflects increased distribution revenue due to customer growth. For PHI, also reflects increased revenue primarily due to distribution and transmission rate increases.
(13)Primarily reflects a decrease in fuel prices.
(14)Reflects increased capacity revenues in the Mid-Atlantic and New York, partially offset by decreased revenues in the Midwest and Other Power Regions.
(15)Primarily reflects an increase in New York ZEC revenues due to higher generation and an increase in ZEC prices and higher gas revenues, net of fuel costs, due to higher natural gas prices.
(17)Primarily reflects a decrease in the number of nuclear outage days in 2021, excluding Salem.
(18)For PECO, primarily reflects the absence of costs in 2021 due to the June 2020 storms. For PECO and PHI, also reflects lower credit loss expense in 2021 due to an increase in 2020 as a result of COVID-19. For Generation, primarily reflects a decrease in nuclear outage days at Salem in 2021.
(19)Reflects ongoing capital expenditures across all utilities. For ComEd, also reflects increased amortization of deferred energy efficiency costs pursuant to FEJA and increased amortization related to the August 2020 storm regulatory asset.
(20)For PECO, primarily reflects an increase in the tax repairs deduction. For BGE and PHI, primarily reflects the absence of the impacts associated with the prior year settlement agreement of ongoing transmission related income tax regulatory liabilities, partially offset at BGE due to the multi-year plan which resulted in the acceleration of certain income tax benefits. For Corporate, primarily reflects the reversal of part of the tax expense recorded in the first quarter, due to the loss before income taxes at Generation due to the February 2021 extreme cold weather event.
(21)Reflects elimination from Generation’s results of activity attributable to noncontrolling interests, primarily for CENG.
(22)For Generation, primarily reflects net unrealized and realized gains on equity investments and higher realized NDT fund gains.
Unless otherwise noted, the income tax impact of each reconciling item between GAAP Net Income and Adjusted (non-GAAP) Operating Earnings is based on the marginal statutory federal and state income tax rates for each Registrant, taking into account whether the income or expense item is taxable or deductible, respectively, in whole or in part. For all items except the unrealized losses related to NDT fund investments, the marginal statutory income tax rates for 2021 and 2020 ranged from 25.0% to 29.0%. Under IRS regulations, NDT fund investment returns are taxed at different rates for investments if they are in qualified or non-qualified funds. The effective tax rates for the unrealized gains and losses related to NDT fund investments were 51.7% and 41.9% for the six months ended June 30, 2021 and 2020, respectively.
(a)Other primarily includes eliminating and consolidating adjustments, Exelon’s corporate operations, shared service entities, and other financing and investment activities.
(b)For ComEd, BGE, Pepco, and DPL Maryland, customer rates are adjusted to eliminate the impacts of weather and customer usage on distribution volumes.
(c)For regulatory recovery mechanisms, including ComEd’s distribution formula rate, ComEd, PECO, BGE, and PHI utilities transmission formula rates, and riders across all utilities, revenues increase and decrease i) as fully recoverable costs fluctuate (with no impact on net earnings), and ii) pursuant to changes in rate base, capital structure and ROE (which impact net earnings).
(1)Reflects the impact of net unrealized gains and losses on Generation’s NDT fund investments for Non-Regulatory Agreement Units.
(2)In 2020, reflects an impairment at ComEd related to the acquisition of transmission assets and the impairment of certain wind assets at Generation. In 2021, reflects an impairment in the New England asset group and an impairment recorded as a result of the agreement to sell the Albany Green Energy biomass facility.
(3)In 2020, primarily reflects accelerated depreciation and amortization expenses associated with the early retirement of certain fossil sites. In 2021, primarily reflects accelerated depreciation and amortization associated with Generation's decision in the third quarter of 2020 to early retire Byron and Dresden nuclear facilities in 2021 and Mystic Units 8 and 9 in 2024, partially offset by a gain on sale of Generation's solar business.
(4)Primarily represents reorganization costs related to cost management programs.
(5)Represents direct costs related to COVID-19 consisting primarily of costs to acquire personal protective equipment, costs for cleaning supplies and services, and costs to hire healthcare professionals to monitor the health of employees.
(6)Reflects the payments made by ComEd under the Deferred Prosecution Agreement, which ComEd entered in July 2020 with the U.S. Attorney’s Office for the Northern District of Illinois.
(7)Represents elimination from Generation’s results of the noncontrolling interests related to certain exclusion items, primarily related to unrealized gains and losses on NDT fund investments for CENG units.
(8)Reflects costs related to the acquisition of Electricite de France SA's (EDF's) interest in CENG.
(9)Reflects costs related to a multi-year Enterprise Resource Program (ERP) system implementation.
(10)Represents costs related to the planned separation primarily comprised of system-related costs, third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the planned separation, and employee-related severance costs.
(11)Decommissioning-related activities for the former ComEd and PECO units (Regulatory Agreement Units), net of applicable taxes, including realized and unrealized gains and losses on the NDT funds, depreciation of the ARC, and accretion of the decommissioning obligation, are generally offset within Exelon’s and Generation’s consolidated statements of operations. These costs reflect the impact of suspension of contractual offset for the Byron units in the second quarter of 2021.
(12)For ComEd, reflects increased electric distribution and energy efficiency revenues (due to higher rate base, higher electric distribution ROE due to increased treasury rates, and higher fully recoverable costs). For PHI, reflects increased revenue primarily due to rate increases. For BGE and PHI, primarily reflects an increase in revenue as a result of the reduction in revenue in 2020 due to the settlement agreement of ongoing transmission related income tax regulatory liabilities. For BGE, also reflects increased distribution revenue due to customer growth. For PHI, also reflects increased revenue primarily due to distribution and transmission rate increases.
(13)Primarily reflects a decrease in nuclear outage days at Salem.
(14)Primarily reflects a decrease in fuel prices.
(15)Reflects increased capacity revenues in the Mid-Atlantic and New York, partially offset by decreased revenues in the Midwest and Other Power Regions.
(16)Primarily reflects the impacts of the February 2021 extreme cold weather event, partially offset by an increase in New York ZEC revenues due to higher generation and an increase in ZEC prices and higher gas revenues, net of fuel costs, due to higher natural gas prices.
(18)Primarily reflects a decrease in the number of nuclear outage days in 2021, excluding Salem.
(19)For PECO, primarily reflects the absence of costs in 2021 due to the June 2020 storms. For PECO and PHI, also reflects lower credit loss expense in 2021 due to an increase in 2020 as a result of COVID-19. For Generation, reflects increased credit loss expense primarily due to the impacts of the February 2021 extreme cold weather event, partially offset by a decrease in planned nuclear outage days at Salem in 2021.
(20)Reflects ongoing capital expenditures across all utilities. For ComEd, also reflects increased amortization of deferred energy efficiency costs pursuant to FEJA and increased amortization related to the August 2020 storm regulatory asset.
(21)For PECO, primarily reflects an increase in the tax repairs deduction. For BGE, primarily due to the multi-year plan which resulted in the acceleration of certain income tax benefits, partially offset by the absence of the impacts associated with the prior year settlement agreement of ongoing transmission related income tax regulatory liabilities. For PHI, reflects the absence of the impacts associated with the prior year settlement agreement of ongoing transmission related income tax regulatory liabilities. For Generation and Corporate, primarily reflects the timing of tax expense driven primarily by the loss before income taxes at Generation due to the February 2021 extreme cold weather event. These timing impacts will continue to reverse by the end of the year. For Generation, also reflects the absence of a prior year one-time tax settlement.
(22)Reflects elimination from Generation’s results of activity attributable to noncontrolling interests, primarily for CENG.
(23)For Generation, primarily reflects higher realized NDT fund gains and net unrealized and realized gains on equity investments.
Net income attributable to noncontrolling interests
75
(50)
(l)
53
(103)
(l)
Net income attributable to common shareholders
$
401
$
521
Effective tax rate(p)
13.4
%
27.6
%
Earnings per average common share
Basic
$
0.41
$
0.53
Diluted
$
0.41
$
0.53
Average common shares outstanding
Basic
978
976
Diluted
979
976
__________
(a)Results reported in accordance with accounting principles generally accepted in the United States (GAAP).
(b)Adjustment to exclude the mark-to-market impact of Exelon’s economic hedging activities, net of intercompany eliminations.
(c)In 2021, adjustment to exclude costs associated with Generation's decision in the third quarter of 2020 to early retire Byron and Dresden nuclear facilities in 2021 and Mystic Units 8 and 9 in 2024. In 2020, adjustment to exclude accelerated depreciation and amortization expenses associated with the early retirement of certain fossil sites.
(d)Adjustment to exclude reorganization costs related to cost management programs.
(e)In 2021, adjustment to exclude an impairment in the New England asset group and an impairment recorded as a result of the agreement to sell the Albany Green Energy biomass facility. In 2020, adjustment to exclude an impairment at ComEd related to the acquisition of transmission assets and the impairment of certain wind assets at Generation.
(f)Adjustment to exclude direct costs related to COVID-19 consisting primarily of costs to acquire personal protective equipment, costs for cleaning supplies and services, and costs to hire healthcare professionals to monitor the health of employees.
(g)Adjustment to exclude costs related to the acquisition of Electricite de France SA's (EDF's) interest in CENG.
(h)Adjustment to exclude costs related to a multi-year Enterprise Resource Program (ERP) system implementation.
(i)Adjustment to exclude costs related to the planned separation primarily comprised of system-related costs, third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the planned separation, and employee-related severance costs.
(j)Adjustment to exclude the impact of suspension of contractual offset for the Byron units in the second quarter of 2021.
(k)Adjustment to exclude the impact of net unrealized gains on Generation’s NDT fund investments for Non-Regulatory Agreement Units.
(l)Adjustment to exclude elimination from Generation’s results of the noncontrolling interests related to certain exclusion items, primarily related to unrealized gains and losses on NDT fund investments for CENG units.
(m)Adjustment to exclude changes in environmental liabilities.
(n)Adjustment to exclude the payments made by ComEd under the Deferred Prosecution Agreement, which ComEd entered in July 2020 with the U.S. Attorney’s Office for the Northern District of Illinois.
(o)Adjustment to exclude income tax related adjustments.
(p)The effective tax rate related to Adjusted (non-GAAP) Operating Earnings is 12.3% and (9.7)% for the three months ended June 30, 2021 and 2020, respectively.
Net income (loss) attributable to noncontrolling interests
99
(32)
(m)
(153)
42
(m)
Net income attributable to common shareholders
$
112
$
1,103
Effective tax rate(p)
20.5
%
(8.5)
%
Earnings per average common share
Basic
$
0.11
$
1.13
Diluted
$
0.11
$
1.13
Average common shares outstanding
Basic
978
975
Diluted
979
976
__________
(a)Results reported in accordance with accounting principles generally accepted in the United States (GAAP).
(b)Adjustment to exclude the mark-to-market impact of Exelon’s economic hedging activities, net of intercompany eliminations.
(c)In 2021, adjustment to exclude costs associated with Generation's decision in the third quarter of 2020 to early retire Byron and Dresden nuclear facilities in 2021 and Mystic Units 8 and 9 in 2024, partially offset by a gain on sale of Generation's solar business. In 2020, adjustment to exclude accelerated depreciation and amortization expenses associated with the early retirement of certain fossil sites.
(d)Adjustment to exclude reorganization costs related to cost management programs.
(e)In 2021, adjustment to exclude an impairment in the New England asset group and an impairment recorded as a result of the agreement to sell the Albany Green Energy biomass facility. In 2020, adjustment to exclude an impairment at ComEd related to the acquisition of transmission assets and the impairment of certain wind assets at Generation.
(f)Adjustment to exclude direct costs related to COVID-19 consisting primarily of costs to acquire personal protective equipment, costs for cleaning supplies and services, and costs to hire healthcare professionals to monitor the health of employees.
(g)Adjustment to exclude costs related to the acquisition of Electricite de France SA's (EDF's) interest in CENG.
(h)Adjustment to exclude costs related to a multi-year Enterprise Resource Program (ERP) system implementation.
(i)Adjustment to exclude costs related to the planned separation primarily comprised of system-related costs, third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the planned separation, and employee-related severance costs.
(j)Adjustment to exclude the impact of suspension of contractual offset for the Byron units in the second quarter of 2021.
(k)Adjustment to exclude changes in environmental liabilities.
(l)Adjustment to exclude the impact of net unrealized gains and losses on Generation’s NDT fund investments for Non-Regulatory Agreement Units.
(m)Adjustment to exclude elimination from Generation’s results of the noncontrolling interests related to certain exclusion items, primarily related to unrealized gains and losses on NDT fund investments for CENG units.
(n)Adjustment to exclude the payments made by ComEd under the Deferred Prosecution Agreement, which ComEd entered in July 2020 with the U.S. Attorney’s Office for the Northern District of Illinois.
(o)Adjustment to exclude income tax related adjustments.
(p)The effective tax rate related to Adjusted (non-GAAP) Operating Earnings is 19.8% and 3.3% for the six months ended June 30, 2021 and 2020, respectively.
(a)Results reported in accordance with accounting principles generally accepted in the United States (GAAP).
(b)Adjustment to exclude an impairment related to the acquisition of transmission assets.
(c)Adjustment to exclude the payments made by ComEd under the Deferred Prosecution Agreement, which ComEd entered in July 2020 with the U.S. Attorney’s Office for the Northern District of Illinois.
(d)Represents costs related to the planned separation primarily comprised of system-related costs, third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the planned separation, and employee-related severance costs.
(a)Results reported in accordance with accounting principles generally accepted in the United States (GAAP).
(b)Adjustment to exclude direct costs related to COVID-19 consisting primarily of costs to acquire personal protective equipment, costs for cleaning supplies and services, and costs to hire healthcare professionals to monitor the health of employees.
(c)Represents costs related to the planned separation primarily comprised of system-related costs, third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the planned separation, and employee-related severance costs.
(d)Adjustment to exclude costs related to a multi-year Enterprise Resource Program (ERP) system implementation.
(e)Adjustment to exclude reorganization costs related to cost management programs.
(a)Results reported in accordance with accounting principles generally accepted in the United States (GAAP).
(b)Adjustment to exclude direct costs related to COVID-19 consisting primarily of costs to acquire personal protective equipment, costs for cleaning supplies and services, and costs to hire healthcare professionals to monitor the health of employees.
(c)Adjustment to exclude costs related to the planned separation primarily comprised of system-related costs, third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the planned separation, and employee-related severance costs.
(d)Adjustment to exclude costs related to a multi-year Enterprise Resource Program (ERP) system implementation.
(e)Adjustment to exclude reorganization costs related to cost management programs.
(a)Results reported in accordance with accounting principles generally accepted in the United States (GAAP).
(b)Adjustment to exclude costs related to a multi-year Enterprise Resource Program (ERP) system implementation.
(c)Adjustment to exclude costs related to the planned separation primarily comprised of system-related costs, third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the planned separation, and employee-related severance costs.
(d)Adjustment to exclude reorganization costs related to cost management programs.
(e)Adjustment to exclude direct costs related to COVID-19 consisting primarily of costs to acquire personal protective equipment, costs for cleaning supplies and services, and costs to hire healthcare professionals to monitor the health of employees.
(b)Adjustment to exclude the mark-to-market impact of Exelon’s economic hedging activities, net of intercompany eliminations.
(c)In 2021, adjustment to exclude costs associated with Generation's decision in the third quarter of 2020 to early retire Byron and Dresden nuclear facilities in 2021 and Mystic Units 8 and 9 in 2024, partially offset by a gain on sale of Generation's solar business. In 2020, adjustment to exclude accelerated depreciation and amortization expenses associated with the early retirement of certain fossil sites.
(d)Adjustment to exclude reorganization costs related to cost management programs.
(e)In 2021, adjustment to exclude an impairment in the New England asset group and an impairment recorded as a result of the agreement to sell the Albany Green Energy biomass facility. In 2020, adjustment to exclude the impairment of certain wind assets at Generation.
(f)Adjustment to exclude direct costs related to COVID-19 consisting primarily of costs to acquire personal protective equipment, costs for cleaning supplies and services, and costs to hire healthcare professionals to monitor the health of employees.
(g)Adjustment to exclude costs related to the acquisition of Electricite de France SA's (EDF's) interest in CENG.
(h)Adjustment to exclude costs related to a multi-year Enterprise Resource Program (ERP) system implementation.
(i)Adjustment to exclude costs related to the planned separation primarily comprised of system-related costs, third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the planned separation, and employee-related severance costs.
(j)Adjustment to exclude the impact of suspension of contractual offset for the Byron units in the second quarter of 2021.
(k)Adjustment to exclude changes in environmental liabilities.
(l)Adjustment to exclude the impact of net unrealized gains and losses on Generation’s NDT fund investments for Non-Regulatory Agreement Units.
(m)Adjustment to exclude elimination from Generation’s results of the noncontrolling interests related to certain exclusion items, primarily related to unrealized gains and losses on NDT fund investments for CENG units.
Net income attributable to noncontrolling interests
1
—
Net loss attributable to common shareholders
$
(20)
$
(66)
Six Months Ended June 30, 2021
Six Months Ended June 30, 2020
GAAP (b)
Non-GAAP Adjustments
GAAP (b)
Non-GAAP Adjustments
Operating revenues
$
(581)
$
—
$
(634)
$
—
Operating expenses
Purchased power and fuel
(545)
—
(598)
—
Operating and maintenance
(35)
(6)
(c)
(73)
3
(f)
Depreciation and amortization
35
—
42
—
Taxes other than income taxes
25
—
23
—
Total operating expenses
(520)
(606)
Gain on sales of assets
4
—
(1)
—
Operating loss
(57)
(29)
Other income and (deductions)
Interest expense, net
(161)
—
(179)
27
(d),(e)
Other, net
45
2
(d)
35
—
Total other income and (deductions)
(116)
(144)
Loss before income taxes
(173)
(173)
Income taxes
44
5
(c),(d),(e)
(49)
12
(d),(e),(f)
Net loss
(217)
(124)
Net income attributable to noncontrolling interests
1
—
Net loss attributable to common shareholders
$
(218)
$
(124)
__________
(a)Other primarily includes eliminating and consolidating adjustments, Exelon’s corporate operations, shared service entities, and other financing and investment activities.
(b)Results reported in accordance with accounting principles generally accepted in the United States (GAAP).
(c)Adjustment to exclude costs related to the planned separation primarily comprised of system-related costs, third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the planned separation, and employee-related severance costs.
(d)Adjustment to exclude the mark-to-market impact of Exelon’s economic hedging activities, net of intercompany eliminations.
(e)Adjustment to exclude income tax-related adjustments.
(f)Adjustment to exclude reorganization costs related to cost management programs.
(a)Reflects revenues from customers purchasing electricity directly from ComEd and customers purchasing electricity from a competitive electric generation supplier, as all customers are assessed delivery charges. For customers purchasing electricity from ComEd, revenues also reflect the cost of energy and transmission.
(b)Includes transmission revenue from PJM, wholesale electric revenue, and mutual assistance revenue.
(c)Includes operating revenues from affiliates totaling $5 million and $11 million for the three months ended June 30, 2021 and 2020, respectively, and $11 million and $16 million for the six months ended June 30, 2021 and 2020, respectively.
(d)Includes alternative revenue programs and late payment charges.
Rate-Regulated Electric Deliveries and Revenues(a)
Residential
6,883
6,397
7.6
%
2.5
%
$
816
$
759
7.5
%
Small commercial & industrial
3,639
3,476
4.7
%
1.9
%
199
187
6.4
%
Large commercial & industrial
6,747
6,602
2.2
%
1.4
%
116
108
7.4
%
Public authorities & electric railroads
270
263
2.7
%
2.7
%
17
14
21.4
%
Other(b)
—
—
n/a
n/a
106
113
(6.2)
%
Total rate-regulated electric revenues(c)
17,539
16,738
4.8
%
1.9
%
1,254
1,181
6.2
%
Other Rate-Regulated Revenues(d)
17
8
112.5
%
Total Electric Revenues
1,271
1,189
6.9
%
Natural Gas (in mmcfs)
Rate-Regulated Natural Gas Deliveries and Revenues(e)
Residential
25,701
23,746
8.2
%
0.2
%
215
220
(2.3)
%
Small commercial & industrial
13,291
10,863
22.4
%
10.7
%
81
70
15.7
%
Large commercial & industrial
9
12
(25.0)
%
11.1
%
—
—
N/A
Transportation
13,118
12,283
6.8
%
3.6
%
12
12
—
%
Other(f)
—
—
n/a
n/a
3
2
50.0
%
Total rate-regulated natural gas revenues(g)
52,119
46,904
11.1
%
3.6
%
311
304
2.3
%
Other Rate-Regulated Revenues(d)
—
—
100.0
%
Total Natural Gas Revenues
311
304
2.3
%
Total Electric and Natural Gas Revenues
$
1,582
$
1,493
6.0
%
Purchased Power and Fuel
$
523
$
499
4.8
%
% Change
Heating and Cooling Degree-Days
2021
2020
Normal
From 2020
From Normal
Heating Degree-Days
2,706
2,557
2,840
5.8
%
(4.7)
%
Cooling Degree-Days
423
376
389
12.5
%
8.7
%
Number of Electric Customers
2021
2020
Number of Natural Gas Customers
2021
2020
Residential
1,513,456
1,501,259
Residential
494,895
489,201
Small commercial & industrial
154,842
154,016
Small commercial & industrial
44,450
44,189
Large commercial & industrial
3,108
3,096
Large commercial & industrial
6
6
Public authorities & electric railroads
10,285
10,119
Transportation
677
719
Total
1,681,691
1,668,490
Total
540,028
534,115
__________
(a)Reflects delivery volumes and revenues from customers purchasing electricity directly from PECO and customers purchasing electricity from a competitive electric generation supplier as all customers are assessed distribution charges. For customers purchasing electricity from PECO, revenues also reflect the cost of energy and transmission.
(b)Includes transmission revenue from PJM, wholesale electric revenue, and mutual assistance revenue.
(c)Includes operating revenues from affiliates totaling $1 million and $1 million for the three months ended June 30, 2021 and 2020, and $3 million and $3 million for the six months ended June 30, 2021 and 2020 respectively.
(d)Includes alternative revenue programs and late payment charges.
(e)Reflects delivery volumes and revenues from customers purchasing natural gas directly from PECO and customers purchasing natural gas from a competitive natural gas supplier as all customers are assessed distribution charges. For customers purchasing natural gas from PECO, revenue also reflects the cost of natural gas.
(f)Includes revenues primarily from off-system sales.
(g)Includes operating revenues from affiliates totaling less than $1 million for both the three months ended June 30, 2021 and 2020, and $1 million and less than $1 million for the six months ended June 30, 2021 and 2020, respectively.
Rate-Regulated Electric Deliveries and Revenues(a)
Residential
6,310
5,888
7.2
%
1.0 %
$
662
$
644
2.8
%
Small commercial & industrial
1,350
1,279
5.6
%
1.3 %
129
118
9.3
%
Large commercial & industrial
6,300
6,077
3.7
%
1.0 %
213
198
7.6
%
Public authorities & electric railroads
97
106
(8.5)
%
(7.7)
%
13
14
(7.1)
%
Other(b)
—
—
n/a
n/a
165
154
7.1
%
Total rate-regulated electric revenues(c)
14,057
13,350
5.3
%
0.9 %
1,182
1,128
4.8
%
Other Rate-Regulated Revenues(d)
8
(10)
(180.0)
%
Total Electric Revenues
1,190
1,118
6.4
%
Natural Gas (in mmcfs)
Rate-Regulated Natural Gas Deliveries and Revenues(e)
Residential
23,399
23,873
(2.0)
%
(12.0)
%
297
287
3.5
%
Small commercial & industrial
5,324
5,378
(1.0)
%
(9.2)
%
48
46
4.3
%
Large commercial & industrial
22,263
20,265
9.9
%
4.4 %
81
76
6.6
%
Other(f)
8,512
3,678
131.4
%
n/a
36
13
176.9
%
Total rate-regulated natural gas revenues(g)
59,498
53,194
11.9
%
(5.4)
%
462
422
9.5
%
Other Rate-Regulated Revenues(d)
4
14
(71.4)
%
Total Natural Gas Revenues
466
436
6.9
%
Total Electric and Natural Gas Revenues
$
1,656
$
1,554
6.6
%
Purchased Power and Fuel
$
550
$
483
13.9
%
% Change
Heating Degree-Days
2021
2020
Normal
From 2020
From Normal
Heating Degree-Days
2,666
2,429
2,884
9.8
%
(7.6)
%
Cooling Degree-Days
300
247
260
21.5
%
15.4
%
Number of Electric Customers
2021
2020
Number of Natural Gas Customers
2021
2020
Residential
1,192,135
1,185,718
Residential
647,534
643,745
Small commercial & industrial
114,682
114,118
Small commercial & industrial
38,223
38,255
Large commercial & industrial
12,528
12,416
Large commercial & industrial
6,132
6,079
Public authorities & electric railroads
267
264
Total
691,889
688,079
Total
1,319,612
1,312,516
__________
(a)Reflects revenues from customers purchasing electricity directly from BGE and customers purchasing electricity from a competitive electric generation supplier as all customers are assessed distribution charges. For customers purchasing electricity from BGE, revenues also reflect the cost of energy and transmission.
(b)Includes transmission revenue from PJM, wholesale electric revenue, and mutual assistance revenue.
(c)Includes operating revenues from affiliates totaling $4 million and $3 million for the three months ended June 30, 2021 and 2020, respectively, and $6 million for both the six months ended June 30, 2021 and 2020.
(d)Includes alternative revenue programs and late payment charges.
(e)Reflects delivery volumes and revenues from customers purchasing natural gas directly from BGE and customers purchasing natural gas from a competitive natural gas supplier as all customers are assessed distribution charges. For customers purchasing natural gas from BGE, revenue also reflects the cost of natural gas.
(f)Includes revenues primarily from off-system sales.
(g)Includes operating revenues from affiliates totaling $3 million and $1 million for the three months ended June 30, 2021 and 2020, respectively, and $7 million and $4 million for the six months ended June 30, 2021 and 2020, respectively.
(a)Reflects revenues from customers purchasing electricity directly from Pepco and customers purchasing electricity from a competitive electric generation supplier as all customers are assessed distribution charges. For customers purchasing electricity from Pepco, revenues also reflect the cost of energy and transmission.
(b)Includes transmission revenue from PJM, wholesale electric revenue, and mutual assistance revenue.
(c)Includes operating revenues from affiliates totaling $1 million for both the three months ended June 30, 2021 and 2020, and $3 million for both the six months ended June 30, 2021 and 2020.
(d)Includes alternative revenue programs and late payment charge revenues.
Rate-Regulated Electric Deliveries and Revenues(a)
Residential
2,651
2,453
8.1
%
3.3
%
$
337
$
308
9.4
%
Small commercial & industrial
1,116
960
16.3
%
14.1
%
92
82
12.2
%
Large commercial & industrial
1,985
2,121
(6.4)
%
(7.2)
%
43
45
(4.4)
%
Public authorities & electric railroads
24
22
9.1
%
9.6
%
7
6
16.7
%
Other(b)
—
—
n/a
n/a
87
105
(17.1)
%
Total rate-regulated electric revenues(c)
5,776
5,556
4.0
%
1.3
%
566
546
3.7
%
Other Rate-Regulated Revenues(d)
19
(23)
(182.6)
%
Total Electric Revenues
585
523
11.9
%
Natural Gas (in mmcfs)
Rate-Regulated Natural Gas Deliveries and Revenues(e)
Residential
5,107
4,815
6.1
%
(2.0)
%
57
57
—
%
Small commercial & industrial
2,295
2,228
3.0
%
(4.3)
%
24
25
(4.0)
%
Large commercial & industrial
853
863
(1.2)
%
(1.5)
%
3
2
50.0
%
Transportation
3,694
3,580
3.2
%
0.7
%
8
7
14.3
%
Other(f)
—
—
n/a
n/a
3
3
—
%
Total rate-regulated natural gas revenues
11,949
11,486
4.0
%
(1.6)
%
95
94
1.1
%
Other Rate-Regulated Revenues(d)
—
—
n/a
Total Natural Gas Revenues
95
94
1.1
%
Total Electric and Natural Gas Revenues
$
680
$
617
10.2
%
Purchased Power and Fuel
$
263
$
249
5.6
%
Electric Service Territory
% Change
Heating and Cooling Degree-Days
2021
2020
Normal
From 2020
From Normal
Heating Degree-Days
2,730
2,504
2,877
9.0
%
(5.1)
%
Cooling Degree-Days
378
320
345
18.1
%
9.6
%
Natural Gas Service Territory
% Change
Heating Degree-Days
2021
2020
Normal
From 2020
From Normal
Heating Degree-Days
2,838
2,609
2,987
8.8
%
(5.0)
%
Number of Electric Customers
2021
2020
Number of Natural Gas Customers
2021
2020
Residential
475,061
470,788
Residential
127,503
126,245
Small commercial & industrial
62,880
61,958
Small commercial & industrial
9,953
9,914
Large commercial & industrial
1,213
1,402
Large commercial & industrial
18
17
Public authorities & electric railroads
607
612
Transportation
158
159
Total
539,761
534,760
Total
137,632
136,335
__________
(a)Reflects delivery volumes and revenues from customers purchasing electricity directly from DPL and customers purchasing electricity from a competitive electric generation supplier as all customers are assessed distribution charges. For customers purchasing electricity from DPL, revenues also reflect the cost of energy and transmission.
(b)Includes transmission revenue from PJM, wholesale electric revenue, and mutual assistance revenue.
(c)Includes operating revenues from affiliates totaling $2 million for both the three months ended June 30, 2021 and 2020, and $4 million for both the six months ended June 30, 2021 and 2020.
(d)Includes alternative revenue programs and late payment charges.
(e)Reflects delivery volumes and revenues from customers purchasing natural gas directly from DPL and customers purchasing natural gas from a competitive natural gas supplier as all customers are assessed distribution charges. For customers purchasing natural gas from DPL, revenue also reflects the cost of natural gas.
(f)Includes revenues primarily from off-system sales.
(a)Reflects delivery volumes and revenues from customers purchasing electricity directly from ACE and customers purchasing electricity from a competitive electric generation supplier as all customers are assessed distribution charges. For customers purchasing electricity from ACE, revenues also reflect the cost of energy and transmission.
(b)Includes transmission revenue from PJM, wholesale electric revenue, and mutual assistance revenue.
(c)Includes operating revenues from affiliates totaling $1 million for both the three months ended June 30, 2021 and 2020, and $1 million for both the six months ended June 30, 2021 and 2020.
(a)Includes the proportionate share of output where Generation has an undivided ownership interest in jointly-owned generating plants and includes the total output of plants that are fully consolidated (e.g. CENG).
(b)Other Power Regions includes New England, South, West, and Canada.
(c)Includes affiliate sales to PECO, BGE, Pepco, DPL, and ACE in the Mid-Atlantic region and affiliate sales to ComEd in the Midwest region.
