0001109357-22-000059 | 10-Q | XBRL Viewer

$ 29

$ 129

5,327

4,632

159

293

1,178

1,083

817

757

354

317

4,427

3,808

900

824

Interest expense to affiliates

(332)

(312)

(6)

137

(201)

(260)

699

564

Income (Loss) from Continuing Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest

218

481

525

Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest

117

(789)

Net income (loss) attributable to noncontrolling interests

598

(264)

Net Income (Loss) Available to Common Stockholders, Basic

597

(289)

Net Income (Loss) from Continuing Operations Available to Common Shareholders, Basic

481

525

Net Income (Loss) from Discontinued Operations Available to Common Shareholders, Basic

116

(814)

Other comprehensive income (loss), net of income taxes

Prior service benefit reclassified to periodic benefit cost

(1)

Actuarial loss reclassified to periodic benefit cost

Pension and non-pension postretirement benefit plan valuation adjustment

(2)

Unrealized gain (loss) on foreign currency translation

Other comprehensive income

Comprehensive income attributable to noncontrolling interests

612

(210)

Comprehensive income attributable to common shareholders/membership interest

$ 611

$ (235)

Average shares of common stock outstanding:

Basic average shares of common stock outstanding

981

977

Assumed exercise and/or distributions of stock-based awards

Diluted average shares of common stock outstanding

^[1]

981

978

Earnings per average common share from continuing operations

Income (Loss) from Continuing Operations, Per Basic Share

$ 0.49

$ 0.53

Income (Loss) from Continuing Operations, Per Diluted Share

0.49

0.53

Discontinued Operation, Income (Loss) from Discontinued Operation, Net of Tax, Per Basic Share

0.12

(0.83)

Discontinued Operation, Income (Loss) from Discontinued Operation, Net of Tax, Per Diluted Share

$ 0.12

$ (0.83)

Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount

Commonwealth Edison Co [Member]

$ 40

$ 54

1,734

1,535

266

245

321

292

1,406

1,210

328

325

Interest expense to affiliates

(97)

(93)

(3)

(88)

(89)

240

236

Other comprehensive income (loss), net of income taxes

188

197

188

197

PECO Energy Co [Member]

1,047

889

196

193

793

679

254

210

Interest expense to affiliates

(38)

(35)

(3)

(34)

(33)

220

177

Other comprehensive income (loss), net of income taxes

206

167

Baltimore Gas and Electric Company [Member]

206

167

(12)

1,154

974

167

152

171

152

919

752

235

222

(35)

(34)

(28)

(26)

207

196

(13)

Other comprehensive income (loss), net of income taxes

198

209

Pepco Holdings LLC [Member]

198

209

(5)

1,404

1,244

248

216

218

210

119

113

1,215

1,058

189

186

(69)

(67)

(52)

(50)

137

136

Other comprehensive income (loss), net of income taxes

130

128

Comprehensive income attributable to common shareholders/membership interest

130

128

Potomac Electric Power Company [Member]

(7)

614

553

108

102

547

466

(36)

(34)

(23)

(22)

(2)

Other comprehensive income (loss), net of income taxes

Delmarva Power and Light Company [Member]

(1)

431

382

357

309

(16)

(15)

(14)

(12)

Other comprehensive income (loss), net of income taxes

Atlantic City Electric Company [Member]

349

310

311

282

(14)

(15)

(11)

(14)

Other comprehensive income (loss), net of income taxes

Generation commodities and services

Revenue from Contract with Customer, Including Assessed Tax

4,481

3,870

Natural gas operating revenues

1,581

1,140

Revenue from Contract with Customer, Including Assessed Tax

817

633

Electricity, US Regulated

338

218

Revenue from Contract with Customer, Including Assessed Tax

4,522

3,991

Electricity, US Regulated | Commonwealth Edison Co [Member]

Revenue from Contract with Customer, Including Assessed Tax

1,688

1,475

Electricity, US Regulated | PECO Energy Co [Member]

579

442

Revenue from Contract with Customer, Including Assessed Tax

734

649

Electricity, US Regulated | Baltimore Gas and Electric Company [Member]

229

189

Revenue from Contract with Customer, Including Assessed Tax

735

620

Electricity, US Regulated | Pepco Holdings LLC [Member]

285

162

Revenue from Contract with Customer, Including Assessed Tax

1,323

1,124

Electricity, US Regulated | Potomac Electric Power Company [Member]

487

348

Revenue from Contract with Customer, Including Assessed Tax

620

526

Electricity, US Regulated | Delmarva Power and Light Company [Member]

174

Revenue from Contract with Customer, Including Assessed Tax

348

300

Electricity, US Regulated | Atlantic City Electric Company [Member]

137

103

Revenue from Contract with Customer, Including Assessed Tax

345

298

Natural Gas, US Regulated

176

153

Revenue from Contract with Customer, Including Assessed Tax

805

641

Natural Gas, US Regulated | PECO Energy Co [Member]

Revenue from Contract with Customer, Including Assessed Tax

306

228

Natural Gas, US Regulated | Baltimore Gas and Electric Company [Member]

145

Revenue from Contract with Customer, Including Assessed Tax

424

330

Natural Gas, US Regulated | Pepco Holdings LLC [Member]

151

Revenue from Contract with Customer, Including Assessed Tax

Natural Gas, US Regulated | Delmarva Power and Light Company [Member]

Revenue from Contract with Customer, Including Assessed Tax

Significant Accounting Policies (All Registrants)

$ 42

$ 33

[1]	The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect were none and less than 1 million for the three months ended March 31, 2022 and 2021, respectively

Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Cash flows from operating activities
Net income (loss)	$ 598	$ (264)
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	1,024	2,104
Asset impairments	0	1
Gain on sales of assets and businesses	(10)	(71)
Deferred income taxes and amortization of investment tax credits	110	(142)
Net fair value changes related to derivatives	(59)	(178)
Net realized and unrealized (gains) losses on NDT funds	205	(118)
Net unrealized (gains) losses on equity investments	16	23
Other non-cash operating activities	232	(170)
Changes in assets and liabilities:
Accounts receivable	(711)	(372)
Inventories	125	77
Accounts payable and accrued expenses	291	(176)
Option premiums (paid) received, net	(39)	16
Collateral received (posted), net	1,142	273
Income taxes	77	113
Pension and non-pension postretirement benefit contributions	(574)	(537)
Other assets and liabilities	(645)	(1,840)
Net Cash Provided by (Used in) Operating Activities, Total	1,782	(1,261)
Cash flows from investing activities
Capital expenditures	(1,922)	(2,140)
Proceeds from NDT fund sales	488	2,908
Investment in NDT funds	(516)	(2,939)
Collection of deferred purchase price	169	1,574
Proceeds from Sale of Property Held-for-sale	16	680
Other investing activities	(54)	12
Net Cash Provided by (Used in) Investing Activities, Total	(1,819)	95
Cash flows from financing activities
Changes in short-term borrowings	(700)	597
Proceeds from short-term borrowings with maturities greater than 90 days	1,150	500
Repayments on short-term borrowings with maturities greater than 90 days	(350)	0
Issuance of long-term debt	4,301	1,705
Retirement of long-term debt	(6)	(79)
Dividends paid on common stock	(332)	(374)
Proceeds from employee stock plans	9	31
Transfer of cash, restricted cash, and cash equivalents to Constellation	(2,594)	0
Other financing activities	(62)	(46)
Net cash flows provided by financing activities	1,416	2,334
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Excluding Exchange Rate Effect, Total	1,379	1,168
Cash, restricted cash, and cash equivalents at beginning of period	1,619	1,166
Cash, restricted cash, and cash equivalents at end of period	2,998	2,334
Supplemental Cash Flow Information
Decrease in capital expenditures not paid	(322)	(324)
Increase in deferred purchase price	348	1,339
Increase in PPE related to ARO update	(335)	2
Exelon Generation Co L L C [Member]
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	207	1,346
Gain on sales of assets and businesses	9	(71)
Deferred income taxes and amortization of investment tax credits	(143)	(234)
Net fair value changes related to derivatives	(59)	(178)
Net realized and unrealized (gains) losses on NDT funds	205	(118)
Net unrealized (gains) losses on equity investments	16	23
Other non-cash operating activities	(36)	332
Cash flows from investing activities
Capital expenditures	(227)	(394)
Collection of deferred purchase price	169	1,574
Supplemental Cash Flow Information
Decrease in capital expenditures not paid	(128)	(37)
Increase in deferred purchase price	348	1,339
Increase in PPE related to ARO update	335	0
Commonwealth Edison Co [Member]
Cash flows from operating activities
Net income (loss)	188	197
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	321	292
Deferred income taxes and amortization of investment tax credits	54	63
Other non-cash operating activities	(9)	(9)
Changes in assets and liabilities:
Accounts receivable	(45)	23
Change in receivables from payables to affiliates, net	(42)	(15)
Inventories	3	(1)
Accounts payable and accrued expenses	(154)	(176)
Collateral received (posted), net	43	5
Income taxes	(2)	(23)
Pension and non-pension postretirement benefit contributions	(176)	(171)
Other assets and liabilities	(37)	(159)
Net Cash Provided by (Used in) Operating Activities, Total	144	26
Cash flows from investing activities
Capital expenditures	(617)	(613)
Other investing activities	7	7
Net Cash Provided by (Used in) Investing Activities, Total	(610)	(606)
Cash flows from financing activities
Changes in short-term borrowings	0	(188)
Issuance of long-term debt	750	700
Dividends paid on common stock	(144)	(127)
Contributions from parent	167	198
Other financing activities	(10)	(9)
Net cash flows provided by financing activities	763	574
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Excluding Exchange Rate Effect, Total	297	(6)
Cash, restricted cash, and cash equivalents at beginning of period	384	405
Cash, restricted cash, and cash equivalents at end of period	681	399
Supplemental Cash Flow Information
Decrease in capital expenditures not paid	(50)	(107)
PECO Energy Co [Member]
Cash flows from operating activities
Net income (loss)	206	167
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	92	86
Deferred income taxes and amortization of investment tax credits	14	6
Other non-cash operating activities	15	12
Changes in assets and liabilities:
Accounts receivable	(40)	(5)
Change in receivables from payables to affiliates, net	(31)	(2)
Inventories	27	13
Accounts payable and accrued expenses	(24)	(36)
Income taxes	0	3
Pension and non-pension postretirement benefit contributions	(12)	(16)
Other assets and liabilities	(106)	(103)
Net Cash Provided by (Used in) Operating Activities, Total	141	125
Cash flows from investing activities
Capital expenditures	(344)	(295)
Changes in Exelon/PHI intercompany money pool	0	(48)
Other investing activities	2	1
Net Cash Provided by (Used in) Investing Activities, Total	(342)	(342)
Cash flows from financing activities
Issuance of long-term debt	0	375
Increase (Decrease) in Due to Affiliates, Current	65	(40)
Dividends paid on common stock	(100)	(85)
Contributions from parent	227	0
Other financing activities	(1)	(4)
Net cash flows provided by financing activities	191	246
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Excluding Exchange Rate Effect, Total	(10)	29
Cash, restricted cash, and cash equivalents at beginning of period	44	26
Cash, restricted cash, and cash equivalents at end of period	34	55
Supplemental Cash Flow Information
Decrease in capital expenditures not paid	(41)	(44)
Baltimore Gas and Electric Company [Member]
Cash flows from operating activities
Net income (loss)	198	209
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	171	152
Deferred income taxes and amortization of investment tax credits	5	(4)
Other non-cash operating activities	44	2
Changes in assets and liabilities:
Accounts receivable	(80)	12
Change in receivables from payables to affiliates, net	(2)	(15)
Inventories	32	9
Accounts payable and accrued expenses	(30)	(59)
Income taxes	4	(9)
Pension and non-pension postretirement benefit contributions	(56)	(65)
Other assets and liabilities	(9)	(103)
Net Cash Provided by (Used in) Operating Activities, Total	277	129
Cash flows from investing activities
Capital expenditures	(303)	(336)
Other investing activities	3	2
Net Cash Provided by (Used in) Investing Activities, Total	(300)	(334)
Cash flows from financing activities
Changes in short-term borrowings	120	156
Dividends paid on common stock	(76)	(74)
Other financing activities	(1)	0
Net cash flows provided by financing activities	43	82
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Excluding Exchange Rate Effect, Total	20	(123)
Cash, restricted cash, and cash equivalents at beginning of period	55	145
Cash, restricted cash, and cash equivalents at end of period	75	22
Supplemental Cash Flow Information
Decrease in capital expenditures not paid	(32)	(80)
Pepco Holdings LLC [Member]
Cash flows from operating activities
Net income (loss)	130	128
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	218	210
Deferred income taxes and amortization of investment tax credits	2	4
Other non-cash operating activities	35	(25)
Changes in assets and liabilities:
Accounts receivable	(21)	56
Change in receivables from payables to affiliates, net	(51)	(18)
Inventories	7	5
Accounts payable and accrued expenses	(23)	(24)
Income taxes	5	3
Pension and non-pension postretirement benefit contributions	(67)	(36)
Other assets and liabilities	(3)	(94)
Net Cash Provided by (Used in) Operating Activities, Total	232	209
Cash flows from investing activities
Capital expenditures	(409)	(456)
Other investing activities	2	1
Net Cash Provided by (Used in) Investing Activities, Total	(407)	(455)
Cash flows from financing activities
Changes in short-term borrowings	(468)	(368)
Issuance of long-term debt	700	625
Retirement of long-term debt	0	(44)
Increase (Decrease) in Due to Affiliates, Current	39	3
Payments of Distributions to Affiliates	(102)	(81)
Proceeds from Contributions from Affiliates	704	560
Other financing activities	(9)	(5)
Net cash flows provided by financing activities	864	690
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Excluding Exchange Rate Effect, Total	689	444
Cash, restricted cash, and cash equivalents at beginning of period	213	160
Cash, restricted cash, and cash equivalents at end of period	902	604
Supplemental Cash Flow Information
Decrease in capital expenditures not paid	(55)	(33)
Potomac Electric Power Company [Member]
Cash flows from operating activities
Net income (loss)	46	59
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	108	102
Deferred income taxes and amortization of investment tax credits	(2)	4
Other non-cash operating activities	12	(25)
Changes in assets and liabilities:
Accounts receivable	(2)	26
Change in receivables from payables to affiliates, net	(25)	(9)
Inventories	0	1
Accounts payable and accrued expenses	5	0
Income taxes	1	2
Pension and non-pension postretirement benefit contributions	(5)	(5)
Other assets and liabilities	(18)	(58)
Net Cash Provided by (Used in) Operating Activities, Total	120	97
Cash flows from investing activities
Capital expenditures	(218)	(220)
Other investing activities	1	1
Net Cash Provided by (Used in) Investing Activities, Total	(217)	(219)
Cash flows from financing activities
Changes in short-term borrowings	(175)	(35)
Issuance of long-term debt	400	150
Dividends paid on common stock	(42)	(28)
Contributions from parent	387	138
Other financing activities	(5)	(1)
Net cash flows provided by financing activities	565	224
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Excluding Exchange Rate Effect, Total	468	102
Cash, restricted cash, and cash equivalents at beginning of period	68	65
Cash, restricted cash, and cash equivalents at end of period	536	167
Supplemental Cash Flow Information
Decrease in capital expenditures not paid	(36)	(16)
Delmarva Power and Light Company [Member]
Cash flows from operating activities
Net income (loss)	56	56
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	57	53
Deferred income taxes and amortization of investment tax credits	5	2
Other non-cash operating activities	9	(1)
Changes in assets and liabilities:
Accounts receivable	(17)	15
Change in receivables from payables to affiliates, net	(17)	(11)
Inventories	8	2
Accounts payable and accrued expenses	15	11
Income taxes	(1)	3
Pension and non-pension postretirement benefit contributions	(1)	0
Other assets and liabilities	33	(26)
Net Cash Provided by (Used in) Operating Activities, Total	147	104
Cash flows from investing activities
Capital expenditures	(103)	(112)
Other investing activities	1	0
Net Cash Provided by (Used in) Investing Activities, Total	(102)	(112)
Cash flows from financing activities
Changes in short-term borrowings	(149)	(146)
Issuance of long-term debt	125	125
Dividends paid on common stock	(41)	(40)
Contributions from parent	144	120
Other financing activities	(2)	(2)
Net cash flows provided by financing activities	77	57
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Excluding Exchange Rate Effect, Total	122	49
Cash, restricted cash, and cash equivalents at beginning of period	71	15
Cash, restricted cash, and cash equivalents at end of period	193	64
Supplemental Cash Flow Information
Decrease in capital expenditures not paid	(8)	(15)
Atlantic City Electric Company [Member]
Cash flows from operating activities
Net income (loss)	26	14
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	47	47
Deferred income taxes and amortization of investment tax credits	1	(1)
Other non-cash operating activities	2	(7)
Changes in assets and liabilities:
Accounts receivable	(1)	13
Change in receivables from payables to affiliates, net	(6)	1
Inventories	(1)	3
Accounts payable and accrued expenses	(17)	(11)
Income taxes	0	1
Pension and non-pension postretirement benefit contributions	(7)	(3)
Other assets and liabilities	0	(3)
Net Cash Provided by (Used in) Operating Activities, Total	44	54
Cash flows from investing activities
Capital expenditures	(87)	(123)
Net Cash Provided by (Used in) Investing Activities, Total	(87)	(123)
Cash flows from financing activities
Changes in short-term borrowings	(144)	(187)
Issuance of long-term debt	175	350
Retirement of long-term debt	0	(44)
Dividends paid on common stock	(19)	(14)
Contributions from parent	173	303
Other financing activities	(3)	(3)
Net cash flows provided by financing activities	182	405
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents, Period Increase (Decrease), Excluding Exchange Rate Effect, Total	139	336
Cash, restricted cash, and cash equivalents at beginning of period	29	30
Cash, restricted cash, and cash equivalents at end of period	168	366
Supplemental Cash Flow Information
Decrease in capital expenditures not paid	$ (10)	$ (2)

Consolidated Balance Sheets (Unaudited) - USD ($) shares in Millions, $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Current Assets
Cash and cash equivalents	$ 2,476	$ 672
Restricted cash and cash equivalents	430	321
Accounts receivable
Customer accounts receivable	2,365	2,189
Customer allowance for credit losses	(389)	(320)
Customer accounts receivable, net	1,976	1,869
Other accounts receivable	1,148	1,068
Other allowance for credit losses	(81)	(72)
Other accounts receivable, net	1,067	996
Inventories, net
Fossil fuel and emission allowances	39	105
Materials and supplies	473	476
Regulatory assets, current	1,221	1,296
Current assets of discontinued operations	0	7,835
Other	463	387
Total current assets	8,145	13,957
Accumulated depreciation and amortization	14,878	14,430
Property, plant and equipment, net	65,465	64,558
Deferred debits and other assets
Regulatory assets, noncurrent	8,200	8,224
Investments	244	250
Goodwill	6,630	6,630
Receivable related to Regulatory Agreement Units	2,969	0
Property, plant, and equipment, deferred debits, and other assets of discontinued operations	0	38,509
Other	1,045	885
Total deferred debits and other assets	19,088	54,498
Total assets	92,698	133,013
Current Liabilities
Short-term borrowings	1,900	1,248
Long-term debt due within one year	2,154	2,153
Accounts payable	2,175	2,379
Accrued expenses	1,029	1,137
Payables to affiliates, current	6	5
Regulatory liabilities, current	394	376
Mark-to-market derivative liabilities, current	0	18
Unamortized energy contract liabilities, current	13	89
Current liabilities of discontinued operations	0	7,940
Other	964	766
Total current liabilities	8,635	16,111
Long-term debt	35,008	30,749
Long-term debt to financing trusts	390	390
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	11,089	10,611
Asset retirement obligations, noncurrent	273	271
Pension obligations	1,447	2,051
Non-pension postretirement benefit obligations	800	811
Regulatory liabilities, noncurrent	9,192	9,628
Mark-to-market derivative liabilities, noncurrent	144	201
Unamortized energy contract liabilities, noncurrent	42	146
Long-term debt, deferred credits, and other liabilities of discontinued operations	0	25,676
Other	2,187	1,573
Total deferred credits and other liabilities	25,174	50,968
Liabilities	69,207	98,218
Commitments and contingencies
Shareholders' equity
Common Stock, No Par Value	$ 0	$ 0
Common stock, shares authorized	2,000	2,000
Common stock, shares outstanding	980	979
Common stock	$ 20,299	$ 20,324
Treasury stock, shares	2	2
Treasury stock, at cost	$ (123)	$ (123)
Retained earnings/Undistributed earnings (losses)	4,028	16,942
Accumulated other comprehensive loss, net	(713)	(2,750)
Total shareholders’ equity	23,491	34,393
Members' Equity [Abstract]
Noncontrolling interests	0	402
Total equity	23,491	34,795
Total liabilities and shareholders’ equity	92,698	133,013
Commonwealth Edison Co [Member]
Current Assets
Cash and cash equivalents	343	131
Restricted cash and cash equivalents	246	210
Accounts receivable
Customer accounts receivable	702	647
Customer allowance for credit losses	(92)	(73)
Customer accounts receivable, net	610	574
Other accounts receivable	219	227
Other allowance for credit losses	(20)	(17)
Other accounts receivable, net	199	210
Receivables from affiliates, current	3	16
Inventories, net
Inventories, net	167	170
Regulatory assets, current	316	335
Other	80	76
Total current assets	1,964	1,722
Accumulated depreciation and amortization	6,267	6,099
Property, plant and equipment, net	26,325	25,995
Deferred debits and other assets
Regulatory assets, noncurrent	1,883	1,870
Investments	6	6
Goodwill	2,625	2,625
Receivables from affiliates, noncurrent	0	2,761
Receivable related to Regulatory Agreement Units	2,484	0
Prepaid pension asset	1,245	1,086
Other	481	405
Total deferred debits and other assets	8,724	8,753
Total assets	37,013	36,470
Current Liabilities
Accounts payable	553	647
Accrued expenses	275	384
Payables to affiliates, current	66	121
Customer deposits	98	99
Regulatory liabilities, current	190	185
Mark-to-market derivative liabilities, current	0	18
Other	161	133
Total current liabilities	1,343	1,587
Long-term debt	10,515	9,773
Long-term debt to financing trusts	205	205
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	4,761	4,685
Asset retirement obligations, noncurrent	145	144
Non-pension postretirement benefit obligations	168	169
Regulatory liabilities, noncurrent	6,551	6,759
Mark-to-market derivative liabilities, noncurrent	144	201
Other	615	592
Total deferred credits and other liabilities	12,384	12,550
Liabilities	24,447	24,115
Commitments and contingencies
Shareholders' equity
Common stock	1,588	1,588
Retained earnings/Undistributed earnings (losses)	1,735	1,691
Other paid-in capital	9,243	9,076
Total shareholders’ equity	12,566	12,355
Members' Equity [Abstract]
Total liabilities and shareholders’ equity	37,013	36,470
PECO Energy Co [Member]
Current Assets
Cash and cash equivalents	26	36
Restricted cash and cash equivalents	8	8
Accounts receivable
Customer accounts receivable	528	489
Customer allowance for credit losses	(125)	(105)
Customer accounts receivable, net	403	384
Other accounts receivable	129	116
Other allowance for credit losses	(9)	(7)
Other accounts receivable, net	120	109
Receivables from affiliates, current	0	1
Inventories, net
Fossil fuel and emission allowances	23	51
Materials and supplies	46	45
Prepaid utility taxes	117	1
Regulatory assets, current	57	48
Other	30	28
Total current assets	830	711
Accumulated depreciation and amortization	4,004	3,964
Property, plant and equipment, net	11,334	11,117
Deferred debits and other assets
Regulatory assets, noncurrent	1,000	943
Investments	33	34
Receivables from affiliates, noncurrent	0	597
Receivable related to Regulatory Agreement Units	486	0
Prepaid pension asset	401	386
Other	29	36
Total deferred debits and other assets	1,949	1,996
Total assets	14,113	13,824
Current Liabilities
Long-term debt due within one year	350	350
Accounts payable	477	494
Accrued expenses	105	136
Payables to affiliates, current	38	70
Borrowings from Exelon/PHI intercompany money pool	65	0
Customer deposits	50	48
Regulatory liabilities, current	94	94
Other	41	35
Total current liabilities	1,220	1,227
Long-term debt	3,848	3,847
Long-term debt to financing trusts	184	184
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	2,495	2,421
Asset retirement obligations, noncurrent	29	29
Non-pension postretirement benefit obligations	287	286
Regulatory liabilities, noncurrent	523	635
Other	82	83
Total deferred credits and other liabilities	3,416	3,454
Liabilities	8,668	8,712
Commitments and contingencies
Shareholders' equity
Common stock	3,655	3,428
Retained earnings/Undistributed earnings (losses)	1,790	1,684
Total shareholders’ equity	5,445	5,112
Members' Equity [Abstract]
Total liabilities and shareholders’ equity	14,113	13,824
Baltimore Gas and Electric Company [Member]
Current Assets
Cash and cash equivalents	41	51
Restricted cash and cash equivalents	34	4
Accounts receivable
Customer accounts receivable	519	436
Customer allowance for credit losses	(59)	(38)
Customer accounts receivable, net	460	398
Other accounts receivable	126	124
Other allowance for credit losses	(11)	(9)
Other accounts receivable, net	115	115
Receivables from affiliates, current	0	1
Inventories, net
Fossil fuel and emission allowances	12	42
Materials and supplies	51	53
Prepaid utility taxes	46	49
Regulatory assets, current	175	215
Other	11	8
Total current assets	945	936
Accumulated depreciation and amortization	4,376	4,299
Property, plant and equipment, net	10,736	10,577
Deferred debits and other assets
Regulatory assets, noncurrent	467	477
Investments	6	14
Prepaid pension asset	315	276
Other	40	44
Total deferred debits and other assets	828	811
Total assets	12,509	12,324
Current Liabilities
Short-term borrowings	250	130
Long-term debt due within one year	250	250
Accounts payable	299	349
Accrued expenses	168	176
Payables to affiliates, current	37	48
Customer deposits	98	97
Regulatory liabilities, current	35	26
Other	61	48
Total current liabilities	1,198	1,124
Long-term debt	3,711	3,711
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	1,755	1,686
Asset retirement obligations, noncurrent	26	26
Non-pension postretirement benefit obligations	170	175
Regulatory liabilities, noncurrent	872	934
Other	85	98
Total deferred credits and other liabilities	2,908	2,919
Liabilities	7,817	7,754
Commitments and contingencies
Shareholders' equity
Common stock	2,575	2,575
Retained earnings/Undistributed earnings (losses)	2,117	1,995
Total shareholders’ equity	4,692	4,570
Members' Equity [Abstract]
Total liabilities and shareholders’ equity	12,509	12,324
Pepco Holdings LLC [Member]
Current Assets
Cash and cash equivalents	796	136
Restricted cash and cash equivalents	106	77
Accounts receivable
Customer accounts receivable	618	616
Customer allowance for credit losses	(113)	(104)
Customer accounts receivable, net	505	512
Other accounts receivable	288	283
Other allowance for credit losses	(41)	(39)
Other accounts receivable, net	247	244
Receivables from affiliates, current	0	2
Inventories, net
Fossil fuel and emission allowances	4	11
Materials and supplies	209	209
Regulatory assets, current	432	432
Other	69	69
Total current assets	2,368	1,692
Accumulated depreciation and amortization	2,256	2,108
Property, plant and equipment, net	16,701	16,498
Deferred debits and other assets
Regulatory assets, noncurrent	1,770	1,794
Investments	142	145
Goodwill	4,005	4,005
Prepaid pension asset	392	344
Deferred income taxes	5	8
Other	253	258
Total deferred debits and other assets	6,567	6,554
Total assets	25,636	24,744
Current Liabilities
Short-term borrowings	0	468
Long-term debt due within one year	400	399
Accounts payable	522	578
Accrued expenses	264	281
Payables to affiliates, current	51	104
Borrowings from Exelon/PHI intercompany money pool	46	7
Customer deposits	80	81
Regulatory liabilities, current	72	68
Unamortized energy contract liabilities, current	13	89
PPA termination obligation	85	0
Other	215	171
Total current liabilities	1,748	2,246
Long-term debt	7,833	7,148
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	2,723	2,675
Asset retirement obligations, noncurrent	70	70
Non-pension postretirement benefit obligations	60	66
Regulatory liabilities, noncurrent	1,182	1,238
Unamortized energy contract liabilities, noncurrent	42	146
Other	661	570
Total deferred credits and other liabilities	4,738	4,765
Liabilities	14,319	14,159
Commitments and contingencies
Shareholders' equity
Retained earnings/Undistributed earnings (losses)	(182)	(210)
Members' Equity [Abstract]
Membership interest	11,499	10,795
Total members' equity	11,317	10,585
Total liabilities and shareholders’ equity	25,636	24,744
Potomac Electric Power Company [Member]
Current Assets
Cash and cash equivalents	502	34
Restricted cash and cash equivalents	34	34
Accounts receivable
Customer accounts receivable	278	277
Customer allowance for credit losses	(40)	(37)
Customer accounts receivable, net	238	240
Other accounts receivable	157	160
Other allowance for credit losses	(18)	(16)
Other accounts receivable, net	139	144
Receivables from affiliates, current	0	0
Inventories, net
Inventories, net	119	119
Regulatory assets, current	216	213
Other	29	25
Total current assets	1,277	809
Accumulated depreciation and amortization	3,929	3,875
Property, plant and equipment, net	8,229	8,104
Deferred debits and other assets
Regulatory assets, noncurrent	496	532
Investments	119	120
Prepaid pension asset	279	279
Other	58	59
Total deferred debits and other assets	952	990
Total assets	10,458	9,903
Current Liabilities
Short-term borrowings	0	175
Long-term debt due within one year	314	313
Accounts payable	246	272
Accrued expenses	158	160
Payables to affiliates, current	34	59
Customer deposits	36	35
Regulatory liabilities, current	18	14
Merger related obligation	27	27
Other	64	55
Total current liabilities	897	1,110
Long-term debt	3,527	3,132
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	1,293	1,275
Asset retirement obligations, noncurrent	45	45
Non-pension postretirement benefit obligations	0	3
Regulatory liabilities, noncurrent	533	549
Other	297	314
Total deferred credits and other liabilities	2,168	2,186
Liabilities	6,592	6,428
Commitments and contingencies
Shareholders' equity
Common stock	2,689	2,302
Retained earnings/Undistributed earnings (losses)	1,177	1,173
Total shareholders’ equity	3,866	3,475
Members' Equity [Abstract]
Total liabilities and shareholders’ equity	10,458	9,903
Delmarva Power and Light Company [Member]
Current Assets
Cash and cash equivalents	120	28
Restricted cash and cash equivalents	73	43
Accounts receivable
Customer accounts receivable	164	149
Customer allowance for credit losses	(24)	(18)
Customer accounts receivable, net	140	131
Other accounts receivable	62	58
Other allowance for credit losses	(9)	(8)
Other accounts receivable, net	53	50
Receivables from affiliates, current	0	1
Inventories, net
Fossil fuel and emission allowances	4	11
Materials and supplies	53	54
Prepaid utility taxes	10	20
Regulatory assets, current	66	68
Other	19	16
Total current assets	538	422
Accumulated depreciation and amortization	1,671	1,635
Property, plant and equipment, net	4,612	4,560
Deferred debits and other assets
Regulatory assets, noncurrent	208	212
Prepaid pension asset	157	157
Other	58	61
Total deferred debits and other assets	423	430
Total assets	5,573	5,412
Current Liabilities
Short-term borrowings	0	149
Long-term debt due within one year	83	83
Accounts payable	128	131
Accrued expenses	50	40
Payables to affiliates, current	15	33
Customer deposits	27	28
Regulatory liabilities, current	33	25
Other	88	59
Total current liabilities	424	548
Long-term debt	1,852	1,727
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	825	803
Asset retirement obligations, noncurrent	16	16
Non-pension postretirement benefit obligations	10	11
Regulatory liabilities, noncurrent	423	441
Other	87	89
Total deferred credits and other liabilities	1,361	1,360
Liabilities	3,637	3,635
Commitments and contingencies
Shareholders' equity
Common stock	1,353	1,209
Retained earnings/Undistributed earnings (losses)	583	568
Total shareholders’ equity	1,936	1,777
Members' Equity [Abstract]
Total liabilities and shareholders’ equity	5,573	5,412
Atlantic City Electric Company [Member]
Current Assets
Cash and cash equivalents	168	29
Restricted cash and cash equivalents	0	0
Accounts receivable
Customer accounts receivable	177	190
Customer allowance for credit losses	(49)	(49)
Customer accounts receivable, net	128	141
Other accounts receivable	79	76
Other allowance for credit losses	(14)	(15)
Other accounts receivable, net	65	61
Receivables from affiliates, current	0	2
Inventories, net
Inventories, net	37	36
Regulatory assets, current	137	61
Other	5	3
Total current assets	540	333
Accumulated depreciation and amortization	1,458	1,420
Property, plant and equipment, net	3,763	3,729
Deferred debits and other assets
Regulatory assets, noncurrent	559	430
Prepaid pension asset	30	27
Other	37	37
Total deferred debits and other assets	626	494
Total assets	4,929	4,556
Current Liabilities
Short-term borrowings	0	144
Long-term debt due within one year	3	3
Accounts payable	139	165
Accrued expenses	43	44
Payables to affiliates, current	23	31
Customer deposits	18	18
Regulatory liabilities, current	20	28
PPA termination obligation	85	0
Other	18	12
Total current liabilities	349	445
Long-term debt	1,754	1,579
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	692	682
Non-pension postretirement benefit obligations	11	12
Regulatory liabilities, noncurrent	203	214
Other	165	49
Total deferred credits and other liabilities	1,071	957
Liabilities	3,174	2,981
Commitments and contingencies
Shareholders' equity
Common stock	1,763	1,590
Retained earnings/Undistributed earnings (losses)	(8)	(15)
Total shareholders’ equity	1,755	1,575
Members' Equity [Abstract]
Total liabilities and shareholders’ equity	$ 4,929	$ 4,556

Consolidated Statements of Changes in Shareholders Equity (Unaudited) - USD ($) shares in Thousands, $ in Millions	Total	Correcting Adjustment [Member]	Common Stock [Member]	Common Stock [Member] Correcting Adjustment [Member]	Treasury Stock [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Noncontrolling Interest [Member]	Commonwealth Edison Co [Member]	Commonwealth Edison Co [Member] Common Stock [Member]	Commonwealth Edison Co [Member] Retained Earnings [Member]	Commonwealth Edison Co [Member] Other Paid-in-Capital [Member]	PECO Energy Co [Member]	PECO Energy Co [Member] Common Stock [Member]	PECO Energy Co [Member] Retained Earnings [Member]	Baltimore Gas and Electric Company [Member]	Baltimore Gas and Electric Company [Member] Common Stock [Member]	Baltimore Gas and Electric Company [Member] Retained Earnings [Member]	Pepco Holdings LLC [Member]	Pepco Holdings LLC [Member] Retained Earnings [Member]	Pepco Holdings LLC [Member] Membership Interest [Member]	Potomac Electric Power Company [Member]	Potomac Electric Power Company [Member] Common Stock [Member]	Potomac Electric Power Company [Member] Retained Earnings [Member]	Delmarva Power and Light Company [Member]	Delmarva Power and Light Company [Member] Common Stock [Member]	Delmarva Power and Light Company [Member] Retained Earnings [Member]	Atlantic City Electric Company [Member]	Atlantic City Electric Company [Member] Common Stock [Member]	Atlantic City Electric Company [Member] Retained Earnings [Member]
Beginning balance (in shares) at Dec. 31, 2020	977,466
Beginning balance at Dec. 31, 2020	$ 34,868		$ 19,373		$ (123)	$ 16,735	$ (3,400)	$ 2,283
Beginning Balance at Dec. 31, 2020																			$ 10,044	$ (68)	$ 10,112
Beginning Balance at Dec. 31, 2020									$ 11,329	$ 1,588	$ 1,456	$ 8,285	$ 4,533	$ 3,014	$ 1,519	$ 4,197	$ 2,318	$ 1,879				$ 3,203	$ 2,058	$ 1,145	$ 1,676	$ 1,089	$ 587	$ 1,398	$ 1,271	$ 127
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	$ (264)					(289)		25	197		197		167		167	209		209	128	128		59		59	56		56	14		14
Long -Term Incentive Plan Activity (shares)	640
Long-Term Incentive Plan Activity		$ 5		$ 5
Employee stock purchase plan issuances (shares)	902
Employee stock purchase plan issuances	$ 34		34
Changes in equity of noncontrolling interests	$ (10)							(10)
Common Stock, Dividends, Per Share, Declared	$ 0.38
Common stock dividends	$ (374)					(374)			(127)		(127)		(85)		(85)	(74)		(74)				(28)		(28)	(40)		(40)	(14)		(14)
Distributions to member																			(81)	(81)
Contributions from parent									198			198							560		560	138	138		120	120		303	303
Other comprehensive income (loss), net of income taxes	$ 54						54
Ending balance (in shares) at Mar. 31, 2021	979,008
Ending balance at Mar. 31, 2021	$ 34,313		19,412		(123)	16,072	(3,346)	2,298
Ending Balance at Mar. 31, 2021																			10,651	(21)	10,672
Ending Balance at Mar. 31, 2021									11,597	1,588	1,526	8,483	4,615	3,014	1,601	4,332	2,318	2,014				3,372	2,196	1,176	1,812	1,209	603	1,701	1,574	127
Beginning balance (in shares) at Dec. 31, 2021	981,291
Beginning balance at Dec. 31, 2021	$ 34,795		20,324		(123)	16,942	(2,750)	402
Beginning Balance at Dec. 31, 2021																			10,585	(210)	10,795
Beginning Balance at Dec. 31, 2021	34,393								12,355	1,588	1,691	9,076	5,112	3,428	1,684	4,570	2,575	1,995				3,475	2,302	1,173	1,777	1,209	568	1,575	1,590	(15)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	$ 598					597		1	188		188		206		206	198		198	130	130		46		46	56		56	26		26
Long -Term Incentive Plan Activity (shares)	540
Long-Term Incentive Plan Activity	$ (13)		(13)
Employee stock purchase plan issuances (shares)	211
Employee stock purchase plan issuances	$ 9		9
Changes in equity of noncontrolling interests	$ (7)							(7)
Common Stock, Dividends, Per Share, Declared	$ 0.34
Distribution of Constellation	$ (11,573)		(21)			(13,179)	2,023	(396)
Common stock dividends	(332)					(332)			(144)		(144)		(100)		(100)	(76)		(76)				(42)		(42)	(41)		(41)	(19)		(19)
Distributions to member																			(102)	(102)
Contributions from parent									167			167	227	227					704		704	387	387		144	144		173	173
Other comprehensive income (loss), net of income taxes	$ 14						14
Ending balance (in shares) at Mar. 31, 2022	982,042
Ending balance at Mar. 31, 2022	$ 23,491		$ 20,299		$ (123)	$ 4,028	$ (713)	$ 0
Ending Balance at Mar. 31, 2022																			$ 11,317	$ (182)	$ 11,499
Ending Balance at Mar. 31, 2022	$ 23,491								$ 12,566	$ 1,588	$ 1,735	$ 9,243	$ 5,445	$ 3,655	$ 1,790	$ 4,692	$ 2,575	$ 2,117				$ 3,866	$ 2,689	$ 1,177	$ 1,936	$ 1,353	$ 583	$ 1,755	$ 1,763	$ (8)

Significant Accounting Policies (All Registrants)

3 Months Ended

Mar. 31, 2022

Accounting Policies [Abstract]

Description of Business

Exelon is a utility services holding company engaged in the energy distribution and transmission businesses through ComEd, PECO, BGE, Pepco, DPL, and ACE.

On February 21, 2021, Exelon's Board of Directors approved a plan to separate the Utility Registrants and Generation. The separation was completed on February 1, 2022, creating two publicly traded companies, Exelon and Constellation. See Note 2 — Discontinued Operations for additional information.

Name of Registrant

Business

Service Territories

Commonwealth Edison Company

Purchase and regulated retail sale of electricity

Northern Illinois, including the City of Chicago

Transmission and distribution of electricity to retail customers

PECO Energy Company

Purchase and regulated retail sale of electricity and natural gas

Southeastern Pennsylvania, including the City of Philadelphia (electricity)

Transmission and distribution of electricity and distribution of natural gas to retail customers

Pennsylvania counties surrounding the City of Philadelphia (natural gas)

Baltimore Gas and Electric Company

Purchase and regulated retail sale of electricity and natural gas

Central Maryland, including the City of Baltimore (electricity and natural gas)

Transmission and distribution of electricity and distribution of natural gas to retail customers

Pepco Holdings LLC

Utility services holding company engaged, through its reportable segments Pepco, DPL, and ACE

Service Territories of Pepco, DPL, and ACE

Potomac Electric
Power Company

Purchase and regulated retail sale of electricity

District of Columbia, and major portions of Montgomery and Prince George’s Counties, Maryland

Transmission and distribution of electricity to retail customers

Delmarva Power &
Light Company

Purchase and regulated retail sale of electricity and natural gas

Portions of Delaware and Maryland (electricity)

Transmission and distribution of electricity and distribution of natural gas to retail customers

Portions of New Castle County, Delaware (natural gas)

Atlantic City Electric Company

Purchase and regulated retail sale of electricity

Portions of Southern New Jersey

Transmission and distribution of electricity to retail customers

Basis of Presentation

This is a combined quarterly report of all Registrants. The Notes to the Consolidated Financial Statements apply to the Registrants as indicated parenthetically next to each corresponding disclosure. When appropriate, the Registrants are named specifically for their related activities and disclosures. Each of the Registrant’s Consolidated Financial Statements includes the accounts of its subsidiaries. All intercompany transactions have been eliminated, except for the historical transactions between the Utility Registrants and Generation for the purposes of presenting discontinued operations in all periods presented in the Consolidated Statements of Operations and Comprehensive Income.

Through its business services subsidiary, BSC, Exelon provides its subsidiaries with a variety of support services at cost, including legal, human resources, financial, information technology, and supply management services. PHI also has a business services subsidiary, PHISCO, which provides a variety of support services at cost, including legal, accounting, engineering, customer operations, distribution and transmission planning, asset management, system operations, and power procurement, to PHI operating companies. The costs of BSC and PHISCO are directly charged or allocated to the applicable subsidiaries. The results of Exelon’s corporate operations are presented as “Other” in the consolidated financial statements and include intercompany eliminations unless otherwise disclosed.

The accompanying consolidated financial statements as of March 31, 2022 and for the three months ended March 31, 2022 and 2021 are unaudited but, in the opinion of the management of each Registrant include all adjustments that are considered necessary for a fair statement of the Registrants’ respective financial statements in accordance with GAAP. All adjustments are of a normal, recurring nature, except as otherwise disclosed. The

December 31, 2021 Consolidated Balance Sheets were derived from audited financial statements. The interim financial statements are to be read in conjunction with prior annual financial statements and notes. Additionally, financial results for interim periods are not necessarily indicative of results that may be expected for any other interim period or for the fiscal year ending December 31, 2022. These Combined Notes to Consolidated Financial Statements have been prepared pursuant to the rules and regulations of the SEC for Quarterly Reports on Form 10-Q. Certain information and note disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations.

The separation of Constellation, including Generation and its subsidiaries, meets the criteria for discontinued operations and as such, results of operations are presented as discontinued operations and have been excluded from continuing operations for all periods presented. Accounting rules require that certain BSC costs previously allocated to Generation be presented as part of Exelon’s continuing operations as these costs do not qualify as expenses of the discontinued operations. Comprehensive income, shareholders' equity, and cash flows related to Constellation have not been segregated and are included in the Consolidated Statements of Operations and Comprehensive Income, Consolidated Statements of Changes in Shareholders’ Equity, and Consolidated Statements of Cash Flows, respectively, for all periods presented. See Note 2 — Discontinued Operations for additional information.

Prior Period Adjustments and Reclassifications (Exelon, PHI, ACE)

In the first quarter of 2022, management identified an error related to an overstatement of the regulatory liability associated with ACE’s mechanism to recover the cost of Transition Bonds issued in 2002 and 2003 by ACE Funding. Management has concluded that the error was not material to previously issued financial statements for Exelon, PHI or ACE.

The error was corrected through a revision to ACE’s financial statements contained herein. The impact of the error correction was an $8 million increase to ACE’s opening Retained earnings as of January 1, 2021 with a corresponding reduction to Regulatory liabilities of $11 million and an increase to Deferred income taxes and unamortized investment tax credits of $3 million. The impact of the error to ACE’s Total operating revenues and Net income was less than $1 million for the three months ended March 31, 2021. The error did not impact net cash flows provided by operating activities, net cash flows used in investing activities or net cash flows provided by financing activities for the three months ended March 31, 2021.

The error was corrected in the Exelon and PHI financial statements for the three months ended March 31, 2022 as it was not material, resulting in an increase to Net income of $8 million.

Discontinued Operations (Exelon)

3 Months Ended

Mar. 31, 2022

Discontinued Operations and Disposal Groups [Abstract]

Disposal Groups, Including Discontinued Operations, Disclosure [Text Block]

Discontinued Operations (Exelon)

On February 21, 2021, Exelon's Board of Directors approved a plan to separate the Utility Registrants and Generation, creating two publicly traded companies ("the separation"). Exelon completed the separation on February 1, 2022, through the distribution of 326,663,937 common stock shares of Constellation, the new publicly traded company, to Exelon shareholders. Under the separation plan, Exelon shareholders retained their current shares of Exelon stock and received one share of Constellation common stock for every three shares of Exelon common stock held on January 20, 2022, the record date for the distribution, in a transaction that is tax-free to Exelon and its shareholders for U.S. federal income tax purposes.

Constellation was newly formed and incorporated in Pennsylvania on June 15, 2021 for the purposes of separation and holds Generation (including Generation's subsidiaries).

Pursuant to the separation:

•Exelon entered into four term loans consisting of a 364-day term loan for $1.15 billion and three 18-month term loans for $300 million, $300 million and $250 million, respectively. Exelon issued these term loans primarily to fund the cash payment to Constellation and for general corporate purposes. See Note 10 — Debt and Credit Agreements for additional information.

•Exelon made a cash payment of $1.75 billion to Constellation on January 31, 2022.

•Exelon contributed its equity ownership interest in Generation to Constellation. Exelon no longer retains any equity ownership interest in Generation or Constellation.

•Exelon transferred certain corporate assets and employee-related obligations to Constellation.

•Exelon received cash from Generation of $258 million to settle the intercompany loan on January 31, 2022. See Note 10 — Debt and Credit Agreements for additional information.

Continuing Involvement

In order to govern the ongoing relationships between Exelon and Constellation after the separation, and to facilitate an orderly transition, Exelon and Constellation have entered into several agreements, including the following:

•Separation Agreement – governs the rights and obligations between Exelon and Constellation regarding certain actions to be taken in connection with the separation, among others, including the allocation of assets and liabilities between Exelon and Constellation.

•Transition Services Agreement (TSA) – governs the terms and conditions of the services that Exelon will provide to Constellation and Constellation will provide to Exelon for an expected period of two years, provided that certain services may be longer than the term and services may be extended with approval from both parties. The services include specified accounting, finance, information technology, human resources, employee benefits and other services that have historically been provided on a centralized basis by BSC. For the period from February 1, 2022 to March 31, 2022, the amounts Exelon billed Constellation and Constellation billed Exelon for these services were $56 million recorded in Other income, net and $9 million recorded in Operating and maintenance expense, respectively.

•Tax Matters Agreement (TMA) – governs the respective rights, responsibilities and obligations of Exelon and Constellation with respect to all tax matters, including tax liabilities and benefits, tax attributes, tax returns, tax contests and other tax sharing regarding U.S. federal, state, local and foreign income taxes, other tax matters and related tax returns. See Note 7. Income Taxes for additional information.

In addition, the Utility Registrants will continue to incur expenses from transactions with Generation after the separation. Prior to the separation, such expenses were primarily recorded as Purchased power from affiliates and an immaterial amount recorded as Operating and maintenance expense from affiliates at the Utility Registrants. After the separation, such expenses are primarily recorded as Purchased power and an immaterial amount recorded as Operating and maintenance expense at the Utility Registrants.

•ComEd had an ICC-approved RFP contract with Generation to provide a portion of ComEd’s electric supply requirements. ComEd also purchased RECs and ZECs from Generation.

•PECO received electric supply from Generation under contracts executed through PECO’s competitive procurement process. In addition, PECO had a ten-year agreement with Generation to sell solar AECs.

•BGE received a portion of its energy requirements from Generation under its MDPSC-approved market-based SOS and gas commodity programs.

•Pepco received electric supply from Generation under contracts executed through Pepco’s competitive procurement process approved by the MDPSC and DCPSC.

•DPL received a portion of its energy requirements from Generation under its MDPSC and DEPSC approved market-based SOS commodity programs.

•ACE received electric supply from Generation under contracts executed through ACE’s competitive procurement process approved by the NJBPU.

ComEd and PECO also have receivables with Generation as a result of the nuclear decommissioning contractual construct whereby, to the extent NDT funds are greater than the underlying ARO at the end of decommissioning, such amounts are due back to ComEd and PECO, as applicable, for payment to their respective customers. See Note 10 — Asset Retirement Obligations of the Combined Notes to Consolidated Financial Statements of the Exelon 2021 Form 10-K and Note 15 — Related Party Transactions for additional information.

Discontinued Operations

The separation represented a strategic shift that would have a major effect on Exelon’s operations and financial results. Accordingly, the separation meets the criteria for discontinued operations.

The following table presents the results of Constellation that have been reclassified from continuing operations and included in discontinued operations within Exelon’s Consolidated Statements of Operations and Comprehensive Income for the three months ended March 31, 2022 and March 31, 2021.

These results are primarily Generation, which is comprised of Exelon’s Mid-Atlantic, Midwest, New York, ERCOT, and Other Power Regions reportable segments, and include the impact of transaction costs, certain BSC costs, including any transition costs, that were historically allocated and directly attributable to Generation, transactions between Generation and the Utility Registrants, and tax-related adjustments. Transaction costs include costs for external bankers, accountants, appraisers, lawyers, external counsels and other advisors, among others, who are involved in the negotiation, appraisal, due diligence and regulatory approval of the separation. Transition costs are primarily employee-related costs such as recruitment expenses, costs to establish certain stand-alone functions and information technology systems, professional services fees and other separation-related costs during the transition to separate Generation. For the purposes of reporting discontinued operations, these results also include transactions between Generation and the Utility Registrants that were historically eliminated within Exelon’s Consolidated Statements of Operations as these transactions will be ongoing after the separation. Certain BSC costs that were historically allocated to Generation are presented as part of continuing operations in Exelon’s Consolidated Statements of Operations as these costs do not qualify as expenses of the discontinued operations per the accounting rules.


	Three Months Ended March 31,
	2022		2021
Operating revenues
Competitive business revenues	$	1,855	$	5,265
Competitive business revenues from affiliates	161		294
Total operating revenues	2,016		5,559
Operating expenses
Competitive businesses purchased power and fuel	1,138		4,610

Operating and maintenance(a)	371		904

Depreciation and amortization	94		940
Taxes other than income taxes	44		121
Total operating expenses	1,647		6,575
Gain on sales of assets and businesses	10		71
Operating income (loss)	379		(945)
Other income and (deductions)
Interest expense, net	(20)		(68)

Other, net	(281)		167
Total other income and (deductions)	(301)		99
Income (loss) before income taxes	78		(846)
Income taxes	(40)		(58)
Equity in losses of unconsolidated affiliates	(1)		(1)
Net income (loss)	117		(789)
Net income attributable to noncontrolling interests	1		25
Net income (loss) from discontinued operations	$	116	$	(814)

__________

(a)Includes transaction and transition costs related to the separation of $52 million and $3 million for the three months ended March 31, 2022 and 2021, respectively. $50 million and $2 million of transaction costs and $2 million and less than $1 million of transition costs are included in the results of discontinued operations in the table presented above for the three months ended March 31, 2022 and March 31, 2021, respectively. See discussion above for additional information.

There were no assets and liabilities of discontinued operations included in Exelon’s Consolidated Balance Sheet as of March 31, 2022. Constellation had net assets of $11,573 million that separated on February 1, 2022 that resulted in a reduction to Exelon’s equity during the three months ended March 31, 2022. Refer to the Distribution of Constellation line in Exelon’s Consolidated Statement of Changes in Shareholders’ Equity for further information.

The following table presents the assets and liabilities of discontinued operations in Exelon’s Consolidated Balance Sheet as of December 31, 2021:


	December 31, 2021
ASSETS
Current assets
Cash and cash equivalents	$	510
Restricted cash and cash equivalents	72
Accounts receivable
Customer accounts receivable	1,724
Customer allowance for credit losses	(55)
Customer accounts receivable, net	1,669
Other accounts receivable	596
Other allowance for credit losses	(4)
Other accounts receivable, net	592
Mark-to-market derivative assets	2,169
Inventories, net
Fossil fuel and emission allowances	284
Materials and supplies	1,004
Renewable energy credits	529
Assets held for sale	13
Other	993
Total current assets of discontinued operations	7,835
Property, plant, and equipment (net of accumulated depreciation and amortization of $15,888)	19,661
Deferred debits and other assets
Nuclear decommissioning trust funds	15,938
Investments	193

Mark-to-market derivative assets	949
Other	1,768
Total property, plant, and equipment, deferred debits, and other assets of discontinued operations	38,509
Total assets of discontinued operations	$	46,344


	December 31, 2021
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current liabilities
Short-term borrowings	$	2,082
Long-term debt due within one year	1,220
Accounts payable	1,757
Accrued expenses	818
Mark-to-market derivative liabilities	981

Renewable energy credit obligation	779
Liabilities held for sale	3
Other	300
Total current liabilities of discontinued operations	7,940
Long-term debt	4,575
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	3,583
Asset retirement obligations	12,819
Pension obligations	939
Non-pension postretirement benefit obligations	876
Spent nuclear fuel obligation	1,210
Mark-to-market derivative liabilities	513

Other	1,161
Total long-term debt, deferred credits, and other liabilities of discontinued operations	25,676
Total liabilities of discontinued operations	$	33,616

The following table presents selected financial information regarding cash flows of the discontinued operations that are included within Exelon’s Consolidated Statements of Cash Flows for the three months ended March 31, 2022 and March 31, 2021.


	Three Months Ended March 31, 2022
	2022		2021
Non-cash items included in net income (loss) from discontinued operations:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	$	207	$	1,346

Gain on sales of assets and businesses	9		(71)
Deferred income taxes and amortization of investment tax credits	(143)		(234)
Net fair value changes related to derivatives	(59)		(178)
Net realized and unrealized losses (gains) on NDT fund investments	205		(118)
Net unrealized losses on equity investments	16		23
Other decommissioning-related activity	36		(332)
Cash flows from investing activities:
Capital expenditures	(227)		(394)
Collection of DPP	169		1,574
Supplemental cash flow information:
Decrease in capital expenditures not paid	(128)		(37)
Increase in DPP	348		1,339
Increase in PP&E related to ARO update	335		—

Mergers, Acquisitions, and Dispositions (Exelon and Generation)	3 Months Ended
	Mar. 31, 2022
Mergers, Acquisitions, and Dispositions [Abstract]
Mergers, Acquisitions, and Dispositions (Exelon and Generation)	Mergers, Acquisitions, and Dispositions (Exelon)

Regulatory Matters (All Registrants)

3 Months Ended

Mar. 31, 2022

Regulated Operations [Abstract]

Regulatory Matters (All Registrants)

As discussed in Note 3 — Regulatory Matters of the Exelon 2021 Form 10-K, the Registrants are involved in rate and regulatory proceedings at FERC and their state commissions. The following discusses developments in 2022 and updates to the 2021 Form 10-K.

Distribution Base Rate Case Proceedings

The following tables show the completed and pending distribution base rate case proceedings in 2022.

Completed Distribution Base Rate Case Proceedings


Registrant/Jurisdiction	Filing Date	Service	Requested Revenue Requirement Increase		Approved Revenue Requirement Increase		Approved ROE		Approval Date	Rate Effective Date
ComEd - Illinois(a)	April 16, 2021	Electric	$	51	$	46	7.36	%	December 1, 2021	January 1, 2022
PECO - Pennsylvania	March 30, 2021	Electric	246		132		N/A(b)		November 18, 2021	January 1, 2022
BGE - Maryland(c)	May 15, 2020 (amended September 11, 2020)	Electric	203		140		9.50	%	December 16, 2020	January 1, 2021
		Natural Gas	108		74		9.65	%
Pepco - District of Columbia(d)	May 30, 2019 (amended June 1, 2020)	Electric	136		109		9.275	%	June 8, 2021	July 1, 2021
Pepco - Maryland(e)	October 26, 2020 (amended March 31, 2021)	Electric	104		52		9.55	%	June 28, 2021	June 28, 2021
DPL - Maryland(f)	September 1, 2021 (amended December 23, 2021)	Electric	27		13		9.60	%	March 2, 2022	March 2, 2022
ACE - New Jersey(g)	December 9, 2020 (amended February 26, 2021)	Electric	67		41		9.60	%	July 14, 2021	January 1, 2022

__________

(a)ComEd's 2022 approved revenue requirement reflects an increase of $37 million for the initial year revenue requirement for 2022 and an increase of $9 million related to the annual reconciliation for 2020. The revenue requirement for 2022 provides for a weighted average debt and equity return on distribution rate base of 5.72%, inclusive of an allowed ROE of 7.36%, reflecting the monthly average yields for 30-year treasury bonds plus 580 basis points. The reconciliation revenue requirement for 2020 provides for a weighted average debt and equity return on distribution rate base of 5.69%, inclusive of an allowed ROE of 7.29%, reflecting the monthly yields on 30-year treasury bonds plus 580 basis points less a performance metrics penalty of 7 basis points.

(b)The PECO electric base rate case proceeding was resolved through a settlement agreement, which did not specify an approved ROE.

(c)Reflects a three-year cumulative multi-year plan for 2021 through 2023. The MDPSC awarded BGE electric revenue requirement increases of $59 million, $39 million, and $42 million, before offsets, in 2021, 2022, and 2023, respectively, and natural gas revenue requirement increases of $53 million, $11 million, and $10 million, before offsets, in 2021, 2022, and 2023, respectively. BGE proposed to use certain tax benefits to fully offset the increases in 2021 and 2022 and partially offset the increase in 2023. However, the MDPSC utilized the tax benefits to fully offset the increases in 2021 and January 2022 such that customer rates remained unchanged. For the remainder of 2022, the MDPSC chose to offset only 25% of the cumulative 2021 and 2022 electric revenue requirement increases and 50% of the cumulative gas revenue requirement increases. Whether certain tax benefits will be used to offset the customer rate increases in 2023 has not been decided, and BGE cannot predict the outcome.

(d)Reflects a cumulative multi-year plan with 18-months remaining in 2021 through 2022. The DCPSC awarded Pepco electric incremental revenue requirement increases of $42 million and $67 million, before offsets, for 2021 and 2022, respectively. 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 2021 and 2022, respectively.

(e)Reflects a three-year cumulative multi-year plan for April 1, 2021 through March 31, 2024. The MDPSC awarded Pepco electric incremental revenue requirement increases of $21 million, $16 million, and $15 million, before offsets, for the 12-month periods ending March 31, 2022, 2023, and 2024, respectively. Pepco proposed to utilize certain tax benefits to fully offset the increase through 2023 and partially offset customer rate increases in 2024. However, the MDPSC only utilized the acceleration of refunds for certain tax benefits to fully offset the increases such that customer rates remain unchanged through March 31, 2022. On February 23, 2022, the MDPSC chose to offset 25% of the cumulative revenue requirement increase for the 12-month period ending March 31, 2023. Whether certain tax benefits will be used to offset the customer rate increases for the 12-month period ending March 31, 2024 has not been decided, and Pepco cannot predict the outcome.

(f)The approved settlement reflects a 9.60% ROE, which is solely for the purposes of calculating AFUDC and regulatory asset carrying costs.

(g)Requested and approved increases are before New Jersey sales and use tax. The order allows ACE to retain approximately $11 million of certain tax benefits which resulted in a decrease to income tax expense in Exelon's, PHI's, and ACE's Consolidated Statements of Operations and Comprehensive Income in the third quarter of 2021.

Pending Distribution Base Rate Case Proceedings

Registrant/Jurisdiction

Filing Date

Service

Requested Revenue Requirement Increase

Requested ROE

Expected Approval Timing

ComEd - Illinois(a)

April 15, 2022

Electric

199

7.85

Fourth quarter of 2022

PECO - Pennsylvania

March 31, 2022

Natural Gas

10.95

Fourth quarter of 2022

DPL - Delaware(b)

January 14, 2022 (amended February 28, 2022)

Natural Gas

10.30

First quarter of 2023

__________

(a)ComEd's 2023 requested revenue requirement reflects an increase of $144 million for the initial year revenue requirement for 2023 and an increase of $55 million related to the annual reconciliation for 2021. The revenue requirement for 2023 provides for a weighted average debt and equity return on distribution rate base of 5.94%, inclusive of an allowed ROE of 7.85%, reflecting the average monthly yields for 30-year treasury bonds plus 580 basis points. The reconciliation revenue requirement for 2021 provides for a weighted average debt and equity return on distribution rate base of 5.91%, inclusive of an allowed ROE of 7.78%, reflecting the average monthly yields for 30-year treasury bonds plus 580 basis points less a performance metrics penalty of 7 basis points. This is ComEd's last performance-based electric distribution formula rate update filing under EIMA as a result of the law authorizing the rate setting process sunsetting at the end of 2022. See Note 3. - Regulatory Matters of the Exelon 2021 Form 10-K for additional information on ComEd's transition away from the electric distribution formula rate.

(b)The rates will go into effect on August 14, 2022, subject to refund.

Transmission Formula Rates

The Utility Registrants' transmission rates are each established based on a FERC-approved formula. ComEd, BGE, Pepco, DPL, and ACE are required to file an annual update to the FERC-approved formula on or before May 15, and PECO is required to file on or before May 31, with the resulting rates effective on June 1 of the same year. The annual update for ComEd is based on prior year actual costs and current year projected capital additions (initial year revenue requirement). The update for ComEd also reconciles any differences between the revenue requirement in effect beginning June 1 of the prior year and actual costs incurred for that year (annual reconciliation). The annual update for BGE is based on prior year actual costs and current year projected capital additions, accumulated depreciation, depreciation and amortization expense, and accumulated deferred income taxes. The update for BGE also reconciles any differences between the actual costs and actual revenues for the calendar year (annual reconciliation).

For 2022, the following total increases were included in ComEd’s and BGE's electric transmission formula rate update. PECO, Pepco, DPL, and ACE intend to file by the required deadline for the annual update.


Registrant(a)	Initial Revenue Requirement Increase		Annual Reconciliation Decrease		Total Revenue Requirement Increase			Allowed Return on Rate Base(c)		Allowed ROE(d)
ComEd	$	24	$	(24)	$	—		8.11	%	11.50	%
BGE	25		(4)		16		(b)	7.30	%	10.50	%

(a)All rates are effective June 1, 2022 - May 31, 2023, subject to review by interested parties pursuant to review protocols of ComEd's and BGE's tariff.

(b)The increase in BGE's transmission revenue requirement includes a $5 million reduction related to a FERC-approved dedicated facilities charge to recover the costs of providing transmission service to specifically designated load by BGE.

(c)Represents the weighted average debt and equity return on transmission rate bases.

(d)As part of the FERC-approved settlements of ComEd’s 2007 transmission rate case, the rate of return on common equity is 11.50%, inclusive of a 50-basis-point incentive adder for being a member of a RTO, and the common equity component of the ratio used to calculate the weighted average debt and equity return for the transmission formula rate is currently capped at 55%. As part of the FERC-approved settlement of the ROE complaint against BGE, the rate of return on common equity is 10.50%, inclusive of a 50-basis-point incentive adder for being a member of a RTO.

Other State Regulatory Matters

Illinois Regulatory Matters

CEJA (Exelon and ComEd). On September 15, 2021, the Governor of Illinois signed into law CEJA. CEJA includes, among other features, (1) procurement of CMCs from qualifying nuclear-powered generating facilities, (2) a requirement to file a general rate case or a new four-year multi-year plan no later than January 20, 2023 to establish rates effective after ComEd’s existing performance-based distribution formula rate sunsets, (3) an extension of and certain adjustments to ComEd’s energy efficiency MWh savings goals, (4) revisions to the Illinois RPS requirements, including expanded charges for the procurement of RECs from wind and solar generation, (5) a requirement to accelerate amortization of ComEd’s unprotected excess deferred income taxes ("EDIT") that ComEd was previously directed by the ICC to amortize using the average rate assumption method which equates to approximately 39.5 years, and (6) requirements that the ICC initiate and conduct various regulatory proceedings on subjects including ethics, spending, grid investments, and performance metrics. Regulatory or legal challenges regarding the validity or implementation of CEJA are possible and Exelon and ComEd cannot reasonably predict the outcome of any such challenges.

The ICC initiated a docket to accelerate and fully credit to customers TCJA unprotected property-related EDIT no later than December 31, 2025. On April 13, 2022, a stipulation and agreement on the schedule for the acceleration of EDIT amortization was submitted by ComEd, the Illinois Attorney General's Office, and the Citizens Utility Board. At this time, ComEd cannot predict an outcome of these proceedings.

See Note 3 — Regulatory Matters of the Exelon 2021 Form 10-K for additional information on CEJA (referred to as Clean Energy Law).

New Jersey Regulatory Matters

Termination of Energy Procurement Provisions of PPAs (Exelon, PHI, and ACE).

On December 22, 2021, ACE filed with the NJBPU a petition to terminate the provisions in the PPAs to purchase electricity from two coal-powered generation facilities located in the state of New Jersey. The petition was approved by the NJBPU on March 23, 2022. Upon closing of the transaction on March 31, 2022, ACE recognized a liability of $203 million for the contract termination fee, which is to be paid by the end of 2024, and recognized a corresponding regulatory asset of $203 million.

As of March 31, 2022, the $203 million liability for the contract termination fee consists of $85 million and $118 million included in Other current liabilities and Other deferred credits and other liabilities, respectively, in Exelon's Consolidated Balance Sheet. As of March 31, 2022, the current and noncurrent liability is included in PPA termination obligation and Other deferred credits and other liabilities, respectively, in PHI's and ACE's Consolidated Balance Sheets.

Regulatory Assets and Liabilities

The Utility Registrants' regulatory assets and liabilities have not changed materially since December 31, 2021, unless noted below. See Note 3 — Regulatory Matters of the Exelon 2021 Form 10-K for additional information on the specific regulatory assets and liabilities.

PECO. Regulatory assets increased $66 million primarily due to an increase of $60 million in the Deferred Income Taxes regulatory asset. Regulatory liabilities decreased by $112 million primarily due to a decrease of $111 million in the Nuclear Decommissioning regulatory liability.

BGE. Regulatory assets decreased $50 million primarily due to a decrease of $19 million in the Electric Energy and Natural Gas Costs regulatory asset and $16 million in the Energy Efficiency and Demand Response Programs regulatory asset. Regulatory liabilities decreased $53 million primarily due to a decrease of $65 million in the Deferred Income Taxes regulatory liability.

ACE. Regulatory assets increased $205 million primarily due to an increase in the Electric Energy Costs regulatory asset as a result of the PPA termination. Regulatory liabilities decreased $19 million primarily due to a decrease of $9 million in the Deferred Income Taxes regulatory liability and $5 million in the Electric Energy Costs regulatory liability.

Capitalized Ratemaking Amounts Not Recognized

The following table presents authorized amounts capitalized for ratemaking purposes related to earnings on shareholders' investment that are not recognized for financial reporting purposes in the Registrants' Consolidated Balance Sheets. These amounts will be recognized as revenues in the related Consolidated Statements of Operations and Comprehensive Income in the periods they are billable to the Utility Registrants' customers.


	Exelon		ComEd(a)		PECO		BGE(b)		PHI		Pepco(c)		DPL(c)		ACE
March 31, 2022	$	49	$	2	$	—	$	34	$	13	$	11	$	2	$	—

December 31, 2021	43		1		—		37		5		3		2		—

__________

(a)Reflects ComEd's unrecognized equity returns earned for ratemaking purposes on its energy efficiency and electric distribution formula rate regulatory assets.

(b)BGE's authorized amounts capitalized for ratemaking purposes primarily relate to earnings on shareholder's investment on its AMI programs.

(c)Pepco's and DPL's authorized amounts capitalized for ratemaking purposes relate to earnings on shareholder's investment on their respective AMI Programs and Energy Efficiency and Demand Response Programs, and for Pepco District of Columbia revenue decoupling program. The earnings on energy efficiency are on Pepco District of Columbia and DPL Delaware programs only.

Revenue from Contracts with Customers (All Registrants)

3 Months Ended

Mar. 31, 2022

Revenue from Contract with Customer [Abstract]

Revenue from Contracts with Customers (All Registrants)

The Registrants recognize revenue from contracts with customers to depict the transfer of goods or services to customers at an amount that the entities expect to be entitled to in exchange for those goods or services. The primary sources of revenue include regulated electric and gas tariff sales, distribution, and transmission services.

See Note 4 — Revenue from Contracts with Customers of the Exelon 2021 Form 10-K for additional information regarding the primary sources of revenue for the Registrants.

Contract Liabilities

The Registrants record contract liabilities when consideration is received or due prior to the satisfaction of the performance obligations. The Registrants record contract liabilities in Other current liabilities and Other noncurrent liabilities in their Consolidated Balance Sheets.

For PHI, Pepco, DPL, and ACE these contract liabilities primarily relate to upfront consideration received in the third quarter of 2020 for a collaborative arrangement with an unrelated owner and manager of communication infrastructure. The revenue attributable to this arrangement will be recognized as operating revenue over the 35 years under the collaborative arrangement.

Revenues recognized were immaterial for Exelon, PHI, Pepco, DPL, and ACE for the three months ended March 31, 2022 and 2021. As of March 31, 2022 and December 31, 2021, ComEd's, PECO's, and BGE's contract liabilities were immaterial.

Transaction Price Allocated to Remaining Performance Obligations

The following table shows the amounts of future revenues expected to be recorded in each year for performance obligations that are unsatisfied or partially unsatisfied as of March 31, 2022. This disclosure only includes contracts for which the total consideration is fixed and determinable at contract inception. The average contract term varies by customer type and commodity but ranges from one month to several years.

This disclosure excludes the Utility Registrants' gas and electric tariff sales contracts and transmission revenue contracts as they generally have an original expected duration of one year or less and, therefore, do not contain any future, unsatisfied performance obligations to be included in this disclosure.


	2022		2023		2024		2025		2026 and thereafter		Total
Exelon	$	6	$	8	$	6	$	5	$	82	$	107
PHI	6		8		6		5		82		107
Pepco	4		6		5		5		65		85
DPL	1		1		—		—		9		11
ACE	1		1		1		—		8		11

Revenue Disaggregation

The Registrants disaggregate revenue recognized from contracts with customers into categories that depict how the nature, amount, timing, and uncertainty of revenue and cash flows are affected by economic factors. See Note 5 — Segment Information for the presentation of the Registrant's revenue disaggregation.

The entire disclosure of revenue from contract with customer to transfer good or service and to transfer nonfinancial asset. Includes, but is not limited to, disaggregation of revenue, credit loss recognized from contract with customer, judgment and change in judgment related to contract with customer, and asset recognized from cost incurred to obtain or fulfill contract with customer. Excludes insurance and lease contracts.

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Segment Information (All Registrants)

Segment Information (All Registrants)

3 Months Ended

Mar. 31, 2022

Segment Reporting [Abstract]

Operating segments for each of the Registrants are determined based on information used by the CODMs in deciding how to evaluate performance and allocate resources at each of the Registrants.

Exelon has six reportable segments, which include ComEd, PECO, BGE, and PHI's three reportable segments consisting of Pepco, DPL, and ACE. ComEd, PECO, BGE, Pepco, DPL, and ACE each represent a single reportable segment, and as such, no separate segment information is provided for these Registrants. Exelon, ComEd, PECO, BGE, Pepco, DPL, and ACE's CODMs evaluate the performance of and allocate resources to ComEd, PECO, BGE, Pepco, DPL, and ACE based on net income.

An analysis and reconciliation of the Registrants’ reportable segment information to the respective information in the consolidated financial statements for the three months ended March 31, 2022 and 2021 is as follows:

Three Months Ended March 31, 2022 and 2021


	ComEd		PECO		BGE		PHI		Other(a)		Intersegment Eliminations		Exelon
Operating revenues(b):
2022
Electric revenues	$	1,734	$	741	$	736	$	1,318	$	—	$	(7)	$	4,522
Natural gas revenues	—		306		418		83		—		(2)		$	805
Shared service and other revenues	—		—		—		3		576		(579)		$	—
Total operating revenues	$	1,734	$	1,047	$	1,154	$	1,404	$	576	$	(588)	$	5,327
2021
Electric revenues	$	1,535	$	661	$	632	$	1,170	$	—	$	(7)	$	3,991
Natural gas revenues	—		228		342		71		—		—		641
Shared service and other revenues	—		—		—		3		491		(494)		—
Total operating revenues	$	1,535	$	889	$	974	$	1,244	$	491	$	(501)	$	4,632

Intersegment revenues(c):
2022	$	6	$	1	$	7	$	3	$	576	$	(587)	$	6
2021	6		2		6		3		487		(497)		7
Depreciation and amortization:
2022	$	321	$	92	$	171	$	218	$	15	$	—	$	817
2021	292		86		152		210		17		—		757
Operating expenses:
2022	$	1,406	$	793	$	919	$	1,215	$	625	$	(531)	$	4,427
2021	1,210		679		752		1,058		448		(339)		3,808
Interest expense, net:
2022	$	100	$	41	$	35	$	69	$	93	$	—	$	338
2021	96		38		34		67		83		—		318
Income (loss) from continuing operations before income taxes:
2022	$	240	$	220	$	207	$	137	$	(62)	$	(43)	$	699
2021	236		177		196		136		(32)		(149)		564
Income Taxes:
2022	$	52	$	14	$	9	$	7	$	146	$	(10)	$	218
2021	39		10		(13)		8		7		(12)		39
Net income (loss) from continuing operations:
2022	$	188	$	206	$	198	$	130	$	(208)	$	(33)	$	481
2021	197		167		209		128		(39)		(137)		525
Capital Expenditures:
2022	$	617	$	344	$	303	$	409	$	22	$	—	$	1,695
2021	613		295		336		456		46		—		1,746
Total assets:
March 31, 2022	$	37,013	$	14,113	$	12,509	$	25,636	$	7,583	$	(4,156)	$	92,698
December 31, 2021	36,470		13,824		12,324		24,744		7,634		(8,319)		86,677

__________

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

(b)Includes gross utility tax receipts from customers. The offsetting remittance of utility taxes to the governing bodies is recorded in expenses in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. See Note 14 — Supplemental Financial Information for additional information on total utility taxes.

(c)See Note 15 — Related Party Transactions for additional information on intersegment revenues.

PHI:


	Pepco		DPL		ACE		Other(a)		Intersegment Eliminations		PHI
Operating revenues(b):
2022
Electric revenues	$	614	$	348	$	349	$	—	$	7	$	1,318
Natural gas revenues	—		83		—		—		—		83
Shared service and other revenues	—		—		—		107		(104)		3
Total operating revenues	$	614	$	431	$	349	$	107	$	(97)	$	1,404
2021
Electric revenues	$	553	$	311	$	310	$	—	$	(4)	$	1,170
Natural gas revenues	—		71		—		—		—		71
Shared service and other revenues	—		—		—		95		(92)		3
Total operating revenues	$	553	$	382	$	310	$	95	$	(96)	$	1,244
Intersegment revenues(c):
2022	$	1	$	1	$	1	$	97	$	(97)	$	3
2021	1		2		1		95		(96)		3
Depreciation and amortization:
2022	$	108	$	57	$	47	$	6	$	—	$	218
2021	102		53		47		8		—		210
Operating expenses:
2022	$	547	$	357	$	311	$	97	$	(97)	$	1,215
2021	466		309		282		97		(96)		1,058
Interest expense, net:
2022	$	36	$	16	$	14	$	3	$	—	$	69
2021	34		15		15		3		—		67
Income (loss) before income taxes:
2022	$	44	$	60	$	27	$	6	$	—	$	137
2021	65		61		14		(4)		—		136
Income Taxes:
2022	$	(2)	$	4	$	1	$	4	$	—	$	7
2021	6		5		—		(3)		—		8
Net income (loss):
2022	$	46	$	56	$	26	$	2	$	—	$	130
2021	59		56		14		(1)		—		128
Capital Expenditures:
2022	$	218	$	103	$	87	$	1	$	—	$	409
2021	220		112		123		1		—		456
Total assets:
March 31, 2022	$	10,458	$	5,573	$	4,929	$	4,720	$	(44)	$	25,636
December 31, 2021	9,903		5,412		4,556		4,933		(60)		24,744

__________

(a)Other primarily includes PHI’s corporate operations, shared service entities, and other financing and investment activities.

(c)Includes intersegment revenues with ComEd, BGE, and PECO, which are eliminated at Exelon.

The following tables disaggregate the Registrants' revenues recognized from contracts with customers into categories that depict how the nature, amount, timing, and uncertainty of revenue and cash flows are affected by economic factors. For the Utility Registrants, the disaggregation of revenues reflects the two primary utility services of electric sales and natural gas sales (where applicable), with further disaggregation of these tariff sales provided by major customer groups. Exelon’s disaggregated revenues are consistent with the Utility Registrants, but exclude any intercompany revenues.



	Three Months Ended March 31, 2022
Revenues from contracts with customers	ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Electric revenues
Residential	$	857	$	487	$	417	$	652	$	275	$	207	$	170
Small commercial & industrial	423		111		81		141		38		56		47
Large commercial & industrial	153		64		131		323		253		26		44
Public authorities & electric railroads	14		8		7		16		8		4		4
Other(a)	239		62		97		193		46		56		81
Total electric revenues(b)	$	1,686	$	732	$	733	$	1,325	$	620	$	349	$	346
Natural gas revenues
Residential	$	—	$	218	$	282	$	51	$	—	$	51	$	—
Small commercial & industrial	—		76		45		21		—		21		—
Large commercial & industrial	—		—		65		3		—		3		—
Transportation	—		8		—		4		—		4		—
Other(c)	—		3		35		4		—		4		—
Total natural gas revenues(d)	$	—	$	305	$	427	$	83	$	—	$	83	$	—
Total revenues from contracts with customers	$	1,686	$	1,037	$	1,160	$	1,408	$	620	$	432	$	346

Other revenues
Revenues from alternative revenue programs	$	40	$	6	$	(12)	$	(5)	$	(7)	$	(1)	$	3
Other electric revenues(e)	8		3		4		1		1		—		—
Other natural gas revenues(e)	—		1		2		—		—		—		—

Total other revenues	$	48	$	10	$	(6)	$	(4)	$	(6)	$	(1)	$	3
Total revenues for reportable segments	$	1,734	$	1,047	$	1,154	$	1,404	$	614	$	431	$	349



	Three Months Ended March 31, 2021
Revenues from contracts with customers	ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Electric revenues
Residential	$	741	$	433	$	362	$	605	$	253	$	190	$	162
Small commercial & industrial	367		100		69		118		33		46		39
Large commercial & industrial	134		57		105		248		184		21		43
Public authorities & electric railroads	11		9		7		13		6		4		3
Other(a)	220		52		77		143		51		41		52
Total electric revenues(b)	$	1,473	$	651	$	620	$	1,127	$	527	$	302	$	299
Natural gas revenues
Residential	$	—	$	160	$	216	$	46	$	—	$	46	$	—
Small commercial & industrial	—		59		35		18		—		18		—
Large commercial & industrial	—		—		54		2		—		2		—
Transportation	—		7		—		4		—		4		—
Other(c)	—		2		31		1		—		1		—
Total natural gas revenues(d)	$	—	$	228	$	336	$	71	$	—	$	71	$	—
Total revenues from contracts with customers	$	1,473	$	879	$	956	$	1,198	$	527	$	373	$	299

Other revenues
Revenues from alternative revenue programs	$	54	$	10	$	18	$	46	$	26	$	9	$	11
Other electric revenues(e)	8		—		—		—		—		—		—


Total other revenues	$	62	$	10	$	18	$	46	$	26	$	9	$	11
Total revenues for reportable segments	$	1,535	$	889	$	974	$	1,244	$	553	$	382	$	310

__________

(a)Includes revenues from transmission revenue from PJM, wholesale electric revenue and mutual assistance revenue.

(b)Includes operating revenues from affiliates in 2022 and 2021 respectively of:

•$6 million, $6 million at ComEd

•$1 million, $1 million at PECO

•$2 million, $2 million at BGE

•$3 million, $3 million at PHI

•$1 million, $1 million at Pepco

•$2 million, $2 million at DPL

•$1 million, $1 million at ACE

(c)Includes revenues from off-system natural gas sales.

(d)Includes operating revenues from affiliates in 2022 and 2021 respectively of:

•less than $1 million, less than $1 million at PECO

•$6 million, $4 million at BGE

(e)Includes late payment charge revenues.

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

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Accounts Receivable (All Registrants)

Accounts Receivable (All Registrants)

3 Months Ended

Mar. 31, 2022

Credit Loss [Abstract]

Allowance for Credit Losses on Accounts Receivable

The following tables present the rollforward of Allowance for Credit Losses on Customer Accounts Receivable.
















	Three Months Ended March 31, 2022
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2021	$	320	$	73	$	105	$	38	$	104	$	37	$	18	$	49
Plus: Current period provision for expected credit losses(a)	110		26		31		26		27		11		7		9
Less: Write-offs, net of recoveries(b)(c)	41		7		11		5		18		8		1		9
Balance as of March 31, 2022	$	389	$	92	$	125	$	59	$	113	$	40	$	24	$	49

	Three Months Ended March 31, 2021
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2020	$	334	$	97	$	116	$	35	$	86	$	32	$	22	$	32
Plus: Current period provision for expected credit losses(d)	70		21		20		9		20		11		6		3
Less: Write-offs, net of recoveries(b)	27		15		6		1		5		2		3		—
Balance as of March 31, 2021	$	377	$	103	$	130	$	43	$	101	$	41	$	25	$	35

__________

(a)For PECO, BGE and ACE, the increase is primarily as a result of increased receivable balances due to the increased aging of receivables. For BGE, also reflects increased receivable balance due to colder weather.

(b)Recoveries were not material to the Registrants.

(c)For ACE, the increase in 2022 is primarily related to the termination of the moratorium, which beginning in March 2020, prevented customer disconnections for non-payment. With disconnection activities restarting in January 2022, write-offs of aging accounts receivable increased throughout the year.

(d)The increase is primarily as a result of increased receivable balances due to the colder weather and the increased aging of receivables, the temporary suspension of customer disconnections for non-payment, temporary cessation of new late payment fees, and reconnection of service for customers previously disconnected due to COVID-19.

The following tables present the rollforward of Allowance for Credit Losses on Other Accounts Receivable.
















	Three Months Ended March 31, 2022
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2021	$	72	$	17	$	7	$	9	$	39	$	16	$	8	$	15
Plus: Current period provision for expected credit losses	14		4		3		3		4		2		1		1
Less: Write-offs, net of recoveries(a)	5		1		1		1		2		—		—		2
Balance as of March 31, 2022	$	81	$	20	$	9	$	11	$	41	$	18	$	9	$	14

	Three Months Ended March 31, 2021
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2020	$	71	$	21	$	8	$	9	$	33	$	13	$	9	$	11
Plus: Current period provision for expected credit losses	10		1		4		1		4		2		1		1
Less: Write-offs, net of recoveries(a)	2		—		1		1		—		—		—		—
Balance as of March 31, 2021	$	79	$	22	$	11	$	9	$	37	$	15	$	10	$	12

__________

(a)Recoveries were not material to the Registrants.

Unbilled Customer Revenue

The following table provides additional information about unbilled customer revenues recorded in the Registrants' Consolidated Balance Sheets as of March 31, 2022 and December 31, 2021.


	Unbilled customer revenues(a)
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
March 31, 2022	$	629	$	189	$	127	$	139	$	174	$	89	$	50	$	35
December 31, 2021	747		240		161		171		175		82		53		40

__________

(a)Unbilled customer revenues are classified in Customer accounts receivables, net in the Registrants' Consolidated Balance Sheets.

Other Purchases of Customer and Other Accounts Receivables

The Utility Registrants are required, under separate legislation and regulations in Illinois, Pennsylvania, Maryland, District of Columbia, Delaware, and New Jersey, to purchase certain receivables from alternative retail electric and, as applicable, natural gas suppliers that participate in the utilities' consolidated billing. The following tables present the total receivables purchased.


	Total receivables purchased
	Exelon(a)		ComEd		PECO		BGE(a)		PHI		Pepco		DPL		ACE
Three months ended March 31, 2022	$	1,044	$	248	$	292	$	222	$	282	$	174	$	57	$	51
Three months ended March 31, 2021	1,023		266		290		199		268		166		56		46

__________

(a)Includes $4 million and $12 million of receivables purchased from Generation for the three months ended March 31, 2022 and 2021, respectively.

Nuclear Decommissioning (Exelon and Generation)	3 Months Ended
Nuclear Decommissioning (Exelon and Generation)	Mar. 31, 2022
Asset Retirement Obligation Disclosure [Abstract]
Nuclear Decommissioning (Exelon and Generation)	Nuclear Decommissioning (Exelon) Accounting Implications of the Regulatory Agreements with ComEd and PECO Based on the regulatory agreements with the ICC and PAPUC that dictate Generation’s obligations related to the shortfall or excess of NDT funds necessary for decommissioning the former ComEd units on a unit-by-unit basis and the former PECO units in total, decommissioning-related activities 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 and Comprehensive Income and are recorded by Generation and the corresponding regulated utility as a component of the intercompany and regulatory balances on the balance sheet. For the purposes of making this determination, the decommissioning obligation referred to is different from the calculation used in the NRC minimum funding obligation filings based on NRC guidelines. For the former ComEd units, given no further recovery from ComEd customers is permitted and Generation retains an obligation to ultimately return any unused NDTs to ComEd customers (on a unit-by-unit basis), to the extent the related NDT investment balances are expected to exceed the total estimated decommissioning obligation for each unit, the offset of decommissioning-related activities within the Consolidated Statements of Operations and Comprehensive Income results with Generation recognizing an intercompany payable to ComEd while ComEd records an intercompany receivable from Generation with a corresponding regulatory liability. However, given the asymmetric settlement provision that does not allow for continued recovery from ComEd customers in the event of a shortfall, recognition of a regulatory asset at ComEd is not permissible and accounting for decommissioning-related activities at Generation for that unit would not be offset, and the impact to Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income could be material during such periods. During the second quarter of 2022, a pre-tax charge of $53 million was recorded in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income for decommissioning-related activities that were not offset for the Byron units due to contractual offset being suspended. Generation believes that additional growth of the NDT funds for the Byron units will ultimately be sufficient to cover the future costs of decommissioning. As of March 31, 2022, decommissioning-related activities for all of the former ComEd units, except for Byron (see discussion above) and Zion (see Note 10 – Asset Retirement Obligations of the Exelon 2021 Form 10-K), are currently offset within Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income. The decommissioning-related activities related to the Non-Regulatory Agreement Units are reflected in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income. See Note 10 – Asset Retirement Obligations of the Exelon 2021 Form 10-K for additional information, including the former PECO units.

Income Taxes (All Registrants)

3 Months Ended

Mar. 31, 2022

Income Tax Disclosure [Abstract]

Income Taxes (All Registrants)

Rate Reconciliation

The effective income tax rate from continuing operations varies from the U.S. federal statutory rate principally due to the following:


	Three Months Ended March 31, 2022(a)
	Exelon		ComEd		PECO(b)		BGE(b)		PHI		Pepco(b)		DPL		ACE(b)
U.S. Federal statutory rate	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit(c)	21.1		8.0		(0.1)		2.4		3.7		(4.5)		6.2		6.8
Plant basis differences	(3.6)		(0.6)		(11.3)		(0.9)		(1.6)		(2.6)		(0.7)		(1.3)
Excess deferred tax amortization	(11.5)		(6.3)		(3.2)		(17.6)		(17.7)		(17.4)		(19.4)		(22.2)
Amortization of investment tax credit, including deferred taxes on basis difference	(0.1)		(0.1)		—		(0.1)		(0.1)		—		(0.2)		(0.2)
Tax credits(d)	1.7		(0.3)		—		(0.4)		(0.4)		(0.4)		(0.3)		(0.3)
Other(e)	2.6		—		—		(0.1)		0.2		(0.6)		0.1		(0.1)
Effective income tax rate	31.2	%	21.7	%	6.4	%	4.3	%	5.1	%	(4.5)	%	6.7	%	3.7	%


	Three Months Ended March 31, 2021(a)
	Exelon		ComEd		PECO(f)		BGE(f)		PHI		Pepco		DPL		ACE(f)
U.S. Federal statutory rate	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	2.8		6.8		(1.6)		(10.1)		6.1		5.5		6.4		6.9
Plant basis differences	(3.4)		(0.6)		(10.5)		(1.4)		(1.5)		(2.1)		(0.7)		(0.9)
Excess deferred tax amortization	(12.0)		(6.9)		(3.2)		(15.5)		(19.3)		(15.1)		(18.5)		(28.7)
Amortization of investment tax credit, including deferred taxes on basis difference	(0.1)		(0.1)		—		(0.1)		(0.1)		—		(0.2)		(0.2)
Tax credits	(0.3)		(0.2)		—		(0.4)		(0.2)		(0.2)		(0.1)		(0.3)
Other	(1.1)		(3.5)		(0.1)		(0.1)		(0.1)		0.1		0.3		2.2
Effective income tax rate	6.9	%	16.5	%	5.6	%	(6.6)	%	5.9	%	9.2	%	8.2	%	—	%

__________

(a)Positive percentages represent income tax expense. Negative percentages represent income tax benefit.

(b)For PECO, the lower effective tax rate is primarily related to plant basis differences attributable to tax repair deductions. For BGE, the lower effective tax rate is primarily due to the Maryland multi-year plan which resulted in the acceleration of certain income tax benefits. For Pepco, the income tax benefit is primarily due to the Maryland and Washington, D.C. multi-year plans which resulted in the acceleration of certain income tax benefits. For ACE, the lower effective tax rate is primarily due to the acceleration of certain income tax benefits due to distribution rate case settlements.

(c)For Exelon, the higher state income taxes, net of federal income tax benefit, is primarily due to the long-term marginal state income tax rate change of approximately $67 million and the recognition of a valuation allowance of approximately $40 million against the net deferred tax asset position for certain standalone state filing jurisdictions as a result of the separation.

(d)For Exelon, reflects the income tax expense related to the write-off of federal tax credits subject to recapture of approximately $15 million as a result of the separation.

(e)For Exelon, primarily reflects the nondeductible transaction costs of approximately $19 million arising as part of the separation.

(f)For PECO, the lower effective tax rate is primarily related to plant basis differences attributable to tax repair deductions. For BGE, the income tax benefit is primarily due to the Maryland multi-year plan which resulted in the acceleration of

certain income tax benefits. For ACE, the lower effective tax rate is primarily due to the acceleration of certain income tax benefits due to distribution rate case settlements.

Unrecognized Tax Benefits

Exelon, PHI and ACE have the following unrecognized tax benefits as of March 31, 2022 and December 31, 2021. ComEd's, PECO's, BGE's, Pepco's, and DPL's amounts are not material.


	Exelon		PHI		ACE
March 31, 2022	$	146	$	56	$	16
December 31, 2021	143		56		16

__________

(a)As of March 31, 2022, Exelon recorded a receivable of approximately $50 million in Noncurrent other assets in the Consolidated Balance Sheet for Constellation’s share of unrecognized tax benefits for periods prior to the separation.

Reasonably possible the total amount of unrecognized tax benefits could significantly increase or decrease within 12 months after the reporting date

As of March 31, 2022, ACE has approximately $14 million of unrecognized state tax benefits that could significantly decrease within the 12 months after the reporting date based on the outcome of pending court cases involving other taxpayers. The unrecognized tax benefit, if recognized, may be included in future base rates and that portion would have no impact to the effective tax rate.

Other Tax Matters

Separation (Exelon)

In connection with the separation, Exelon recorded an income tax expense related to continuing operations of approximately $148 million primarily due to the long-term marginal state income tax rate change of approximately $67 million discussed further below, the recognition of valuation allowances of approximately $40 million against the net deferred tax assets positions for certain standalone state filing jurisdictions, the write-off of federal and state tax credits subject to recapture of approximately $17 million, and nondeductible transaction costs for federal and state taxes of approximately $24 million.

Tax Matters Agreement (Exelon)

In connection with the separation, Exelon entered into a TMA with Constellation. The TMA governs the respective rights, responsibilities, and obligations between Exelon and Constellation after the separation with respect to tax liabilities, refunds and attributes for open tax years that Constellation was part of Exelon’s consolidated group for U.S. federal, state, and local tax purposes.

Indemnification for Taxes. As a former subsidiary of Exelon, Constellation has joint and several liability with Exelon to the IRS and certain state jurisdictions relating to the taxable periods prior to the separation. The TMA specifies that Constellation is liable for their share of taxes required to be paid by Exelon with respect to taxable periods prior to the separation to the extent Constellation would have been responsible for such taxes under the existing Exelon tax sharing agreement. As of March 31, 2022, Exelon recorded a receivable of approximately $55 million in Current other assets in the Consolidated Balance Sheet for Constellation’s share of taxes for periods prior to the separation.

Tax Refunds. The TMA specifies that Constellation is entitled to their share of any future tax refunds claimed by Exelon with respect to taxable periods prior to the separation to the extent that Constellation would have received such tax refunds under the existing Exelon tax sharing agreement.

Tax Attributes. At the date of separation certain tax attributes, primarily pre-closing tax credit carryforwards, that were generated by Constellation were required by law to be allocated to Exelon. The TMA also provides that Exelon will reimburse Constellation when those allocated tax credit carryforwards are utilized. As of March 31, 2022, Exelon recorded a payable of approximately $11 million and $484 million in Current other liabilities and Noncurrent other liabilities, respectively, in the Consolidated Balance Sheet for tax credit carryforwards that are expected to be utilized and reimbursed to Constellation.

Long-Term Marginal State Income Tax Rate (All Registrants)In the first quarter of 2022, Exelon updated its marginal state income tax rates for changes in state apportionment due to the separation, which resulted in an increase of approximately $67 million to the deferred tax liability at Exelon, and a corresponding adjustment to income tax expense, net of federal taxes.

The entire disclosure for income taxes. Disclosures may include net deferred tax liability or asset recognized in an enterprise's statement of financial position, net change during the year in the total valuation allowance, approximate tax effect of each type of temporary difference and carryforward that gives rise to a significant portion of deferred tax liabilities and deferred tax assets, utilization of a tax carryback, and tax uncertainties information.

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Retirement Benefits (All Registrants)

Retirement Benefits (All Registrants)

3 Months Ended

Mar. 31, 2022

Retirement Benefits [Abstract]

Defined Benefit Pension and OPEB

Effective February 1, 2022, in connection with the separation, pension and OPEB obligations and assets for current and former employees of the Constellation business and certain other former employees of Exelon and its subsidiaries transferred to pension and OPEB plans and trusts maintained by Constellation or its subsidiaries. The Exelon New England Union Employees Pension Plan and Constellation Mystic Power, LLC Union Employees Pension Plan Including Plan A and Plan B were transferred. The following OPEB plans were also transferred: Constellation Mystic Power, LLC Post-Employment Medical Account Savings Plan, Exelon New England Union Post-Employment Medical Savings Account Plan, and the Nine Mile Point Nuclear Station, LLC Medical Care and Prescription Drug Plan for Retired Employees.

As a result of the separation, Exelon restructured certain of its qualified pension plans. Pension obligations and assets for current and former employees continuing with Exelon and who are participants in the Exelon Employee Pension Plan for Clinton, TMI, and Oyster Creek, Pension Plan of Constellation Energy Nuclear Group, LLC, and Nine Mile Point Pension Plan were merged into the Pension Plan of Constellation Energy Group, Inc, which was subsequently renamed, Exelon Pension Plan (EPP). Exelon employees who participated in these plans prior to the separation now participate in the EPP. The merging of the plans did not change the benefits offered to the plan participants and, thus, had no impact on Exelon's pension obligations.

The tables below show the pension and OPEB plans in which employees of each operating company participated as of March 31, 2022:

Operating Company(a)

Name of Plan:

ComEd

PECO

BGE

PHI

Pepco

DPL

ACE

Qualified Pension Plans:

Exelon Corporation Retirement Program

Exelon Corporation Pension Plan for Bargaining Unit Employees

Exelon Pension Plan

Pepco Holdings LLC Retirement Plan

Non-Qualified Pension Plans:

Exelon Corporation Supplemental Pension Benefit Plan and 2000 Excess Benefit Plan

Exelon Corporation Supplemental Management Retirement Plan

Constellation Energy Group, Inc. Senior Executive Supplemental Plan

Constellation Energy Group, Inc. Supplemental Pension Plan

Constellation Energy Group, Inc. Benefits Restoration Plan

Baltimore Gas & Electric Company Executive Benefit Plan

Baltimore Gas & Electric Company Manager Benefit Plan

Pepco Holdings LLC 2011 Supplemental Executive Retirement Plan

Conectiv Supplemental Executive Retirement Plan

Pepco Holdings LLC Combined Executive Retirement Plan

Atlantic City Electric Director Retirement Plan

Operating Company(a)

Name of Plan:

ComEd

PECO

BGE

PHI

Pepco

DPL

ACE

OPEB Plans:

PECO Energy Company Retiree Medical Plan

Exelon Corporation Health Care Program

Exelon Corporation Employees’ Life Insurance Plan

Exelon Corporation Health Reimbursement Arrangement Plan

BGE Retiree Medical Plan

BGE Retiree Dental Plan

Exelon Employee Life Insurance Plan and Family Life Insurance Plan

Exelon Retiree Medical Plan of Constellation Energy Nuclear Group, LLC

Exelon Retiree Dental Plan of Constellation Energy Nuclear Group, LLC

Pepco Holdings LLC Welfare Plan for Retirees

__________

(a)Employees generally remain in their legacy benefit plans when transferring between operating companies.

As of February 1, 2022, in connection with the separation, Exelon's pension and OPEB plans were remeasured. The remeasurement and separation resulted in a decrease to the pension obligation, net of plan assets, of $921 million and a decrease to the OPEB obligation of $893 million. Additionally, accumulated other comprehensive loss, decreased by $1,994 million (after-tax) and regulatory assets and liabilities increased by $14 million and $5 million respectively. Key assumptions were held consistent with the year end December 31, 2021 assumptions with the exception of the discount rate.

The majority of the 2022 pension benefit cost for the Exelon-sponsored plans is calculated using an expected long-term rate of return on plan assets of 7.00% and a discount rate of 3.24%. The majority of the 2022 OPEB cost is calculated using an expected long-term rate of return on plan assets of 6.44% for funded plans and a discount rate of 3.20%.

During the first quarter of 2022, Exelon received an updated valuation of its pension and OPEB to reflect actual census data as of February 1, 2022. This valuation resulted in a decrease to the pension obligation of $24 million and an increase to the OPEB obligation of $5 million. Additionally, accumulated other comprehensive loss increased by $5 million (after-tax) and regulatory assets and liabilities decreased by $30 million and $3 million, respectively.

A portion of the net periodic benefit cost for all plans is capitalized within the Consolidated Balance Sheets. The following table presents the components of Exelon's net periodic benefit costs, prior to capitalization, for the three months ended March 31, 2022 and 2021.



	Pension Benefits				OPEB
	Three Months Ended March 31,				Three Months Ended March 31,
	2022		2021		2022		2021
Components of net periodic benefit cost:
Service cost	$	61	$	74	$	10	$	14
Interest cost	110		102		19		17
Expected return on assets	(209)		(213)		(25)		(26)
Amortization of:
Prior service cost (credit)	1		1		(5)		(6)
Actuarial loss	76		100		4		7
Curtailment benefits	—		—		—		(1)


Net periodic benefit cost	$	39	$	64	$	3	$	5

The amounts below represent the Registrants' allocated pension and OPEB costs. For Exelon, the service cost component is included in Operating and maintenance expense and Property, plant, and equipment, net while the non-service cost components are included in Other, net and Regulatory assets. For the Utility Registrants, the service cost and non-service cost components are included in Operating and maintenance expense and Property, plant, and equipment, net in their consolidated financial statements.


	Three Months Ended March 31,
Pension and OPEB Costs		2022		2021
Exelon		$	42	$	69
ComEd		16		32
PECO		(2)		2
BGE		11		15
PHI		13		12
Pepco		2		2
DPL		1		1
ACE		3		3

Defined Contribution Savings Plan

The Registrants participate in a 401(k) defined contribution savings plan that is sponsored by Exelon. The plan is qualified under applicable sections of the IRC and allow employees to contribute a portion of their pre-tax and/or after-tax income in accordance with specified guidelines. All Registrants match a percentage of the employee contributions up to certain limits. The following table presents the matching contributions to the savings plans for the three months ended March 31, 2022 and 2021, respectively.


	Three Months Ended March 31,
Savings Plans Matching Contributions		2022		2021
Exelon		$	20	$	20
ComEd		8		8
PECO		3		3
BGE		2		2
PHI		3		3
Pepco		1		1
DPL		1		1
ACE		—		—

The entire disclosure for retirement benefits.

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Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Financial Instruments (All Registrants)

3 Months Ended

Mar. 31, 2022

Derivative Financial Instruments (All Registrants)

The Registrants use derivative instruments to manage commodity price risk related to ongoing business operations.

Authoritative guidance requires that derivative instruments be recognized as either assets or liabilities at fair value, with changes in fair value of the derivative recognized in earnings immediately. Other accounting treatments are available through special election and designation, provided they meet specific, restrictive criteria both at the time of designation and on an ongoing basis. These alternative permissible accounting treatments include NPNS, cash flow hedges, and fair value hedges. At ComEd, derivative economic hedges related to commodities are recorded at fair value and offset by a corresponding regulatory asset or liability. For all NPNS derivative instruments, accounts receivable or accounts payable are recorded when derivatives settle and revenue or expense is recognized in earnings as the underlying physical commodity is sold or consumed.

ComEd’s use of cash collateral is generally unrestricted unless ComEd is downgraded below investment grade. Cash collateral held by PECO, BGE, Pepco, DPL, and ACE must be deposited in an unaffiliated major U.S. commercial bank or foreign bank with a U.S. branch office that meet certain qualifications.

Commodity Price Risk

The Registrants employ established policies and procedures to manage their risks associated with market fluctuations in commodity prices by entering into physical and financial derivative contracts, which are either determined to be non-derivative or classified as economic hedges. The Utility Registrants procure electric and natural gas supply through a competitive procurement process approved by each of the respective state utility commissions. The Utility Registrants’ hedging programs are intended to reduce exposure to energy and natural gas price volatility and have no direct earnings impact as the costs are fully recovered from customers through

regulatory-approved recovery mechanisms. The following table provides a summary of the Utility Registrants’ primary derivative hedging instruments, listed by commodity and accounting treatment.


Registrant	Commodity	Accounting Treatment	Hedging Instrument
ComEd	Electricity	NPNS	Fixed price contracts based on all requirements in the IPA procurement plans.
	Electricity	Changes in fair value of economic hedge recorded to an offsetting regulatory asset or liability(a)	20-year floating-to-fixed energy swap contracts beginning June 2012 based on the renewable energy resource procurement requirements in the Illinois Settlement Legislation of approximately 1.3 million MWhs per year.
PECO	Electricity	NPNS	Fixed price contracts for default supply requirements through full requirements contracts.
	Gas	NPNS	Fixed price contracts to cover about 10% of planned natural gas purchases in support of projected firm sales.
BGE	Electricity	NPNS	Fixed price contracts for all SOS requirements through full requirements contracts.
	Gas	NPNS	Fixed price contracts for between 10-20% of forecasted system supply requirements for flowing (i.e., non-storage) gas for the November through March period.
Pepco	Electricity	NPNS	Fixed price contracts for all SOS requirements through full requirements contracts.
DPL	Electricity	NPNS	Fixed price contracts for all SOS requirements through full requirements contracts.
	Gas	NPNS	Fixed and index priced contracts through full requirements contracts.
		Changes in fair value of economic hedge recorded to an offsetting regulatory asset or liability(b)	Exchange traded future contracts for up to 50% of estimated monthly purchase requirements each month, including purchases for storage injections.
ACE	Electricity	NPNS	Fixed price contracts for all BGS requirements through full requirements contracts.

__________

(a)See Note 3 — Regulatory Matters of the 2021 Form 10-K for additional information.

(b)The fair value of the DPL economic hedge is not material as of March 31, 2022 and December 31, 2021.

The fair value of derivative economic hedges is presented in current and noncurrent Mark-to-market derivative liabilities in Exelon's and ComEd's Consolidated Balance Sheets.

Credit Risk

The Registrants would be exposed to credit-related losses in the event of non-performance by counterparties on executed derivative instruments. The credit exposure of derivative contracts, before collateral, is represented by the fair value of contracts at the reporting date. The Utility Registrants have contracts to procure electric and natural gas supply that provide suppliers with a certain amount of unsecured credit. If the exposure on the supply contract exceeds the amount of unsecured credit, the suppliers may be required to post collateral. The net credit exposure is mitigated primarily by the ability to recover procurement costs through customer rates. As of March 31, 2022, the amount of cash collateral held with external counterparties by Exelon, ComEd, PHI, and DPL was $192 million, $72 million, $86 million, and $73 million, respectively, which is recorded in Other current liabilities in Exelon's, ComEd's, PHI's, and DPL's Consolidated Balance Sheets. The amounts for PECO, BGE, Pepco, and ACE were not material as of March 31, 2022. As of December 31, 2021, the amounts for ComEd and DPL were $41 million and $43 million, respectively. The amounts for Exelon, PECO, BGE, PHI, Pepco, and ACE were not material as of December 31, 2021.

The Utility Registrants’ electric supply procurement contracts do not contain provisions that would require them to post collateral. PECO’s, BGE’s, and DPL’s natural gas procurement contracts contain provisions that could require PECO, BGE, and DPL to post collateral in the form of cash or credit support, which vary by contract and counterparty, with thresholds contingent upon PECO’s, BGE's, and DPL’s credit rating. As of March 31, 2022, PECO, BGE, and DPL were not required to post collateral for any of these agreements. If PECO, BGE, or DPL lost their investment grade credit rating as of March 31, 2022, they could have been required to post collateral to their counterparties of $39 million, $62 million, and $16 million, respectively.

Debt and Credit Agreements (All Registrants)

3 Months Ended

Mar. 31, 2022

Debt Disclosure [Abstract]

Debt and Credit Agreements (All Registrants)

Short-Term Borrowings

Exelon Corporate, ComEd, and BGE meet their short-term liquidity requirements primarily through the issuance of commercial paper. PECO meets their short-term liquidity requirements primarily through the issuance of commercial paper and borrowings from the Exelon intercompany money pool. Pepco, DPL, and ACE meet their short-term liquidity requirements primarily through the issuance of commercial paper and borrowings from the PHI intercompany money pool. PHI Corporate meets its short-term liquidity requirements primarily through the issuance of short-term notes and borrowings from the Exelon intercompany money pool. The Registrants may use their respective credit facilities for general corporate purposes, including meeting short-term funding requirements and the issuance of letters of credit.

Commercial Paper

The following table reflects the Registrants' commercial paper programs as of March 31, 2022 and December 31, 2021. PECO and ComEd had no commercial paper borrowings as of March 31, 2022 and December 31, 2021.


	Outstanding Commercial Paper as of				Average Interest Rate on Commercial Paper Borrowings as of
Commercial Paper Issuer	March 31, 2022		December 31, 2021		March 31, 2022		December 31, 2021
Exelon(a)	$	250	$	599	0.87	%	0.35	%


BGE	250		130		0.87	%	0.37	%
PHI(b)	—		469		—	%	0.35	%

Pepco	—		175		—	%	0.33	%
DPL	—		149		—	%	0.36	%
ACE	—		145		—	%	0.35	%

__________

(a)Exelon Corporate had no outstanding commercial paper borrowings as of March 31, 2022 and December 31, 2021.

(b)Represents the consolidated amounts of Pepco, DPL, and ACE.

Revolving Credit Agreements

On February 1, 2022, Exelon Corporate and the Utility Registrants' each entered into a new 5-year revolving credit facility that replaced its existing syndicated revolving credit facility. The following table reflects the credit agreements:


Borrower	Aggregate Bank Commitment	Interest Rate
Exelon Corporate	900	SOFR plus 1.275	%
ComEd	1,000	SOFR plus 1.000	%
PECO	600	SOFR plus 0.900	%
BGE	600	SOFR plus 0.900	%
Pepco	300	SOFR plus 1.075	%
DPL	300	SOFR plus 1.000	%
ACE	300	SOFR plus 1.075	%

See Note 17 — Debt and Credit Agreements of the Exelon 2021 Form 10-K for additional information on the Registrants' credit facilities.

Short-Term Loan Agreements

On March 23, 2017, Exelon Corporate entered into a term loan agreement for $500 million. The loan agreement was renewed on March 14, 2022 and will expire on March 16, 2023. Pursuant to the loan agreement, loans made thereunder bear interest at a variable rate equal to SOFR plus 0.65% and all indebtedness thereunder is unsecured. The loan agreement is reflected in Exelon's Consolidated Balance Sheets within Short-term borrowings.

On March 31, 2021, Exelon Corporate entered into a 364-day term loan agreement for $150 million with a variable interest rate of LIBOR plus 0.65% and an expiration date of March 30, 2022. Exelon Corporate repaid the term loan on March 30, 2022.

In connection with the separation, on January 24, 2022, Exelon Corporate entered into a 364-day term loan agreement for $1.15 billion. The loan agreement will expire on January 23, 2023. Pursuant to the loan agreement, loans made thereunder bear interest at a variable rate equal to SOFR plus 0.75% with a 22.5 basis point increase commencing on July 24, 2022. All indebtedness pursuant to the loan agreement is unsecured.

Long-Term Debt

Issuance of Long-Term Debt

During the three months ended March 31, 2022, the following long-term debt was issued:

Company

Type

Interest Rate

Maturity

Amount

Use of Proceeds

Exelon

SMBC Term Loan Agreement

SOFR plus 0.65%

July 21, 2023

$300

Fund a cash payment to Constellation and for general corporate purposes.

Exelon

U.S. Bank Term Loan Agreement

SOFR plus 0.65%

July 21, 2023

300

Fund a cash payment to Constellation and for general corporate purposes.

Exelon

PNC Term Loan Agreement

SOFR plus 0.65%

July 24, 2023

250

Fund a cash payment to Constellation and for general corporate purposes.

Exelon

Notes

2.75%

March 15, 2027

650

Repay existing indebtedness and for general corporate purposes.

Exelon

Notes

3.35%

March 15, 2032

650

Repay existing indebtedness and for general corporate purposes.

Exelon

Notes

4.10%

March 15, 2052

700

Repay existing indebtedness and for general corporate purposes.

ComEd

First Mortgage Bonds, Series 132

3.15%

March 15, 2032

300

Repay outstanding commercial paper obligations and to fund other general corporate purposes.

ComEd

First Mortgage Bonds, Series 133

3.85%

March 15, 2052

450

Repay outstanding commercial paper obligations and to fund other general corporate purposes.

Pepco(a)

First Mortgage Bonds

3.97%

March 24, 2052

400

Repay existing indebtedness and for general corporate purposes.

DPL

First Mortgage Bonds

3.06%

February 15, 2052

125

Repay existing indebtedness and for general corporate purposes.

ACE

First Mortgage Bonds

2.27%

February 15, 2032

Repay existing indebtedness and for general corporate purposes.

ACE

First Mortgage Bonds

3.06%

February 15, 2052

150

Repay existing indebtedness and for general corporate purposes.

__________

(a)On March 24, 2022, Pepco entered into a purchase agreement of First Mortgage Bonds of $225 million at 3.35% due on September 15, 2032. The closing date of the issuance is expected to occur in September 2022.

Long-Term Debt to Affiliates

As of December 31, 2021, Exelon Corporate had $319 million recorded to intercompany notes receivable from Generation. See Note 17 — Debt and Credit Agreements of the Exelon 2021 Form 10-K for additional information. In connection with the separation, on January 31, 2022, Exelon Corporate received cash from Generation of $258 million to settle the intercompany loan.

Debt Covenants

As of March 31, 2022, the Registrants are in compliance with debt covenants.

The entire disclosure for information about short-term and long-term debt arrangements, which includes amounts of borrowings under each line of credit, note payable, commercial paper issue, bonds indenture, debenture issue, own-share lending arrangements and any other contractual agreement to repay funds, and about the underlying arrangements, rationale for a classification as long-term, including repayment terms, interest rates, collateral provided, restrictions on use of assets and activities, whether or not in compliance with debt covenants, and other matters important to users of the financial statements, such as the effects of refinancing and noncompliance with debt covenants.

Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-URI http://asc.fasb.org/topic&trid=2208564

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1B
-Subparagraph (h)
-URI http://asc.fasb.org/extlink&oid=123466505&loc=SL123495323-112611

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1C
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=123466505&loc=SL123495334-112611

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
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-Section 50
-Paragraph 1I
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Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
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Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08(c))
-URI http://asc.fasb.org/extlink&oid=120395691&loc=d3e23780-122690

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
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-Section 50
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-Subparagraph (g)
-URI http://asc.fasb.org/extlink&oid=123466505&loc=SL123495323-112611

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
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Reference 9: http://www.xbrl.org/2003/role/disclosureRef
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-Name Accounting Standards Codification
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-Paragraph 1C
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=123466505&loc=SL123495334-112611

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
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-Paragraph 1E
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=123466505&loc=SL123495348-112611

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
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Reference 12: http://www.xbrl.org/2003/role/disclosureRef
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Reference 13: http://www.xbrl.org/2003/role/disclosureRef
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Fair Value of Financial Assets and Liabilities (All Registrants)

Fair Value of Financial Assets and Liabilities (All Registrants)

3 Months Ended

Mar. 31, 2022

Fair Value Disclosures [Abstract]

Exelon measures and classifies fair value measurements in accordance with the hierarchy as defined by GAAP. The hierarchy prioritizes the inputs to valuation techniques used to measure fair value into three levels as follows:

•Level 1 - quoted prices (unadjusted) in active markets for identical assets or liabilities that the Registrants have the ability to liquidate as of the reporting date.

•Level 2 - inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.

•Level 3 - unobservable inputs, such as internally developed pricing models or third-party valuations for the asset or liability due to little or no market activity for the asset or liability.

Fair Value of Financial Liabilities Recorded at Amortized Cost

The following tables present the carrying amounts and fair values of the Registrants’ short-term liabilities, long-term debt, and trust preferred securities (long-term debt to financing trusts or junior subordinated debentures) as of March 31, 2022 and December 31, 2021. The Registrants have no financial liabilities classified as Level 1.

The carrying amounts of the Registrants’ short-term liabilities as presented in their Consolidated Balance Sheets are representative of their fair value (Level 2) because of the short-term nature of these instruments.


	March 31, 2022								December 31, 2021
	Carrying Amount		Fair Value						Carrying Amount		Fair Value
			Level 2		Level 3		Total				Level 2		Level 3		Total
Long-Term Debt, including amounts due within one year(a)
Exelon	$	37,162	$	35,174	$	2,645	$	37,819	$	32,902	$	34,897	$	2,217	$	37,114
ComEd	10,515		10,894		—		10,894		9,773		11,305		—		11,305
PECO	4,198		4,244		50		4,294		4,197		4,740		50		4,790
BGE	3,961		3,969		—		3,969		3,961		4,406		—		4,406
PHI	8,233		5,453		2,595		8,048		7,547		5,970		2,167		8,137
Pepco	3,841		2,901		1,272		4,173		3,445		3,201		975		4,176
DPL	1,935		1,300		592		1,892		1,810		1,426		552		1,978
ACE	1,757		1,007		732		1,739		1,582		1,091		641		1,732
Long-Term Debt to Financing Trusts
Exelon	$	390	$	—	$	435	$	435	$	390	$	—	$	470	$	470
ComEd	205		—		228		228		205		—		248		248
PECO	184		—		207		207		184		—		222		222

__________

(a)Includes unamortized debt issuance costs, unamortized debt discount and premium, net, purchase accounting fair value adjustments, and finance lease liabilities which are not fair valued. Refer to Note 17 - Debt and Credit Agreements of the Exelon 2021 Form 10-K for unamortized debt issuance costs, unamortized debt discount and premium, net, and purchase accounting fair value adjustments and Note 11 - Leases of the Exelon 2021 Form 10-K for finance lease liabilities.

Recurring Fair Value Measurements

The following tables present assets and liabilities measured and recorded at fair value in the Registrants' Consolidated Balance Sheets on a recurring basis and their level within the fair value hierarchy as of March 31, 2022 and December 31, 2021:

Exelon


	As of March 31, 2022						As of December 31, 2021
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Cash equivalents(a)	$	2,418	$	—	$	—	$	2,418	$	524	$	—	$	—	$	524
Rabbi trust investments
Cash equivalents	65		—		—		65		60		—		—		60
Mutual funds	55		—		—		55		60		—		—		60
Fixed income	—		9		—		9		—		10		—		10
Life insurance contracts	—		63		37		100		—		61		37		98
Rabbi trust investments subtotal	120		72		37		229		120		71		37		228
Total assets	2,538		72		37		2,647		644		71		37		752
Liabilities
Mark-to-market derivative liabilities	—		—		(144)		(144)		—		—		(219)		(219)
Deferred compensation obligation	—		(84)		—		(84)		—		(131)		—		(131)
Total liabilities	—		(84)		(144)		(228)		—		(131)		(219)		(350)
Total net assets (liabilities)	$	2,538	$	(12)	$	(107)	$	2,419	$	644	$	(60)	$	(182)	$	402

__________

(a)Exelon excludes cash of $470 million and $464 million as of March 31, 2022 and December 31, 2021, respectively, and restricted cash of $110 million and $49 million as of March 31, 2022 and December 31, 2021, respectively, and includes long-term restricted cash of $92 million and $44 million as of March 31, 2022 and December 31, 2021, respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets.

ComEd, PECO, and BGE


	ComEd								PECO								BGE
As of March 31, 2022	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Cash equivalents(a)	$	537	$	—	$	—	$	537	$	9	$	—	$	—	$	9	$	—	$	—	$	—	$	—
Rabbi trust investments
Cash equivalents	—		—		—		—		1		—		—		1		—		—		—		—
Mutual funds	—		—		—		—		9		—		—		9		7		—		—		7
Life insurance contracts	—		—		—		—		—		17		—		17		—		—		—		—
Rabbi trust investments subtotal	—		—		—		—		10		17		—		27		7		—		—		7
Total assets	537		—		—		537		19		17		—		36		7		—		—		7
Liabilities
Mark-to-market derivative liabilities(b)	—		—		(144)		(144)		—		—		—		—		—		—		—		—
Deferred compensation obligation	—		(9)		—		(9)		—		(8)		—		(8)		—		(5)		—		(5)
Total liabilities	—		(9)		(144)		(153)		—		(8)		—		(8)		—		(5)		—		(5)
Total net assets (liabilities)	$	537	$	(9)	$	(144)	$	384	$	19	$	9	$	—	$	28	$	7	$	(5)	$	—	$	2


	ComEd								PECO								BGE
As of December 31, 2021	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Cash equivalents(a)	$	237	$	—	$	—	$	237	$	9	$	—	$	—	$	9	$	—	$	—	$	—	$	—
Rabbi trust investments
Mutual funds	—		—		—		—		11		—		—		11		14		—		—		14
Life insurance contracts	—		—		—		—		—		16		—		16		—		—		—		—
Rabbi trust investments subtotal	—		—		—		—		11		16		—		27		14		—		—		14
Total assets	237		—		—		237		20		16		—		36		14		—		—		14
Liabilities
Mark-to-market derivative liabilities(b)	—		—		(219)		(219)		—		—		—		—		—		—		—		—
Deferred compensation obligation	—		(10)		—		(10)		—		(9)		—		(9)		—		(7)		—		(7)
Total liabilities	—		(10)		(219)		(229)		—		(9)		—		(9)		—		(7)		—		(7)
Total net assets (liabilities)	$	237	$	(10)	$	(219)	$	8	$	20	$	7	$	—	$	27	$	14	$	(7)	$	—	$	7

__________

(a)ComEd excludes cash of $71 million and $105 million as of March 31, 2022 and December 31, 2021, respectively, and restricted cash of $73 million and $42 million as of March 31, 2022 and December 31, 2021, respectively, and includes long-term restricted cash of $92 million and $43 million as of March 31, 2022 and December 31, 2021, respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets. PECO excludes cash of $25 million and $35 million as of March 31, 2022 and December 31, 2021, respectively. BGE excludes cash of $41 million and $51 million as of March 31, 2022 and December 31, 2021, respectively, and restricted cash of $34 million and $4 million as of March 31, 2022 and December 31, 2021, respectively.

(b)The Level 3 balance consists of the current and noncurrent liability of none and $144 million, respectively, as of March 31, 2022 and $18 million and $201 million, respectively, as of December 31, 2021 related to floating-to-fixed energy swap contracts with unaffiliated suppliers.

PHI, Pepco, DPL, and ACE



	As of March 31, 2022								As of December 31, 2021
PHI	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Cash equivalents(a)	$	599	$	—	$	—	$	599	$	110	$	—	$	—	$	110
Rabbi trust investments
Cash equivalents	61		—		—		61		59		—		—		59
Mutual funds	12		—		—		12		14		—		—		14
Fixed income	—		9		—		9		—		10		—		10
Life insurance contracts	—		24		36		60		—		27		35		62
Rabbi trust investments subtotal	73		33		36		142		73		37		35		145
Total assets	672		33		36		741		183		37		35		255
Liabilities
Deferred compensation obligation	—		(17)		—		(17)		—		(18)		—		(18)



Total liabilities	—		(17)		—		(17)		—		(18)		—		(18)
Total net assets	$	672	$	16	$	36	$	724	$	183	$	19	$	35	$	237


	Pepco								DPL								ACE
As of March 31, 2022	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Cash equivalents(a)	$	294	$	—	$	—	$	294	$	152	$	—	$	—	$	152	$	153	$	—	$	—	$	153




Rabbi trust investments
Cash equivalents	59		—		—		59		—		—		—		—		—		—		—		—

Life insurance contracts	—		24		36		60		—		—		—		—		—		—		—		—
Rabbi trust investments subtotal	59		24		36		119		—		—		—		—		—		—		—		—
Total assets	353		24		36		413		152		—		—		152		153		—		—		153
Liabilities
Deferred compensation obligation	—		(2)		—		(2)		—		—		—		—		—		—		—		—



Total liabilities	—		(2)		—		(2)		—		—		—		—		—		—		—		—
Total net assets	$	353	$	22	$	36	$	411	$	152	$	—	$	—	$	152	$	153	$	—	$	—	$	153


	Pepco								DPL								ACE
As of December 31, 2021	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Cash equivalents(a)	$	31	$	—	$	—	$	31	$	43	$	—	$	—	$	43	$	—	$	—	$	—	$	—
Rabbi trust investments
Cash equivalents	58		—		—		58		—		—		—		—		—		—		—		—


Life insurance contracts	—		27		35		62		—		—		—		—		—		—		—		—
Rabbi trust investments subtotal	58		27		35		120		—		—		—		—		—		—		—		—
Total assets	89		27		35		151		43		—		—		43		—		—		—		—
Liabilities
Deferred compensation obligation	—		(2)		—		(2)		—		—		—		—		—		—		—		—



Total liabilities	—		(2)		—		(2)		—		—		—		—		—		—		—		—
Total net assets	$	89	$	25	$	35	$	149	$	43	$	—	$	—	$	43	$	—	$	—	$	—	$	—

__________

(a)PHI excludes cash of $300 million and $100 million as of March 31, 2022 and December 31, 2021, respectively, and restricted cash of $3 million as of both March 31, 2022 and December 31, 2021. Pepco excludes cash of $239 million and $34 million as of March 31, 2022 and December 31, 2021, respectively, and restricted cash of $3 million as of both March 31, 2022 and December 31, 2021. DPL excludes cash of $41 million and $28 million as of March 31, 2022 and December 31, 2021, respectively. ACE excludes cash of $15 million and $29 million as of March 31, 2022 and December 31, 2021, respectively.

Reconciliation of Level 3 Assets and Liabilities

The following tables present the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis during the three months ended March 31, 2022 and 2021:


	Exelon		ComEd			PHI and Pepco
Three months ended March 31, 2022	Total		Mark-to-Market Derivatives			Life Insurance Contracts
Balance as of January 1, 2022	$	(182)	$	(219)		$	35
Total realized / unrealized gains
Included in net income(a)	1		—			1


Included in regulatory assets	75		75		(b)	—







Transfers out of Level 3	(1)		—			—
Balance as of March 31, 2022	$	(107)	$	(144)		$	36
The amount of total gains included in income attributed to the change in unrealized gains related to assets and liabilities as of March 31, 2022	$	1	$	—		$	1


	Exelon		ComEd			PHI and Pepco
Three Months Ended March 31, 2021	Total		Mark-to-Market Derivatives			Life Insurance Contracts
Balance as of January 1, 2021	$	(267)	$	(301)		$	34
Total realized / unrealized gains
Included in net income(a)	1		—			1


Included in regulatory assets	6		6		(b)	—








Balance as of March 31, 2021	$	(260)	$	(295)		$	35
The amount of total gains included in income attributed to the change in unrealized gain related to assets and liabilities as of March 31, 2021	$	1	$	—		$	1

__________

(a)Classified in Operating and maintenance expense in the Consolidated Statements of Operations and Comprehensive Income.

(b)Includes $69 million of increases in fair value and an increase for realized losses due to settlements of $6 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the three months ended March 31, 2022. Includes $2 million of decreases in fair value and an increase for realized losses due to settlements of $8 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the three months ended March 31, 2021.

Valuation Techniques Used to Determine Fair Value

Exelon’s valuation techniques used to measure the fair value of the assets and liabilities shown in the tables below are in accordance with the policies discussed in Note 18 — Fair Value of Financial Assets and Liabilities of the Exelon 2021 Form 10-K.

Mark-to-Market Derivatives (Exelon and ComEd)

The table below discloses the significant inputs to the forward curve used to value mark-to-market derivatives.


Type of trade	Fair Value as of March 31, 2022		Fair Value as of December 31, 2021		Valuation Technique	Unobservable Input	2022 Range & Arithmetic Average				2021 Range & Arithmetic Average
Mark-to-market derivatives	$	(144)	$	(219)	Discounted Cash Flow	Forward heat rate(a)	8.90x	-	9.10x	9.00x	9x	-	10x	9.13x
						Marketability reserve	4%	-	5%	4.35%	3%	-	7%	4.77%
						Renewable factor	92%	-	120%	98%	92%	-	120%	97%

__________

(a)Quoted forward natural gas rates are utilized to project the forward power curve for the delivery of energy at specified future dates.

The inputs listed above, which are as of the balance sheet date, would have a direct impact on the fair value of the above instruments if they were adjusted. An increase to the marketability reserves would decrease the fair value. An increase to the forward heat rate or renewable factor would increase the fair value accordingly.

Commitments and Contingencies Disclosure [Abstract]

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

+ References + Details

Commitments and Contingencies (All Registrants)

3 Months Ended

Mar. 31, 2022

Commitments and Contingencies (All Registrants)

The following is an update to the current status of commitments and contingencies set forth in Note 19 — Commitments and Contingencies of the Exelon 2021 Form 10-K.

Commitments

PHI Merger Commitments (Exelon, PHI, Pepco, DPL, and ACE). Approval of the PHI Merger in Delaware, New Jersey, Maryland, and the District of Columbia was conditioned upon Exelon and PHI agreeing to certain commitments. The following amounts represent total commitment costs that have been recorded since the acquisition date and the total remaining obligations for Exelon, PHI, Pepco, DPL, and ACE as of March 31, 2022:


Description	Exelon		PHI		Pepco		DPL		ACE
Total commitments	$	513	$	320	$	120	$	89	$	111
Remaining commitments(a)	65		55		46		6		3

__________

(a)Remaining commitments extend through 2026 and include rate credits, energy efficiency programs and delivery system modernization.

In addition, Exelon has committed to purchase 100 MWs of wind energy in PJM. DPL has committed to conducting three RFPs to procure up to a total of 120 MWs of wind RECs for the purpose of meeting Delaware's renewable portfolio standards. DPL has conducted two of the three wind REC RFPs. The first 40 MW wind REC tranche was conducted in 2017 and did not result in a purchase agreement. The second 40 MW wind REC tranche was conducted in 2018 and resulted in a proposed REC purchase agreement that was approved by the DEPSC in 2019. The RFP for the third and final 40 MW wind REC tranche will be conducted in the second half of 2022.

Commercial Commitments (All Registrants). The Registrants’ commercial commitments as of March 31, 2022, representing commitments potentially triggered by future events were as follows:


			Expiration within
	Total		2022		2023		2024		2025		2026		2027 and beyond
Exelon
Letters of credit	$	14	$	12	$	2	$	—	$	—	$	—	$	—
Surety bonds(a)	201		188		11		2		—		—		—
Financing trust guarantees	378		—		—		—		—		—		378
Guaranteed lease residual values(b)	30		1		3		6		5		5		10
Total commercial commitments	$	623	$	201	$	16	$	8	$	5	$	5	$	388

ComEd
Letters of credit	$	7	$	7	$	—	$	—	$	—	$	—	$	—
Surety bonds(a)	17		12		3		2		—		—		—
Financing trust guarantees	200		—		—		—		—		—		200
Total commercial commitments	$	224	$	19	$	3	$	2	$	—	$	—	$	200

PECO
Letters of credit	$	1	$	1	$	—	$	—	$	—	$	—	$	—
Surety bonds(a)	3		2		1		—		—		—		—
Financing trust guarantees	178		—		—		—		—		—		178
Total commercial commitments	$	182	$	3	$	1	$	—	$	—	$	—	$	178

BGE
Letters of credit	$	2	$	2	$	—	$	—	$	—	$	—	$	—
Surety bonds(a)	4		3		1		—		—		—		—
Total commercial commitments	$	6	$	5	$	1	$	—	$	—	$	—	$	—

PHI

Surety bonds(a)	$	94	$	91	$	3	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	30		1		3		6		5		5		10
Total commercial commitments	$	124	$	92	$	6	$	6	$	5	$	5	$	10

Pepco

Surety bonds(a)	$	84	$	84	$	—	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	10		—		1		2		2		2		3
Total commercial commitments	$	94	$	84	$	1	$	2	$	2	$	2	$	3

DPL

Surety bonds(a)	$	6	$	3	$	3	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	13		1		1		3		2		2		4
Total commercial commitments	$	19	$	4	$	4	$	3	$	2	$	2	$	4

ACE
Surety bonds(a)	$	4	$	4	$	—	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	7		—		1		1		1		1		3
Total commercial commitments	$	11	$	4	$	1	$	1	$	1	$	1	$	3

__________

(a)Surety bonds — Guarantees issued related to contract and commercial agreements, excluding bid bonds.

(b)Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The lease term associated with these assets ranges from 1 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $73 million guaranteed by Exelon and PHI, of which $25 million, $30 million, and $18 million is guaranteed by Pepco, DPL, and ACE, respectively. Historically, payments under the guarantees have not been made and PHI believes the likelihood of payments being required under the guarantees is remote.

Environmental Remediation Matters

General (All Registrants). The Registrants’ operations have in the past, and may in the future, require substantial expenditures to comply with environmental laws. Additionally, under Federal and state environmental laws, the Registrants are generally liable for the costs of remediating environmental contamination of property now or formerly owned by them and of property contaminated by hazardous substances generated by them. The Registrants own or lease a number of real estate parcels, including parcels on which their operations or the operations of others may have resulted in contamination by substances that are considered hazardous under environmental laws. In addition, the Registrants are currently involved in a number of proceedings relating to sites where hazardous substances have been deposited and may be subject to additional proceedings in the future. Unless otherwise disclosed, the Registrants cannot reasonably estimate whether they will incur significant liabilities for additional investigation and remediation costs at these or additional sites identified by the Registrants, environmental agencies or others, or whether such costs will be recoverable from third parties, including customers. Additional costs could have a material, unfavorable impact on the Registrants' financial statements.

MGP Sites (All Registrants). ComEd, PECO, BGE, and DPL have identified sites where former MGP or gas purification activities have or may have resulted in actual site contamination. For almost all of these sites, there are additional PRPs that may share responsibility for the ultimate remediation of each location.

•ComEd has 21 sites that are currently under some degree of active study and/or remediation. ComEd expects the majority of the remediation at these sites to continue through at least 2031.

•PECO has 6 sites that are currently under some degree of active study and/or remediation. PECO expects the majority of the remediation at these sites to continue through at least 2023.

•BGE has 4 sites that currently require some level of remediation and/or ongoing activity. BGE expects the majority of the remediation at these sites to continue through at least 2023.

•DPL has 1 site that is currently under study and the required cost at the site is not expected to be material.

The historical nature of the MGP and gas purification sites and the fact that many of the sites have been buried and built over, impacts the ability to determine a precise estimate of the ultimate costs prior to initial sampling and determination of the exact scope and method of remedial activity. Management determines its best estimate of remediation costs using all available information at the time of each study, including probabilistic and deterministic modeling for ComEd and PECO, and the remediation standards currently required by the applicable state environmental agency. Prior to completion of any significant clean up, each site remediation plan is approved by the appropriate state environmental agency.

ComEd, pursuant to an ICC order, and PECO, pursuant to a PAPUC order, are currently recovering environmental remediation costs of former MGP facility sites through customer rates. While BGE and DPL do not have riders for MGP clean-up costs, they have historically received recovery of actual clean-up costs in distribution rates.

As of March 31, 2022 and December 31, 2021, the Registrants had accrued the following undiscounted amounts for environmental liabilities in Other current liabilities and Other deferred credits and other liabilities in their respective Consolidated Balance Sheets:


	March 31, 2022				December 31, 2021
	Total environmental investigation and remediation liabilities		Portion of total related to MGP investigation and remediation		Total environmental investigation and remediation liabilities		Portion of total related to MGP investigation and remediation
Exelon	$	354	$	305	$	352	$	303
ComEd	279		279		279		279
PECO	21		20		22		20
BGE	7		6		6		4
PHI	42		—		42		—
Pepco	40		—		40		—
DPL	1		—		1		—
ACE	1		—		1		—

Benning Road Site (Exelon, PHI, and Pepco). In September 2010, PHI received a letter from EPA identifying the Benning Road site as one of six land-based sites potentially contributing to contamination of the lower Anacostia River. A portion of the site, which is owned by Pepco, was formerly the location of an electric generating facility owned by Pepco subsidiary, Pepco Energy Services, which became a part of Generation, following the 2016 merger between PHI and Exelon. This generating facility was deactivated in June 2012. The remaining portion of the site consists of a Pepco transmission and distribution service center that remains in operation. In December 2011, the U.S. District Court for the District of Columbia approved a Consent Decree entered into by Pepco and Pepco Energy Services (hereinafter "Pepco Entities") with the DOEE, which requires the Pepco Entities to conduct a Remedial Investigation and Feasibility Study (RI/FS) for the Benning Road site and an approximately 10 to 15-acre portion of the adjacent Anacostia River. The purpose of this RI/FS is to define the nature and extent of contamination from the Benning Road site and to evaluate remedial alternatives.

Pursuant to an internal agreement between the Pepco Entities, since 2013, Pepco has performed the work required by the Consent Decree and has been reimbursed for that work by an agreed upon allocation of costs between the Pepco Entities. In September 2019, the Pepco Entities issued a draft “final” RI report which DOEE approved on February 3, 2020. The Pepco Entities are developing a FS to evaluate possible remedial alternatives for submission to DOEE. The Court has established a schedule for completion of the FS, and approval by the DOEE, by September 16, 2022. After completion and approval of the FS, DOEE will prepare a Proposed Plan for public comment and then issue a Record of Decision (ROD) identifying any further response actions determined to be necessary. As part of the separation between Exelon and Constellation in February 2022, the internal agreement between the Pepco Entities for completion and payment for the remaining Consent Decree work was memorialized in a formal agreement for post-separation activities. A second post-separation assumption agreement between Exelon and Constellation transferred any of the potential remaining remediation liability, if any, of PES/Generation to a non-utility subsidiary of Exelon which going forward will be responsible for those liabilities. Exelon, PHI, and Pepco have determined that a loss associated with this matter is probable and have accrued an estimated liability, which is included in the table above.

Anacostia River Tidal Reach (Exelon, PHI, and Pepco). Contemporaneous with the Benning Road site RI/FS, being performed by the Pepco Entities, DOEE and National Park Service ("NPS") have been conducting a separate RI/FS focused on the entire tidal reach of the Anacostia River extending from just north of the Maryland-District of Columbia boundary line to the confluence of the Anacostia and Potomac Rivers. The river-wide RI incorporated the results of the river sampling performed by the Pepco Entities as part of the Benning RI/FS, as well as similar sampling efforts conducted by owners of other sites adjacent to this segment of the river and supplemental river sampling conducted by DOEE’s contractor. In April 2018, DOEE released a draft RI report for public review and comment. Pepco submitted written comments to the draft RI and participated in a public hearing.

Exelon, PHI, and Pepco have determined that it is probable that costs for remediation will be incurred and recorded a liability in the third quarter 2019 for management’s best estimate of its share of those costs. On September 30, 2020, DOEE released its Interim ROD. The Interim ROD reflects an adaptive management

approach which will require several identified “hot spots” in the river to be addressed first while continuing to conduct studies and to monitor the river to evaluate improvements and determine potential future remediation plans. The adaptive management process chosen by DOEE is less intrusive, provides more long-term environmental certainty, is less costly, and allows for site specific remediation plans already underway, including the plan for the Benning Road site to proceed to conclusion. Pepco concluded that incremental exposure remains reasonably possible, but management cannot reasonably estimate a range of loss beyond the amounts recorded, which are included in the table above.

On July 12, 2021, DOEE and NPS held a virtual meeting with the PRP's in response to a General Notice Letter sent by each agency inviting the PRP's to participate in discussions, which Pepco attended.

In addition to the activities associated with the remedial process outlined above, CERCLA separately requires federal and state (here including Washington, D.C.) Natural Resource Trustees (federal or state agencies designated by the President or the relevant state, respectively, or Indian tribes) to conduct an assessment of any damages to natural resources within their jurisdiction as a result of the contamination that is being remediated. The Trustees can seek compensation from responsible parties for such damages, including restoration costs. During the second quarter of 2018, Pepco became aware that the Trustees are in the beginning stages of a Natural Resources Damages (NRD) assessment, a process that often takes many years beyond the remedial decision to complete. Pepco has entered into negotiations with the Trustees to evaluate possible incorporation of NRD assessment and restoration as part of its remedial activities associated with the Benning site to accelerate the NRD benefits for that portion of the Anacostia River Sediment Project ("ARSP") assessment. Pepco has concluded that a loss associated with the eventual NRD assessment is reasonably possible. Due to the very early stage of the assessment process, Pepco cannot reasonably estimate the final range of loss potentially resulting from this process.

As noted in the Benning Road Site disclosure above, as part of the separation of Exelon and Constellation in February 2022, an assumption agreement was executed transferring any potential future remediation liabilities associated with the Benning Site remediation to a non-utility subsidiary of Exelon. Similarly, any potential future liability associated with the ARSP was also assumed by this entity.

Litigation and Regulatory Matters

Deferred Prosecution Agreement (DPA) and Related Matters (Exelon and ComEd). Exelon and ComEd received a grand jury subpoena in the second quarter of 2019 from the U.S. Attorney’s Office for the Northern District of Illinois (USAO) requiring production of information concerning their lobbying activities in the State of Illinois. On October 4, 2019, Exelon and ComEd received a second grand jury subpoena from the USAO requiring production of records of any communications with certain individuals and entities. On October 22, 2019, the SEC notified Exelon and ComEd that it had also opened an investigation into their lobbying activities. On July 17, 2020, ComEd entered into a DPA with the USAO to resolve the USAO investigation. Under the DPA, the USAO filed a single charge alleging that ComEd improperly gave and offered to give jobs, vendor subcontracts, and payments associated with those jobs and subcontracts for the benefit of the Speaker of the Illinois House of Representatives and the Speaker’s associates, with the intent to influence the Speaker’s action regarding legislation affecting ComEd’s interests. The DPA provides that the USAO will defer any prosecution of such charge and any other criminal or civil case against ComEd in connection with the matters identified therein for a three-year period subject to certain obligations of ComEd, including payment to the U.S. Treasury of $200 million, which was paid in November 2020. Exelon was not made party to the DPA, and therefore the investigation by the USAO into Exelon’s activities ended with no charges being brought against Exelon. The SEC’s investigation remains ongoing and Exelon and ComEd have cooperated fully and intend to continue to cooperate fully with the SEC. Exelon and ComEd cannot predict the outcome of the SEC investigation. No loss contingency has been reflected in Exelon's and ComEd's consolidated financial statements with respect to the SEC investigation, as this contingency is neither probable nor reasonably estimable at this time.

Subsequent to Exelon announcing the receipt of the subpoenas, various lawsuits were filed, and various demand letters were received related to the subject of the subpoenas, the conduct described in the DPA and the SEC's investigation, including:

•Four putative class action lawsuits against ComEd and Exelon were filed in federal court on behalf of ComEd customers in the third quarter of 2020 alleging, among other things, civil violations of federal racketeering laws. In addition, the Citizens Utility Board (CUB) filed a motion to intervene in these cases

on October 22, 2020 which was granted on December 23, 2020. On December 2, 2020, the court appointed interim lead plaintiffs in the federal cases which consisted of counsel for three of the four federal cases. These plaintiffs filed a consolidated complaint on January 5, 2021. CUB also filed its own complaint against ComEd only on the same day. The remaining federal case, Potter, et al. v. Exelon et al, differed from the other lawsuits as it named additional individual defendants not named in the consolidated complaint. However, the Potter plaintiffs voluntarily dismissed their complaint without prejudice on April 5, 2021. ComEd and Exelon moved to dismiss the consolidated class action complaint and CUB’s complaint on February 4, 2021 and briefing was completed on March 22, 2021. On March 25, 2021, the parties agreed, along with state court plaintiffs, discussed below, to jointly engage in mediation. The parties participated in a one-day mediation on June 7, 2021 but no settlement was reached. On September 9, 2021, the federal court granted Exelon’s and ComEd’s motion to dismiss and dismissed the plaintiffs’ and CUB’s federal law claim with prejudice. The federal court also dismissed the related state law claims made by the federal plaintiffs and CUB on jurisdictional grounds. Plaintiffs appealed dismissal of the federal law claim to the Seventh Circuit Court of Appeals. Plaintiffs and CUB also refiled their state law claims in state court and moved to consolidate them with the already pending consumer state court class action, discussed below. Plaintiffs' opening appeal brief in the Seventh Circuit was filed on January 14, 2022. Exelon and ComEd filed their response brief on March 7, 2022, and plaintiffs filed their reply brief on April 6, 2022. The court has scheduled oral argument for May 17, 2022.

•Three putative class action lawsuits against ComEd and Exelon were filed in Illinois state court in the third quarter of 2020 seeking restitution and compensatory damages on behalf of ComEd customers. The cases were consolidated into a single action in October of 2020. In November 2020, CUB filed a motion to intervene in the cases pursuant to an Illinois statute allowing CUB to intervene as a party or otherwise participate on behalf of utility consumers in any proceeding which affects the interest of utility consumers. On November 23, 2020, the court allowed CUB’s intervention, but denied CUB's request to stay these cases. Plaintiffs subsequently filed a consolidated complaint, and ComEd and Exelon filed a motion to dismiss on jurisdictional and substantive grounds on January 11, 2021. Briefing on that motion was completed on March 2, 2021. The parties agreed, on March 25, 2021, along with the federal court, plaintiffs discussed above, to jointly engage in mediation. The parties participated in a one-day mediation on June 7, 2021 but no settlement was reached. On December 23, 2021, the state court granted ComEd and Exelon's motion to dismiss with prejudice. On December 30, 2021, plaintiffs filed a motion to reconsider that dismissal and for permission to amend their complaint. The court denied the plaintiffs' motion on January 21, 2022. Plaintiffs have appealed the court's ruling dismissing their complaint to the First District Court of Appeals. On February 15, 2022, Exelon and ComEd moved to dismiss the federal plaintiffs' refiled state law claims, seeking dismissal on the same legal grounds asserted in their motion to dismiss the original state court plaintiffs' complaint. The court granted dismissal of the refiled state claims on February 16, 2022. The original federal plaintiffs appealed that dismissal on February 18, 2022. The two state appeals were consolidated on March 21, 2022. Plaintiffs' opening appellate briefs are currently due June 3, 2022.

•A putative class action lawsuit against Exelon and certain officers of Exelon and ComEd was filed in federal court in December 2019 alleging misrepresentations and omissions in Exelon’s SEC filings related to ComEd’s lobbying activities and the related investigations. The complaint was amended on September 16, 2020, to dismiss two of the original defendants and add other defendants, including ComEd. Defendants filed a motion to dismiss in November 2020. The court denied the motion in April 2021. On May 26, 2021, defendants moved the court to certify its order denying the motion to dismiss for interlocutory appeal. Briefing on the motion was completed in June 2021. That motion was denied on January 28, 2022. In May 2021, the parties each filed respective initial discovery disclosures. On June 9, 2021, defendants filed their answer and affirmative defenses to the complaint and the parties engaged thereafter in discovery. On September 9, 2021, the U.S. government moved to intervene in the lawsuit and stay discovery until the parties entered into an amendment to their protective order that would prohibit the parties from requesting discovery into certain matters, including communications with the U.S. government. The court ordered said amendment to the protective order on November 15, 2021 and discovery resumed. On February 10, 2022, the court granted an extension of the amendment to the protective order, at the U.S. government's request, to May 15, 2022 and directed the parties to submit a proposed joint schedule for the additional case proceedings by May 13, 2022.

•Several shareholders have sent letters to the Exelon Board of Directors from 2020 through May 2022 demanding, among other things, that the Exelon Board of Directors investigate and address alleged breaches of fiduciary duties and other alleged violations by Exelon and ComEd officers and directors related to the conduct described in the DPA. In the first quarter of 2021, the Exelon Board of Directors appointed a Special Litigation Committee (“SLC”) consisting of disinterested and independent parties to investigate and address these shareholders’ allegations and make recommendations to the Exelon Board of Directors based on the outcome of the SLC’s investigation. In July 2021, one of the demand letter shareholders filed a derivative action against current and former Exelon and ComEd officers and directors, and against Exelon, as nominal defendant, asserting the same claims made in its demand letter. On October 12, 2021, the parties to the derivative action filed an agreed motion to stay that litigation for 120 days in order to allow the SLC to continue its investigation, which the court granted. On January 31, 2022, the parties jointly moved the court to extend the stay an additional 120 days.

•Two separate shareholder requests seeking review of certain Exelon books and records were received in August 2021 and January 2022. Exelon responded to both requests and both shareholders have since sent formal shareholder demands to the Exelon Board, as discussed above.

No loss contingencies have been reflected in Exelon’s and ComEd’s consolidated financial statements with respect to these matters, as such contingencies are neither probable nor reasonably estimable at this time.

The ICC continues to conduct an investigation into rate impacts of conduct admitted in the DPA initiated on August 12, 2021. On December 16, 2021, ComEd filed direct testimony addressing the costs recovered from customers related to the DPA and Exelon's funding of the fine paid by ComEd. In that testimony, ComEd proposed to voluntarily refund to customers compensation costs of the former officers charged with wrongdoing in connection with events described in the DPA for the period during which those events occurred as well as costs, previously proposed to be returned, of individuals and entities specifically identified in the DPA, as well as individuals and entities who were referred to ComEd as part of the conduct described in the DPA and who failed, during their tenure at ComEd, to perform work to management expectations. The testimony supports the calculation of the refund amount and proposes a refund mechanism (one-time bill credit in April 2023) and also addresses other topics outlined by statute and the ICC orders initiating the investigation. On April 14, 2022, in response to rebuttal testimony from ICC staff and the Illinois Attorney General, City of Chicago, and CUB, ComEd filed surrebuttal testimony, in which ComEd proposed to increase its voluntary customer refund to $38 million of ICC and FERC jurisdictional amounts, and estimated interest to resolve the issue of the potential expenditure of customer monies on activities identified in the DPA in this matter. An accrual for the amount of the voluntary customer refund has been recorded in Other deferred credits and other liabilities in Exelon’s and ComEd’s Consolidated Balance Sheets as of March 31, 2022. The voluntary customer refund will not be recovered in rates or charged to customers and ComEd will not seek or accept reimbursement or indemnification from any source other than Exelon. The evidentiary hearing on the remaining contested issue was held on April 28, 2022. A final order is expected by September 9, 2022.

Savings Plan Claim (Exelon). On December 6, 2021, seven current and former employees filed a putative ERISA class action suit in U.S. District Court for the Northern District of Illinois against Exelon, its Board of Directors, the former Board Investment Oversight Committee, the Corporate Investment Committee, individual defendants, and other unnamed fiduciaries of the Exelon Corporation Employee Savings Plan (“Plan”). The complaint alleges that the defendants violated their fiduciary duties under the Plan by including certain investment options that allegedly were more expensive than and underperformed similar passively-managed or other funds available in the marketplace and permitting a third-party administrative service provider/recordkeeper and an investment adviser to charge excessive fees for the services provided. The plaintiffs seek declaratory, equitable and monetary relief on behalf of the Plan and participants. On February 16, 2022, the court granted the parties' stipulated dismissal of the individual named defendants without prejudice. The remaining defendants filed a motion to dismiss the complaint on February 25, 2022. The plaintiffs filed their response brief on March 28, 2022 and the defendants filed their reply on April 11, 2022. On March 4, 2022, the Chamber of Commerce filed a brief of amicus curiae in support of the defendants' motion to dismiss. No loss contingencies have been reflected in Exelon’s consolidated financial statements with respect to this matter, as such contingencies are neither probable nor reasonably estimable at this time.

General (All Registrants). The Registrants are involved in various other litigation matters that are being defended and handled in the ordinary course of business. The assessment of whether a loss is probable or reasonably possible, and whether the loss or a range of loss is estimable, often involves a series of complex

judgments about future events. The Registrants maintain accruals for such losses that are probable of being incurred and subject to reasonable estimation. Management is sometimes unable to estimate an amount or range of reasonably possible loss, particularly where (1) the damages sought are indeterminate, (2) the proceedings are in the early stages, or (3) the matters involve novel or unsettled legal theories. In such cases, there is considerable uncertainty regarding the timing or ultimate resolution of such matters, including a possible eventual loss.

Changes in Accumulated Other Comprehensive Income (Exelon)

3 Months Ended

Mar. 31, 2022

Changes in Accumulated Other Comprehensive Income [Abstract]

Changes in Accumulated Other Comprehensive Income

Changes in Accumulated Other Comprehensive Income (Exelon)

The following tables present changes in Exelon's AOCI, net of tax, by component:


Three Months Ended March 31, 2022	Cash Flow Hedges		Pension and Non-Pension Postretirement Benefit Plan Items(a)		Foreign Currency Items		Total
Balance at December 31, 2021	$	(6)	$	(2,721)	$	(23)	$	(2,750)
Separation of Constellation	6		1,994		23		2,023

Amounts reclassified from AOCI	—		14		—		14
Net current-period OCI	—		14		—		14
Balance at March 31, 2022	$	—	$	(713)	$	—	$	(713)


Three Months Ended March 31, 2021	Losses on Cash Flow Hedges		Pension and Non-Pension Postretirement Benefit Plan Items(a)		Foreign Currency Items		Total
Balance at December 31, 2020	$	(5)	$	(3,372)	$	(23)	$	(3,400)
OCI before reclassifications	—		(2)		1		(1)
Amounts reclassified from AOCI	—		55		—		55
Net current-period OCI	—		53		1		54
Balance at March 31, 2021	$	(5)	$	(3,319)	$	(22)	$	(3,346)

______

(a)This AOCI component is included in the computation of net periodic pension and OPEB cost. Additionally, as of February 1, 2022, in connection with the separation, Exelon's pension and OPEB plans were remeasured. See Note 8 — Retirement Benefits for additional information. See Exelon's Statements of Operations and Comprehensive Income for individual components of AOCI.

The following table presents income tax benefit (expense) allocated to each component of Exelon's other comprehensive income (loss):


	Three Months Ended March 31,
		2022		2021
Pension and non-pension postretirement benefit plans:
Prior service benefit reclassified to periodic benefit cost		$	—	$	1
Actuarial loss reclassified to periodic benefit cost		(5)		(19)

Supplemental Financial Information (All Registrants)

3 Months Ended

Mar. 31, 2022

Supplemental Financial Information [Abstract]

Supplemental Financial Information (All Registrants)

Supplemental Statement of Operations Information

The following tables provide additional information about material items recorded in the Registrants' Consolidated Statements of Operations and Comprehensive Income:


	Taxes other than income taxes
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE










Three Months Ended March 31, 2022
Utility taxes(a)	$	221	$	78	$	38	$	27	$	78	$	70	$	7	$	1
Property	94		10		4		46		34		23		10		1
Payroll	37		7		4		4		7		2		1		1

Three Months Ended March 31, 2021
Utility taxes(a)	$	193	$	59	$	35	$	25	$	74	$	67	$	6	$	1
Property	86		8		4		42		32		21		10		1
Payroll	33		7		4		5		7		2		1		—

_________

(a)The Registrants' utility taxes represent municipal and state utility taxes and gross receipts taxes related to their operating revenues. The offsetting collection of utility taxes from customers is recorded in revenues in the Registrants’ Consolidated Statements of Operations and Comprehensive Income.


	Other, net
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Three Months Ended March 31, 2022

AFUDC — Equity	$	36	$	8	$	7	$	6	$	15	$	11	$	2	$	2
Non-service net periodic benefit cost	17		—		—		—		—		—		—		—

Three Months Ended March 31, 2021

AFUDC — Equity	$	28	$	4	$	6	$	7	$	11	$	9	$	1	$	1
Non-service net periodic benefit cost	20		—		—		—		—		—		—		—

Supplemental Cash Flow Information

The following tables provide additional information about material items recorded in the Registrants' Consolidated Statements of Cash Flows.


	Depreciation and amortization
	Exelon(a)		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Three Months Ended March 31, 2022
Property, plant, and equipment(b)	$	726	$	254	$	88	$	117	$	164	$	72	$	45	$	41
Amortization of regulatory assets(b)	179		67		4		54		54		36		12		6
Amortization of intangible assets, net(b)	6		—		—		—		—		—		—		—
Amortization of energy contract assets and liabilities(c)	3		—		—		—		—		—		—		—
Nuclear fuel(d)	66		—		—		—		—		—		—		—
ARO accretion(e)	44		—		—		—		—		—		—		—
Total depreciation, amortization, and accretion	$	1,024	$	321	$	92	$	171	$	218	$	108	$	57	$	47

Three Months Ended March 31, 2021
Property, plant, and equipment(b)	$	1,522	$	239	$	82	$	106	$	154	$	67	$	42	$	37
Amortization of regulatory assets(b)	160		53		4		46		56		35		11		10
Amortization of intangible assets, net(b)	15		—		—		—		—		—		—		—
Amortization of energy contract assets and liabilities(c)	4		—		—		—		—		—		—		—
Nuclear fuel(d)	276		—		—		—		—		—		—		—
ARO accretion(e)	127		—		—		—		—		—		—		—
Total depreciation, amortization, and accretion	$	2,104	$	292	$	86	$	152	$	210	$	102	$	53	$	47

__________

(a)Exelon's amounts include amounts related to Generation prior to the separation. See Note 2 — Discontinued Operations for additional information.

(b)Included in Depreciation and amortization in the Registrants' Consolidated Statements of Operations and Comprehensive Income.

(c)Included in Operating revenues or Purchased power and fuel expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income.

(d)Included in Purchased fuel expense in Exelon's Consolidated Statement of Operations and Comprehensive Income.

(e)Included in Operating and maintenance expense in Exelon's Consolidated Statement of Operations and Comprehensive Income.


	Other non-cash operating activities
	Exelon(a)		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Three Months Ended March 31, 2022
Pension and non-pension postretirement benefit costs	$	44	$	16	$	(2)	$	12	$	13	$	2	$	1	$	3
Allowance for credit losses	78		17		27		18		18		9		6		3
Other decommissioning-related activity	36		—		—		—		—		—		—		—
Energy-related options	60		—		—		—		—		—		—		—
True-up adjustments to decoupling mechanisms and formula rates(b)	(29)		(40)		(6)		12		5		7		1		(3)


Long-term incentive plan	25		—		—		—		—		—		—		—


Amortization of operating ROU asset	23		1		—		7		7		2		2		1


AFUDC — Equity	(36)		(8)		(7)		(6)		(15)		(11)		(2)		(2)

Three Months Ended March 31, 2021
Pension and non-pension postretirement benefit costs	$	95	$	32	$	2	$	14	$	12	$	2	$	1	$	3
Allowance for credit losses	85		13		24		4		10		5		4		1
Other decommissioning-related activity	(322)		—		—		—		—		—		—		—
Energy-related options	17		—		—		—		—		—		—		—
True-up adjustments to decoupling mechanisms and formula rates(b)	(129)		(54)		(10)		(18)		(46)		(26)		(9)		(11)


Long-term incentive plan	32		—		—		—		—		—		—		—


Amortization of operating ROU asset	37		—		—		7		7		1		3		1


AFUDC — Equity	(28)		(4)		(6)		(7)		(11)		(9)		(1)		(1)

__________

(a)Exelon's amounts include amounts related to Generation prior to the separation. See Note 2 — Discontinued Operations for additional information.

(b)For ComEd, reflects the true-up adjustments in regulatory assets and liabilities associated with its distribution, energy efficiency, distributed generation, and transmission formula rates. For BGE, Pepco, DPL, and ACE, reflects the change in regulatory assets and liabilities associated with their decoupling mechanisms and transmission formula rates. For PECO, reflects the change in regulatory assets and liabilities associated with its transmission formula rates. See Note 3 — Regulatory Matters of the Exelon Form 10-K for additional information.

The following tables provide a reconciliation of cash, cash equivalents, and restricted cash reported within the Registrants’ Consolidated Balance Sheets that sum to the total of the same amounts in their Consolidated Statements of Cash Flows.


	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
March 31, 2022
Cash and cash equivalents	$	2,476	$	343	$	26	$	41	$	796	$	502	$	120	$	168
Restricted cash and cash equivalents	430		246		8		34		106		34		73		—
Restricted cash included in other long-term assets	92		92		—		—		—		—		—		—
Total cash, restricted cash, and cash equivalents	$	2,998	$	681	$	34	$	75	$	902	$	536	$	193	$	168

December 31, 2021
Cash and cash equivalents	$	672	$	131	$	36	$	51	$	136	$	34	$	28	$	29
Restricted cash and cash equivalents	321		210		8		4		77		34		43		—
Restricted cash included in other long-term assets	44		43		—		—		—		—		—		—
Cash, restricted cash, and cash equivalents from discontinued operations	582		—		—		—		—		—		—		—
Total cash, restricted cash, and cash equivalents	$	1,619	$	384	$	44	$	55	$	213	$	68	$	71	$	29

March 31, 2021
Cash and cash equivalents	$	1,908	$	86	$	48	$	21	$	558	$	134	$	64	$	353
Restricted cash and cash equivalents	374		270		7		1		37		33		—		4
Restricted cash included in other long-term assets	52		43		—		—		9		—		—		9
Total cash, restricted cash, and cash equivalents(a)	$	2,334	$	399	$	55	$	22	$	604	$	167	$	64	$	366

December 31, 2020
Cash and cash equivalents	$	663	$	83	$	19	$	144	$	111	$	30	$	15	$	17
Restricted cash and cash equivalents	438		279		7		1		39		35		—		3
Restricted cash included in other long-term assets	53		43		—		—		10		—		—		10
Cash, restricted cash, and cash equivalents - Held for Sale	12		—		—		—		—		—		—		—
Total cash, restricted cash, and cash equivalents(a)	$	1,166	$	405	$	26	$	145	$	160	$	65	$	15	$	30

__________

(a)Exelon's amounts include amounts related to Generation prior to the separation. See Note 2 — Discontinued Operations for additional information.

For additional information on restricted cash see Note 1 — Significant Accounting Policies of the Exelon 2021 Form 10-K.

Supplemental Balance Sheet Information

The following table provides additional information about material items recorded in the Registrants' Consolidated Balance Sheets.


	Accrued expenses
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
March 31, 2022
Compensation-related accruals(a)	$	370	$	95	$	51	$	48	$	73	$	26	$	15	$	12
Taxes accrued	258		95		15		78		94		85		10		9
Interest accrued	346		66		36		39		77		37		21		17

December 31, 2021
Compensation-related accruals(a)	$	596	$	155	$	77	$	78	$	113	$	35	$	20	$	17
Taxes accrued	253		94		14		53		96		88		9		11
Interest accrued	297		116		41		44		52		28		8		11

__________

(a)Primarily includes accrued payroll, bonuses and other incentives, vacation, and benefits.

Related Party Transactions (All Registrants)

3 Months Ended

Mar. 31, 2022

Utility Registrants' expense with Generation

The Utility Registrants incurred expenses from transactions with the Generation affiliate as described in the footnotes to the table below prior to separation on February 1, 2022. Such expenses were primarily recorded as Purchased power from affiliates and an immaterial amount recorded as Operating and maintenance expense from affiliates at the Utility Registrants:


	Three Months Ended March 31,
	2022		2021
ComEd(a)	$	59	$	85
PECO(b)	33		42
BGE(c)	18		72
PHI	51		100
Pepco(d)	39		75
DPL(e)	10		21
ACE(f)	2		4

__________

(a)ComEd had an ICC-approved RFP contract with Generation to provide a portion of ComEd’s electric supply requirements. ComEd also purchased RECs and ZECs from Generation.

(b)PECO received electric supply from Generation under contracts executed through PECO’s competitive procurement process. In addition, PECO had a ten-year agreement with Generation to sell solar AECs.

(c)BGE received a portion of its energy requirements from Generation under its MDPSC-approved market-based SOS and gas commodity programs.

(d)Pepco received electric supply from Generation under contracts executed through Pepco's competitive procurement process approved by the MDPSC and DCPSC.

(e)DPL received a portion of its energy requirements from Generation under its MDPSC and DEPSC approved market-based SOS commodity programs.

(f)ACE received electric supply from Generation under contracts executed through ACE's competitive procurement process approved by the NJBPU.

Service Company Costs for Corporate Support

The Registrants receive a variety of corporate support services from BSC. Pepco, DPL, and ACE also receive corporate support services from PHISCO. See Note 1 — Significant Accounting Policies for additional information regarding BSC and PHISCO.

The following table presents the service company costs allocated to the Registrants:


		Operating and maintenance from affiliates					Capitalized costs
	Three Months Ended March 31,					Three Months Ended March 31,
		2022		2021			2022		2021
Exelon
BSC							$	205	$	114
PHISCO							19		17
ComEd
BSC		$	85	$	71		85		45
PECO
BSC		49		39			36		17
BGE
BSC		51		43			38		20
PHI
BSC		50		39			46		32
PHISCO							19		17
Pepco
BSC		29		22			17		13
PHISCO		29		30			8		7

DPL
BSC		18		14			14		10
PHISCO		24		25			6		5

ACE
BSC		15		12			15		8
PHISCO		21		22			5		5

Current Receivables from/Payables to affiliates

The following tables present current receivables from affiliates and current payables to affiliates:

March 31, 2022


				Receivables from affiliates:
	Payables to affiliates:			ComEd			PECO			BGE			Pepco			DPL			ACE			BSC			PHISCO			Other			Total
ComEd					$	—		$	—		$	—		$	—		$	—		$	64		$	—		$	2		$	66
PECO		$	—					—			—			—			—			33			—			5			38
BGE		—			—						—			—			—			35			—			2			37
PHI		—			—			—			—			—			—			7			1			10			18
Pepco		—			—			—						—			—			19			15			—			34
DPL		—			—			—			—						—			3			12			—			15
ACE		—			—			—			—			—						12			11			—			23
Other		3			—			—			—			—			—			—			—						3
Total		$	3		$	—		$	—		$	—		$	—		$	—		$	173		$	39		$	19		$	234

December 31, 2021


				Receivables from affiliates:
	Payables to affiliates:			ComEd			PECO			BGE			Pepco			DPL			ACE			Generation			BSC			PHISCO			Other			Total
ComEd					$	—		$	—		$	—		$	—		$	—		41			$	71		$	—		$	9		$	121
PECO		$	—					—			—			—			—			30			36			—			4			70
BGE		—			—						—			—			—			4			41			—			3			48
PHI		—			1			—			—			—			1			—			5			—			9			16
Pepco		—			—			1						1			1			20			21			12			3			59
DPL		—			—			—			—						—			4			17			11			1			33
ACE		—			—			—			—			—						7			13			9			2			31
Generation		13			—			—			—			—			—						102			—			16			131
Other		3			—			—			—			—			—			11			—			—						14
Total		$	16		$	1		$	1		$	—		$	1		$	2		$	117		$	306		$	32		$	47		$	523

Borrowings from Exelon/PHI intercompany money pool

To provide an additional short-term borrowing option that will generally be more favorable to the borrowing participants than the cost of external financing both Exelon and PHI operate an intercompany money pool. ComEd, PECO, and PHI Corporate participate in the Exelon money pool. Pepco, DPL, and ACE participate in the PHI intercompany money pool.

Noncurrent Receivables from affiliates

ComEd and PECO have noncurrent receivables with Generation as a result of the nuclear decommissioning contractual construct whereby, to the extent NDT funds are greater than the underlying ARO at the end of decommissioning, such amounts are due back to ComEd and PECO, as applicable, for payment to their respective customers. The receivables are recorded in Receivable related to Regulatory Agreement Units as of March 31, 2022 and in noncurrent Receivables from affiliates as of December 31, 2021. See Note 10 — Asset Retirement Obligations of the Combined Notes to Consolidated Financial Statements of the Exelon 2021 Form 10-K for additional information.

Long-term debt to financing trusts

The following table presents Long-term debt to financing trusts:


	March 31, 2022						December 31, 2021
	Exelon		ComEd		PECO		Exelon		ComEd		PECO
ComEd Financing III	$	206	$	205	$	—	$	206	$	205	$	—
PECO Trust III	81		—		81		81		—		81
PECO Trust IV	103		—		103		103		—		103
Total	$	390	$	205	$	184	$	390	$	205	$	184

Planned Separation

3 Months Ended

Mar. 31, 2022

Discontinued Operations and Disposal Groups [Abstract]

Disposal Groups, Including Discontinued Operations, Disclosure [Text Block]

Discontinued Operations (Exelon)

Constellation was newly formed and incorporated in Pennsylvania on June 15, 2021 for the purposes of separation and holds Generation (including Generation's subsidiaries).

Pursuant to the separation:

•Exelon made a cash payment of $1.75 billion to Constellation on January 31, 2022.

•Exelon contributed its equity ownership interest in Generation to Constellation. Exelon no longer retains any equity ownership interest in Generation or Constellation.

•Exelon transferred certain corporate assets and employee-related obligations to Constellation.

•Exelon received cash from Generation of $258 million to settle the intercompany loan on January 31, 2022. See Note 10 — Debt and Credit Agreements for additional information.

Continuing Involvement

•ComEd had an ICC-approved RFP contract with Generation to provide a portion of ComEd’s electric supply requirements. ComEd also purchased RECs and ZECs from Generation.

•BGE received a portion of its energy requirements from Generation under its MDPSC-approved market-based SOS and gas commodity programs.

•Pepco received electric supply from Generation under contracts executed through Pepco’s competitive procurement process approved by the MDPSC and DCPSC.

•DPL received a portion of its energy requirements from Generation under its MDPSC and DEPSC approved market-based SOS commodity programs.

•ACE received electric supply from Generation under contracts executed through ACE’s competitive procurement process approved by the NJBPU.

Discontinued Operations

The separation represented a strategic shift that would have a major effect on Exelon’s operations and financial results. Accordingly, the separation meets the criteria for discontinued operations.


	Three Months Ended March 31,
	2022		2021
Operating revenues
Competitive business revenues	$	1,855	$	5,265
Competitive business revenues from affiliates	161		294
Total operating revenues	2,016		5,559
Operating expenses
Competitive businesses purchased power and fuel	1,138		4,610

Operating and maintenance(a)	371		904

Depreciation and amortization	94		940
Taxes other than income taxes	44		121
Total operating expenses	1,647		6,575
Gain on sales of assets and businesses	10		71
Operating income (loss)	379		(945)
Other income and (deductions)
Interest expense, net	(20)		(68)

Other, net	(281)		167
Total other income and (deductions)	(301)		99
Income (loss) before income taxes	78		(846)
Income taxes	(40)		(58)
Equity in losses of unconsolidated affiliates	(1)		(1)
Net income (loss)	117		(789)
Net income attributable to noncontrolling interests	1		25
Net income (loss) from discontinued operations	$	116	$	(814)

__________

The following table presents the assets and liabilities of discontinued operations in Exelon’s Consolidated Balance Sheet as of December 31, 2021:


	December 31, 2021
ASSETS
Current assets
Cash and cash equivalents	$	510
Restricted cash and cash equivalents	72
Accounts receivable
Customer accounts receivable	1,724
Customer allowance for credit losses	(55)
Customer accounts receivable, net	1,669
Other accounts receivable	596
Other allowance for credit losses	(4)
Other accounts receivable, net	592
Mark-to-market derivative assets	2,169
Inventories, net
Fossil fuel and emission allowances	284
Materials and supplies	1,004
Renewable energy credits	529
Assets held for sale	13
Other	993
Total current assets of discontinued operations	7,835
Property, plant, and equipment (net of accumulated depreciation and amortization of $15,888)	19,661
Deferred debits and other assets
Nuclear decommissioning trust funds	15,938
Investments	193

Mark-to-market derivative assets	949
Other	1,768
Total property, plant, and equipment, deferred debits, and other assets of discontinued operations	38,509
Total assets of discontinued operations	$	46,344


	December 31, 2021
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current liabilities
Short-term borrowings	$	2,082
Long-term debt due within one year	1,220
Accounts payable	1,757
Accrued expenses	818
Mark-to-market derivative liabilities	981

Renewable energy credit obligation	779
Liabilities held for sale	3
Other	300
Total current liabilities of discontinued operations	7,940
Long-term debt	4,575
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	3,583
Asset retirement obligations	12,819
Pension obligations	939
Non-pension postretirement benefit obligations	876
Spent nuclear fuel obligation	1,210
Mark-to-market derivative liabilities	513

Other	1,161
Total long-term debt, deferred credits, and other liabilities of discontinued operations	25,676
Total liabilities of discontinued operations	$	33,616


	Three Months Ended March 31, 2022
	2022		2021
Non-cash items included in net income (loss) from discontinued operations:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	$	207	$	1,346

Gain on sales of assets and businesses	9		(71)
Deferred income taxes and amortization of investment tax credits	(143)		(234)
Net fair value changes related to derivatives	(59)		(178)
Net realized and unrealized losses (gains) on NDT fund investments	205		(118)
Net unrealized losses on equity investments	16		23
Other decommissioning-related activity	36		(332)
Cash flows from investing activities:
Capital expenditures	(227)		(394)
Collection of DPP	169		1,574
Supplemental cash flow information:
Decrease in capital expenditures not paid	(128)		(37)
Increase in DPP	348		1,339
Increase in PP&E related to ARO update	335		—

Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2022

Accounting Policies [Abstract]

Description of Business and Basis of Presentation (All Registrants)

Description of Business

Exelon is a utility services holding company engaged in the energy distribution and transmission businesses through ComEd, PECO, BGE, Pepco, DPL, and ACE.

Name of Registrant

Business

Service Territories

Commonwealth Edison Company

Purchase and regulated retail sale of electricity

Northern Illinois, including the City of Chicago

Transmission and distribution of electricity to retail customers

PECO Energy Company

Purchase and regulated retail sale of electricity and natural gas

Southeastern Pennsylvania, including the City of Philadelphia (electricity)

Transmission and distribution of electricity and distribution of natural gas to retail customers

Pennsylvania counties surrounding the City of Philadelphia (natural gas)

Baltimore Gas and Electric Company

Purchase and regulated retail sale of electricity and natural gas

Central Maryland, including the City of Baltimore (electricity and natural gas)

Transmission and distribution of electricity and distribution of natural gas to retail customers

Pepco Holdings LLC

Utility services holding company engaged, through its reportable segments Pepco, DPL, and ACE

Service Territories of Pepco, DPL, and ACE

Potomac Electric
Power Company

Purchase and regulated retail sale of electricity

District of Columbia, and major portions of Montgomery and Prince George’s Counties, Maryland

Transmission and distribution of electricity to retail customers

Delmarva Power &
Light Company

Purchase and regulated retail sale of electricity and natural gas

Portions of Delaware and Maryland (electricity)

Transmission and distribution of electricity and distribution of natural gas to retail customers

Portions of New Castle County, Delaware (natural gas)

Atlantic City Electric Company

Purchase and regulated retail sale of electricity

Portions of Southern New Jersey

Transmission and distribution of electricity to retail customers

Basis of Presentation

Prior Period Adjustments and Reclassifications (Exelon, PHI, ACE)

The error was corrected in the Exelon and PHI financial statements for the three months ended March 31, 2022 as it was not material, resulting in an increase to Net income of $8 million.

Discontinued Operations (Tables) - Exelon Generation Co L L C [Member]

3 Months Ended

12 Months Ended

Mar. 31, 2022

Dec. 31, 2021

Discontinued Operations - Income Statement

Discontinued Operations - Income Statement


	Three Months Ended March 31,
	2022		2021
Operating revenues
Competitive business revenues	$	1,855	$	5,265
Competitive business revenues from affiliates	161		294
Total operating revenues	2,016		5,559
Operating expenses
Competitive businesses purchased power and fuel	1,138		4,610

Operating and maintenance(a)	371		904

Depreciation and amortization	94		940
Taxes other than income taxes	44		121
Total operating expenses	1,647		6,575
Gain on sales of assets and businesses	10		71
Operating income (loss)	379		(945)
Other income and (deductions)
Interest expense, net	(20)		(68)

Other, net	(281)		167
Total other income and (deductions)	(301)		99
Income (loss) before income taxes	78		(846)
Income taxes	(40)		(58)
Equity in losses of unconsolidated affiliates	(1)		(1)
Net income (loss)	117		(789)
Net income attributable to noncontrolling interests	1		25
Net income (loss) from discontinued operations	$	116	$	(814)

__________

Discontinued Operations - Balance Sheet [Table Text Block]

The following table presents the assets and liabilities of discontinued operations in Exelon’s Consolidated Balance Sheet as of December 31, 2021:


	December 31, 2021
ASSETS
Current assets
Cash and cash equivalents	$	510
Restricted cash and cash equivalents	72
Accounts receivable
Customer accounts receivable	1,724
Customer allowance for credit losses	(55)
Customer accounts receivable, net	1,669
Other accounts receivable	596
Other allowance for credit losses	(4)
Other accounts receivable, net	592
Mark-to-market derivative assets	2,169
Inventories, net
Fossil fuel and emission allowances	284
Materials and supplies	1,004
Renewable energy credits	529
Assets held for sale	13
Other	993
Total current assets of discontinued operations	7,835
Property, plant, and equipment (net of accumulated depreciation and amortization of $15,888)	19,661
Deferred debits and other assets
Nuclear decommissioning trust funds	15,938
Investments	193

Mark-to-market derivative assets	949
Other	1,768
Total property, plant, and equipment, deferred debits, and other assets of discontinued operations	38,509
Total assets of discontinued operations	$	46,344


	December 31, 2021
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current liabilities
Short-term borrowings	$	2,082
Long-term debt due within one year	1,220
Accounts payable	1,757
Accrued expenses	818
Mark-to-market derivative liabilities	981

Renewable energy credit obligation	779
Liabilities held for sale	3
Other	300
Total current liabilities of discontinued operations	7,940
Long-term debt	4,575
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	3,583
Asset retirement obligations	12,819
Pension obligations	939
Non-pension postretirement benefit obligations	876
Spent nuclear fuel obligation	1,210
Mark-to-market derivative liabilities	513

Other	1,161
Total long-term debt, deferred credits, and other liabilities of discontinued operations	25,676
Total liabilities of discontinued operations	$	33,616

Discontinued Operations - Cash Flows [Table Text Block]


	Three Months Ended March 31, 2022
	2022		2021
Non-cash items included in net income (loss) from discontinued operations:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	$	207	$	1,346

Gain on sales of assets and businesses	9		(71)
Deferred income taxes and amortization of investment tax credits	(143)		(234)
Net fair value changes related to derivatives	(59)		(178)
Net realized and unrealized losses (gains) on NDT fund investments	205		(118)
Net unrealized losses on equity investments	16		23
Other decommissioning-related activity	36		(332)
Cash flows from investing activities:
Capital expenditures	(227)		(394)
Collection of DPP	169		1,574
Supplemental cash flow information:
Decrease in capital expenditures not paid	(128)		(37)
Increase in DPP	348		1,339
Increase in PP&E related to ARO update	335		—

Regulatory Matters (Tables)

3 Months Ended

Mar. 31, 2022

Regulated Operations [Abstract]

Public Utilities Distribution Rate Cases [Table Text Block]

The following tables show the completed and pending distribution base rate case proceedings in 2022.

Completed Distribution Base Rate Case Proceedings


Registrant/Jurisdiction	Filing Date	Service	Requested Revenue Requirement Increase		Approved Revenue Requirement Increase		Approved ROE		Approval Date	Rate Effective Date
ComEd - Illinois(a)	April 16, 2021	Electric	$	51	$	46	7.36	%	December 1, 2021	January 1, 2022
PECO - Pennsylvania	March 30, 2021	Electric	246		132		N/A(b)		November 18, 2021	January 1, 2022
BGE - Maryland(c)	May 15, 2020 (amended September 11, 2020)	Electric	203		140		9.50	%	December 16, 2020	January 1, 2021
		Natural Gas	108		74		9.65	%
Pepco - District of Columbia(d)	May 30, 2019 (amended June 1, 2020)	Electric	136		109		9.275	%	June 8, 2021	July 1, 2021
Pepco - Maryland(e)	October 26, 2020 (amended March 31, 2021)	Electric	104		52		9.55	%	June 28, 2021	June 28, 2021
DPL - Maryland(f)	September 1, 2021 (amended December 23, 2021)	Electric	27		13		9.60	%	March 2, 2022	March 2, 2022
ACE - New Jersey(g)	December 9, 2020 (amended February 26, 2021)	Electric	67		41		9.60	%	July 14, 2021	January 1, 2022

__________

(b)The PECO electric base rate case proceeding was resolved through a settlement agreement, which did not specify an approved ROE.

(f)The approved settlement reflects a 9.60% ROE, which is solely for the purposes of calculating AFUDC and regulatory asset carrying costs.

Pending Distribution Base Rate Case Proceedings

Registrant/Jurisdiction

Filing Date

Service

Requested Revenue Requirement Increase

Requested ROE

Expected Approval Timing

ComEd - Illinois(a)

April 15, 2022

Electric

199

7.85

Fourth quarter of 2022

PECO - Pennsylvania

March 31, 2022

Natural Gas

10.95

Fourth quarter of 2022

DPL - Delaware(b)

January 14, 2022 (amended February 28, 2022)

Natural Gas

10.30

First quarter of 2023

__________

(b)The rates will go into effect on August 14, 2022, subject to refund.

Public Utilities Transmission Rate Filings [Table Text Block]


Registrant(a)	Initial Revenue Requirement Increase		Annual Reconciliation Decrease		Total Revenue Requirement Increase			Allowed Return on Rate Base(c)		Allowed ROE(d)
ComEd	$	24	$	(24)	$	—		8.11	%	11.50	%
BGE	25		(4)		16		(b)	7.30	%	10.50	%

(a)All rates are effective June 1, 2022 - May 31, 2023, subject to review by interested parties pursuant to review protocols of ComEd's and BGE's tariff.

(c)Represents the weighted average debt and equity return on transmission rate bases.

Capitalized Ratemaking Amounts Not Recognized [Table Text Block]


	Exelon		ComEd(a)		PECO		BGE(b)		PHI		Pepco(c)		DPL(c)		ACE
March 31, 2022	$	49	$	2	$	—	$	34	$	13	$	11	$	2	$	—

December 31, 2021	43		1		—		37		5		3		2		—

__________

(a)Reflects ComEd's unrecognized equity returns earned for ratemaking purposes on its energy efficiency and electric distribution formula rate regulatory assets.

(b)BGE's authorized amounts capitalized for ratemaking purposes primarily relate to earnings on shareholder's investment on its AMI programs.

Revenue from Contracts with Customers (Tables)

3 Months Ended

Mar. 31, 2022

Contracts with Customers [Line Items]

Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction


	2022		2023		2024		2025		2026 and thereafter		Total
Exelon	$	6	$	8	$	6	$	5	$	82	$	107
PHI	6		8		6		5		82		107
Pepco	4		6		5		5		65		85
DPL	1		1		—		—		9		11
ACE	1		1		1		—		8		11

Segment Information (Tables)

3 Months Ended

Mar. 31, 2022

Segment Tables [Line Items]

Analysis and reconciliation of reportable segment information

Three Months Ended March 31, 2022 and 2021


	ComEd		PECO		BGE		PHI		Other(a)		Intersegment Eliminations		Exelon
Operating revenues(b):
2022
Electric revenues	$	1,734	$	741	$	736	$	1,318	$	—	$	(7)	$	4,522
Natural gas revenues	—		306		418		83		—		(2)		$	805
Shared service and other revenues	—		—		—		3		576		(579)		$	—
Total operating revenues	$	1,734	$	1,047	$	1,154	$	1,404	$	576	$	(588)	$	5,327
2021
Electric revenues	$	1,535	$	661	$	632	$	1,170	$	—	$	(7)	$	3,991
Natural gas revenues	—		228		342		71		—		—		641
Shared service and other revenues	—		—		—		3		491		(494)		—
Total operating revenues	$	1,535	$	889	$	974	$	1,244	$	491	$	(501)	$	4,632

Intersegment revenues(c):
2022	$	6	$	1	$	7	$	3	$	576	$	(587)	$	6
2021	6		2		6		3		487		(497)		7
Depreciation and amortization:
2022	$	321	$	92	$	171	$	218	$	15	$	—	$	817
2021	292		86		152		210		17		—		757
Operating expenses:
2022	$	1,406	$	793	$	919	$	1,215	$	625	$	(531)	$	4,427
2021	1,210		679		752		1,058		448		(339)		3,808
Interest expense, net:
2022	$	100	$	41	$	35	$	69	$	93	$	—	$	338
2021	96		38		34		67		83		—		318
Income (loss) from continuing operations before income taxes:
2022	$	240	$	220	$	207	$	137	$	(62)	$	(43)	$	699
2021	236		177		196		136		(32)		(149)		564
Income Taxes:
2022	$	52	$	14	$	9	$	7	$	146	$	(10)	$	218
2021	39		10		(13)		8		7		(12)		39
Net income (loss) from continuing operations:
2022	$	188	$	206	$	198	$	130	$	(208)	$	(33)	$	481
2021	197		167		209		128		(39)		(137)		525
Capital Expenditures:
2022	$	617	$	344	$	303	$	409	$	22	$	—	$	1,695
2021	613		295		336		456		46		—		1,746
Total assets:
March 31, 2022	$	37,013	$	14,113	$	12,509	$	25,636	$	7,583	$	(4,156)	$	92,698
December 31, 2021	36,470		13,824		12,324		24,744		7,634		(8,319)		86,677

__________

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

(c)See Note 15 — Related Party Transactions for additional information on intersegment revenues.

PHI:


	Pepco		DPL		ACE		Other(a)		Intersegment Eliminations		PHI
Operating revenues(b):
2022
Electric revenues	$	614	$	348	$	349	$	—	$	7	$	1,318
Natural gas revenues	—		83		—		—		—		83
Shared service and other revenues	—		—		—		107		(104)		3
Total operating revenues	$	614	$	431	$	349	$	107	$	(97)	$	1,404
2021
Electric revenues	$	553	$	311	$	310	$	—	$	(4)	$	1,170
Natural gas revenues	—		71		—		—		—		71
Shared service and other revenues	—		—		—		95		(92)		3
Total operating revenues	$	553	$	382	$	310	$	95	$	(96)	$	1,244
Intersegment revenues(c):
2022	$	1	$	1	$	1	$	97	$	(97)	$	3
2021	1		2		1		95		(96)		3
Depreciation and amortization:
2022	$	108	$	57	$	47	$	6	$	—	$	218
2021	102		53		47		8		—		210
Operating expenses:
2022	$	547	$	357	$	311	$	97	$	(97)	$	1,215
2021	466		309		282		97		(96)		1,058
Interest expense, net:
2022	$	36	$	16	$	14	$	3	$	—	$	69
2021	34		15		15		3		—		67
Income (loss) before income taxes:
2022	$	44	$	60	$	27	$	6	$	—	$	137
2021	65		61		14		(4)		—		136
Income Taxes:
2022	$	(2)	$	4	$	1	$	4	$	—	$	7
2021	6		5		—		(3)		—		8
Net income (loss):
2022	$	46	$	56	$	26	$	2	$	—	$	130
2021	59		56		14		(1)		—		128
Capital Expenditures:
2022	$	218	$	103	$	87	$	1	$	—	$	409
2021	220		112		123		1		—		456
Total assets:
March 31, 2022	$	10,458	$	5,573	$	4,929	$	4,720	$	(44)	$	25,636
December 31, 2021	9,903		5,412		4,556		4,933		(60)		24,744

__________

(a)Other primarily includes PHI’s corporate operations, shared service entities, and other financing and investment activities.

(c)Includes intersegment revenues with ComEd, BGE, and PECO, which are eliminated at Exelon.

Schedule of Revenue by Major Customers by Reporting Segments [Table Text Block]



	Three Months Ended March 31, 2022
Revenues from contracts with customers	ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Electric revenues
Residential	$	857	$	487	$	417	$	652	$	275	$	207	$	170
Small commercial & industrial	423		111		81		141		38		56		47
Large commercial & industrial	153		64		131		323		253		26		44
Public authorities & electric railroads	14		8		7		16		8		4		4
Other(a)	239		62		97		193		46		56		81
Total electric revenues(b)	$	1,686	$	732	$	733	$	1,325	$	620	$	349	$	346
Natural gas revenues
Residential	$	—	$	218	$	282	$	51	$	—	$	51	$	—
Small commercial & industrial	—		76		45		21		—		21		—
Large commercial & industrial	—		—		65		3		—		3		—
Transportation	—		8		—		4		—		4		—
Other(c)	—		3		35		4		—		4		—
Total natural gas revenues(d)	$	—	$	305	$	427	$	83	$	—	$	83	$	—
Total revenues from contracts with customers	$	1,686	$	1,037	$	1,160	$	1,408	$	620	$	432	$	346

Other revenues
Revenues from alternative revenue programs	$	40	$	6	$	(12)	$	(5)	$	(7)	$	(1)	$	3
Other electric revenues(e)	8		3		4		1		1		—		—
Other natural gas revenues(e)	—		1		2		—		—		—		—

Total other revenues	$	48	$	10	$	(6)	$	(4)	$	(6)	$	(1)	$	3
Total revenues for reportable segments	$	1,734	$	1,047	$	1,154	$	1,404	$	614	$	431	$	349



	Three Months Ended March 31, 2021
Revenues from contracts with customers	ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Electric revenues
Residential	$	741	$	433	$	362	$	605	$	253	$	190	$	162
Small commercial & industrial	367		100		69		118		33		46		39
Large commercial & industrial	134		57		105		248		184		21		43
Public authorities & electric railroads	11		9		7		13		6		4		3
Other(a)	220		52		77		143		51		41		52
Total electric revenues(b)	$	1,473	$	651	$	620	$	1,127	$	527	$	302	$	299
Natural gas revenues
Residential	$	—	$	160	$	216	$	46	$	—	$	46	$	—
Small commercial & industrial	—		59		35		18		—		18		—
Large commercial & industrial	—		—		54		2		—		2		—
Transportation	—		7		—		4		—		4		—
Other(c)	—		2		31		1		—		1		—
Total natural gas revenues(d)	$	—	$	228	$	336	$	71	$	—	$	71	$	—
Total revenues from contracts with customers	$	1,473	$	879	$	956	$	1,198	$	527	$	373	$	299

Other revenues
Revenues from alternative revenue programs	$	54	$	10	$	18	$	46	$	26	$	9	$	11
Other electric revenues(e)	8		—		—		—		—		—		—


Total other revenues	$	62	$	10	$	18	$	46	$	26	$	9	$	11
Total revenues for reportable segments	$	1,535	$	889	$	974	$	1,244	$	553	$	382	$	310

__________

(a)Includes revenues from transmission revenue from PJM, wholesale electric revenue and mutual assistance revenue.

(b)Includes operating revenues from affiliates in 2022 and 2021 respectively of:

•$6 million, $6 million at ComEd

•$1 million, $1 million at PECO

•$2 million, $2 million at BGE

•$3 million, $3 million at PHI

•$1 million, $1 million at Pepco

•$2 million, $2 million at DPL

•$1 million, $1 million at ACE

(c)Includes revenues from off-system natural gas sales.

(d)Includes operating revenues from affiliates in 2022 and 2021 respectively of:

•less than $1 million, less than $1 million at PECO

•$6 million, $4 million at BGE

(e)Includes late payment charge revenues.

Accounts Receivable (Tables)

3 Months Ended

Mar. 31, 2022

Accounts, Notes, Loans and Financing Receivable, Gross, Allowance, and Net [Abstract]

Allowance for credit loss rollforward

The following tables present the rollforward of Allowance for Credit Losses on Customer Accounts Receivable.
















	Three Months Ended March 31, 2022
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2021	$	320	$	73	$	105	$	38	$	104	$	37	$	18	$	49
Plus: Current period provision for expected credit losses(a)	110		26		31		26		27		11		7		9
Less: Write-offs, net of recoveries(b)(c)	41		7		11		5		18		8		1		9
Balance as of March 31, 2022	$	389	$	92	$	125	$	59	$	113	$	40	$	24	$	49

	Three Months Ended March 31, 2021
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2020	$	334	$	97	$	116	$	35	$	86	$	32	$	22	$	32
Plus: Current period provision for expected credit losses(d)	70		21		20		9		20		11		6		3
Less: Write-offs, net of recoveries(b)	27		15		6		1		5		2		3		—
Balance as of March 31, 2021	$	377	$	103	$	130	$	43	$	101	$	41	$	25	$	35

__________

(b)Recoveries were not material to the Registrants.

The following tables present the rollforward of Allowance for Credit Losses on Other Accounts Receivable.
















	Three Months Ended March 31, 2022
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2021	$	72	$	17	$	7	$	9	$	39	$	16	$	8	$	15
Plus: Current period provision for expected credit losses	14		4		3		3		4		2		1		1
Less: Write-offs, net of recoveries(a)	5		1		1		1		2		—		—		2
Balance as of March 31, 2022	$	81	$	20	$	9	$	11	$	41	$	18	$	9	$	14

	Three Months Ended March 31, 2021
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2020	$	71	$	21	$	8	$	9	$	33	$	13	$	9	$	11
Plus: Current period provision for expected credit losses	10		1		4		1		4		2		1		1
Less: Write-offs, net of recoveries(a)	2		—		1		1		—		—		—		—
Balance as of March 31, 2021	$	79	$	22	$	11	$	9	$	37	$	15	$	10	$	12

__________

(a)Recoveries were not material to the Registrants.

Unbilled customer revenue

The following table provides additional information about unbilled customer revenues recorded in the Registrants' Consolidated Balance Sheets as of March 31, 2022 and December 31, 2021.


	Unbilled customer revenues(a)
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
March 31, 2022	$	629	$	189	$	127	$	139	$	174	$	89	$	50	$	35
December 31, 2021	747		240		161		171		175		82		53		40

__________

(a)Unbilled customer revenues are classified in Customer accounts receivables, net in the Registrants' Consolidated Balance Sheets.

Purchases and sales of accounts receivable


	Total receivables purchased
	Exelon(a)		ComEd		PECO		BGE(a)		PHI		Pepco		DPL		ACE
Three months ended March 31, 2022	$	1,044	$	248	$	292	$	222	$	282	$	174	$	57	$	51
Three months ended March 31, 2021	1,023		266		290		199		268		166		56		46

__________

(a)Includes $4 million and $12 million of receivables purchased from Generation for the three months ended March 31, 2022 and 2021, respectively.

Income Taxes (Tables)

3 Months Ended

Mar. 31, 2022

Income Tax Disclosure [Abstract]

Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]

The effective income tax rate from continuing operations varies from the U.S. federal statutory rate principally due to the following:


	Three Months Ended March 31, 2022(a)
	Exelon		ComEd		PECO(b)		BGE(b)		PHI		Pepco(b)		DPL		ACE(b)
U.S. Federal statutory rate	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit(c)	21.1		8.0		(0.1)		2.4		3.7		(4.5)		6.2		6.8
Plant basis differences	(3.6)		(0.6)		(11.3)		(0.9)		(1.6)		(2.6)		(0.7)		(1.3)
Excess deferred tax amortization	(11.5)		(6.3)		(3.2)		(17.6)		(17.7)		(17.4)		(19.4)		(22.2)
Amortization of investment tax credit, including deferred taxes on basis difference	(0.1)		(0.1)		—		(0.1)		(0.1)		—		(0.2)		(0.2)
Tax credits(d)	1.7		(0.3)		—		(0.4)		(0.4)		(0.4)		(0.3)		(0.3)
Other(e)	2.6		—		—		(0.1)		0.2		(0.6)		0.1		(0.1)
Effective income tax rate	31.2	%	21.7	%	6.4	%	4.3	%	5.1	%	(4.5)	%	6.7	%	3.7	%


	Three Months Ended March 31, 2021(a)
	Exelon		ComEd		PECO(f)		BGE(f)		PHI		Pepco		DPL		ACE(f)
U.S. Federal statutory rate	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	2.8		6.8		(1.6)		(10.1)		6.1		5.5		6.4		6.9
Plant basis differences	(3.4)		(0.6)		(10.5)		(1.4)		(1.5)		(2.1)		(0.7)		(0.9)
Excess deferred tax amortization	(12.0)		(6.9)		(3.2)		(15.5)		(19.3)		(15.1)		(18.5)		(28.7)
Amortization of investment tax credit, including deferred taxes on basis difference	(0.1)		(0.1)		—		(0.1)		(0.1)		—		(0.2)		(0.2)
Tax credits	(0.3)		(0.2)		—		(0.4)		(0.2)		(0.2)		(0.1)		(0.3)
Other	(1.1)		(3.5)		(0.1)		(0.1)		(0.1)		0.1		0.3		2.2
Effective income tax rate	6.9	%	16.5	%	5.6	%	(6.6)	%	5.9	%	9.2	%	8.2	%	—	%

__________

(a)Positive percentages represent income tax expense. Negative percentages represent income tax benefit.

(d)For Exelon, reflects the income tax expense related to the write-off of federal tax credits subject to recapture of approximately $15 million as a result of the separation.

(e)For Exelon, primarily reflects the nondeductible transaction costs of approximately $19 million arising as part of the separation.

certain income tax benefits. For ACE, the lower effective tax rate is primarily due to the acceleration of certain income tax benefits due to distribution rate case settlements.

Schedule of Unrecognized Tax Benefits Roll Forward [Table Text Block]

Exelon, PHI and ACE have the following unrecognized tax benefits as of March 31, 2022 and December 31, 2021. ComEd's, PECO's, BGE's, Pepco's, and DPL's amounts are not material.


	Exelon		PHI		ACE
March 31, 2022	$	146	$	56	$	16
December 31, 2021	143		56		16

__________

Retirement Benefits (Tables)

3 Months Ended

Mar. 31, 2022

Retirement Benefits [Abstract]

Calculation of Net Periodic Benefit Costs



	Pension Benefits				OPEB
	Three Months Ended March 31,				Three Months Ended March 31,
	2022		2021		2022		2021
Components of net periodic benefit cost:
Service cost	$	61	$	74	$	10	$	14
Interest cost	110		102		19		17
Expected return on assets	(209)		(213)		(25)		(26)
Amortization of:
Prior service cost (credit)	1		1		(5)		(6)
Actuarial loss	76		100		4		7
Curtailment benefits	—		—		—		(1)


Net periodic benefit cost	$	39	$	64	$	3	$	5

Allocated Portion of Pension and Postretirement Benefit Costs


	Three Months Ended March 31,
Pension and OPEB Costs		2022		2021
Exelon		$	42	$	69
ComEd		16		32
PECO		(2)		2
BGE		11		15
PHI		13		12
Pepco		2		2
DPL		1		1
ACE		3		3

Defined Contribution Savings Plans


	Three Months Ended March 31,
Savings Plans Matching Contributions		2022		2021
Exelon		$	20	$	20
ComEd		8		8
PECO		3		3
BGE		2		2
PHI		3		3
Pepco		1		1
DPL		1		1
ACE		—		—

Debt and Credit Agreements (Tables)

3 Months Ended

Mar. 31, 2022

Debt Instrument [Line Items]

Schedule of Commercial Paper Borrowings


	Outstanding Commercial Paper as of				Average Interest Rate on Commercial Paper Borrowings as of
Commercial Paper Issuer	March 31, 2022		December 31, 2021		March 31, 2022		December 31, 2021
Exelon(a)	$	250	$	599	0.87	%	0.35	%


BGE	250		130		0.87	%	0.37	%
PHI(b)	—		469		—	%	0.35	%

Pepco	—		175		—	%	0.33	%
DPL	—		149		—	%	0.36	%
ACE	—		145		—	%	0.35	%

__________

(a)Exelon Corporate had no outstanding commercial paper borrowings as of March 31, 2022 and December 31, 2021.

(b)Represents the consolidated amounts of Pepco, DPL, and ACE.

Schedule of Revolving Credit Agreements


Borrower	Aggregate Bank Commitment	Interest Rate
Exelon Corporate	900	SOFR plus 1.275	%
ComEd	1,000	SOFR plus 1.000	%
PECO	600	SOFR plus 0.900	%
BGE	600	SOFR plus 0.900	%
Pepco	300	SOFR plus 1.075	%
DPL	300	SOFR plus 1.000	%
ACE	300	SOFR plus 1.075	%

Schedule of Long-term Debt Instruments [Table Text Block]

During the three months ended March 31, 2022, the following long-term debt was issued:

Company

Type

Interest Rate

Maturity

Amount

Use of Proceeds

Exelon

SMBC Term Loan Agreement

SOFR plus 0.65%

July 21, 2023

$300

Fund a cash payment to Constellation and for general corporate purposes.

Exelon

U.S. Bank Term Loan Agreement

SOFR plus 0.65%

July 21, 2023

300

Fund a cash payment to Constellation and for general corporate purposes.

Exelon

PNC Term Loan Agreement

SOFR plus 0.65%

July 24, 2023

250

Fund a cash payment to Constellation and for general corporate purposes.

Exelon

Notes

2.75%

March 15, 2027

650

Repay existing indebtedness and for general corporate purposes.

Exelon

Notes

3.35%

March 15, 2032

650

Repay existing indebtedness and for general corporate purposes.

Exelon

Notes

4.10%

March 15, 2052

700

Repay existing indebtedness and for general corporate purposes.

ComEd

First Mortgage Bonds, Series 132

3.15%

March 15, 2032

300

Repay outstanding commercial paper obligations and to fund other general corporate purposes.

ComEd

First Mortgage Bonds, Series 133

3.85%

March 15, 2052

450

Repay outstanding commercial paper obligations and to fund other general corporate purposes.

Pepco(a)

First Mortgage Bonds

3.97%

March 24, 2052

400

Repay existing indebtedness and for general corporate purposes.

DPL

First Mortgage Bonds

3.06%

February 15, 2052

125

Repay existing indebtedness and for general corporate purposes.

ACE

First Mortgage Bonds

2.27%

February 15, 2032

Repay existing indebtedness and for general corporate purposes.

ACE

First Mortgage Bonds

3.06%

February 15, 2052

150

Repay existing indebtedness and for general corporate purposes.

__________

Tabular disclosure of long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the entity, if longer.

Fair Value of Financial Liabilities Recorded at Amortized Cost

Fair Value of Financial Assets and Liabilities (Tables)

3 Months Ended

Mar. 31, 2022

Fair Value Disclosures [Abstract]


	March 31, 2022								December 31, 2021
	Carrying Amount		Fair Value						Carrying Amount		Fair Value
			Level 2		Level 3		Total				Level 2		Level 3		Total
Long-Term Debt, including amounts due within one year(a)
Exelon	$	37,162	$	35,174	$	2,645	$	37,819	$	32,902	$	34,897	$	2,217	$	37,114
ComEd	10,515		10,894		—		10,894		9,773		11,305		—		11,305
PECO	4,198		4,244		50		4,294		4,197		4,740		50		4,790
BGE	3,961		3,969		—		3,969		3,961		4,406		—		4,406
PHI	8,233		5,453		2,595		8,048		7,547		5,970		2,167		8,137
Pepco	3,841		2,901		1,272		4,173		3,445		3,201		975		4,176
DPL	1,935		1,300		592		1,892		1,810		1,426		552		1,978
ACE	1,757		1,007		732		1,739		1,582		1,091		641		1,732
Long-Term Debt to Financing Trusts
Exelon	$	390	$	—	$	435	$	435	$	390	$	—	$	470	$	470
ComEd	205		—		228		228		205		—		248		248
PECO	184		—		207		207		184		—		222		222

__________

Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]

Recurring Fair Value Measurements

Exelon


	As of March 31, 2022						As of December 31, 2021
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Cash equivalents(a)	$	2,418	$	—	$	—	$	2,418	$	524	$	—	$	—	$	524
Rabbi trust investments
Cash equivalents	65		—		—		65		60		—		—		60
Mutual funds	55		—		—		55		60		—		—		60
Fixed income	—		9		—		9		—		10		—		10
Life insurance contracts	—		63		37		100		—		61		37		98
Rabbi trust investments subtotal	120		72		37		229		120		71		37		228
Total assets	2,538		72		37		2,647		644		71		37		752
Liabilities
Mark-to-market derivative liabilities	—		—		(144)		(144)		—		—		(219)		(219)
Deferred compensation obligation	—		(84)		—		(84)		—		(131)		—		(131)
Total liabilities	—		(84)		(144)		(228)		—		(131)		(219)		(350)
Total net assets (liabilities)	$	2,538	$	(12)	$	(107)	$	2,419	$	644	$	(60)	$	(182)	$	402

__________

ComEd, PECO, and BGE


	ComEd								PECO								BGE
As of March 31, 2022	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Cash equivalents(a)	$	537	$	—	$	—	$	537	$	9	$	—	$	—	$	9	$	—	$	—	$	—	$	—
Rabbi trust investments
Cash equivalents	—		—		—		—		1		—		—		1		—		—		—		—
Mutual funds	—		—		—		—		9		—		—		9		7		—		—		7
Life insurance contracts	—		—		—		—		—		17		—		17		—		—		—		—
Rabbi trust investments subtotal	—		—		—		—		10		17		—		27		7		—		—		7
Total assets	537		—		—		537		19		17		—		36		7		—		—		7
Liabilities
Mark-to-market derivative liabilities(b)	—		—		(144)		(144)		—		—		—		—		—		—		—		—
Deferred compensation obligation	—		(9)		—		(9)		—		(8)		—		(8)		—		(5)		—		(5)
Total liabilities	—		(9)		(144)		(153)		—		(8)		—		(8)		—		(5)		—		(5)
Total net assets (liabilities)	$	537	$	(9)	$	(144)	$	384	$	19	$	9	$	—	$	28	$	7	$	(5)	$	—	$	2


	ComEd								PECO								BGE
As of December 31, 2021	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Cash equivalents(a)	$	237	$	—	$	—	$	237	$	9	$	—	$	—	$	9	$	—	$	—	$	—	$	—
Rabbi trust investments
Mutual funds	—		—		—		—		11		—		—		11		14		—		—		14
Life insurance contracts	—		—		—		—		—		16		—		16		—		—		—		—
Rabbi trust investments subtotal	—		—		—		—		11		16		—		27		14		—		—		14
Total assets	237		—		—		237		20		16		—		36		14		—		—		14
Liabilities
Mark-to-market derivative liabilities(b)	—		—		(219)		(219)		—		—		—		—		—		—		—		—
Deferred compensation obligation	—		(10)		—		(10)		—		(9)		—		(9)		—		(7)		—		(7)
Total liabilities	—		(10)		(219)		(229)		—		(9)		—		(9)		—		(7)		—		(7)
Total net assets (liabilities)	$	237	$	(10)	$	(219)	$	8	$	20	$	7	$	—	$	27	$	14	$	(7)	$	—	$	7

__________

PHI, Pepco, DPL, and ACE



	As of March 31, 2022								As of December 31, 2021
PHI	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Cash equivalents(a)	$	599	$	—	$	—	$	599	$	110	$	—	$	—	$	110
Rabbi trust investments
Cash equivalents	61		—		—		61		59		—		—		59
Mutual funds	12		—		—		12		14		—		—		14
Fixed income	—		9		—		9		—		10		—		10
Life insurance contracts	—		24		36		60		—		27		35		62
Rabbi trust investments subtotal	73		33		36		142		73		37		35		145
Total assets	672		33		36		741		183		37		35		255
Liabilities
Deferred compensation obligation	—		(17)		—		(17)		—		(18)		—		(18)



Total liabilities	—		(17)		—		(17)		—		(18)		—		(18)
Total net assets	$	672	$	16	$	36	$	724	$	183	$	19	$	35	$	237


	Pepco								DPL								ACE
As of March 31, 2022	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Cash equivalents(a)	$	294	$	—	$	—	$	294	$	152	$	—	$	—	$	152	$	153	$	—	$	—	$	153




Rabbi trust investments
Cash equivalents	59		—		—		59		—		—		—		—		—		—		—		—

Life insurance contracts	—		24		36		60		—		—		—		—		—		—		—		—
Rabbi trust investments subtotal	59		24		36		119		—		—		—		—		—		—		—		—
Total assets	353		24		36		413		152		—		—		152		153		—		—		153
Liabilities
Deferred compensation obligation	—		(2)		—		(2)		—		—		—		—		—		—		—		—



Total liabilities	—		(2)		—		(2)		—		—		—		—		—		—		—		—
Total net assets	$	353	$	22	$	36	$	411	$	152	$	—	$	—	$	152	$	153	$	—	$	—	$	153


	Pepco								DPL								ACE
As of December 31, 2021	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Cash equivalents(a)	$	31	$	—	$	—	$	31	$	43	$	—	$	—	$	43	$	—	$	—	$	—	$	—
Rabbi trust investments
Cash equivalents	58		—		—		58		—		—		—		—		—		—		—		—


Life insurance contracts	—		27		35		62		—		—		—		—		—		—		—		—
Rabbi trust investments subtotal	58		27		35		120		—		—		—		—		—		—		—		—
Total assets	89		27		35		151		43		—		—		43		—		—		—		—
Liabilities
Deferred compensation obligation	—		(2)		—		(2)		—		—		—		—		—		—		—		—



Total liabilities	—		(2)		—		(2)		—		—		—		—		—		—		—		—
Total net assets	$	89	$	25	$	35	$	149	$	43	$	—	$	—	$	43	$	—	$	—	$	—	$	—

__________

Fair Value Reconciliation of Level 3 Assets and Liabilities Measured at Fair Value on a Recurring Basis

Reconciliation of Level 3 Assets and Liabilities

The following tables present the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis during the three months ended March 31, 2022 and 2021:


	Exelon		ComEd			PHI and Pepco
Three months ended March 31, 2022	Total		Mark-to-Market Derivatives			Life Insurance Contracts
Balance as of January 1, 2022	$	(182)	$	(219)		$	35
Total realized / unrealized gains
Included in net income(a)	1		—			1


Included in regulatory assets	75		75		(b)	—







Transfers out of Level 3	(1)		—			—
Balance as of March 31, 2022	$	(107)	$	(144)		$	36
The amount of total gains included in income attributed to the change in unrealized gains related to assets and liabilities as of March 31, 2022	$	1	$	—		$	1


	Exelon		ComEd			PHI and Pepco
Three Months Ended March 31, 2021	Total		Mark-to-Market Derivatives			Life Insurance Contracts
Balance as of January 1, 2021	$	(267)	$	(301)		$	34
Total realized / unrealized gains
Included in net income(a)	1		—			1


Included in regulatory assets	6		6		(b)	—








Balance as of March 31, 2021	$	(260)	$	(295)		$	35
The amount of total gains included in income attributed to the change in unrealized gain related to assets and liabilities as of March 31, 2021	$	1	$	—		$	1

__________

(a)Classified in Operating and maintenance expense in the Consolidated Statements of Operations and Comprehensive Income.

Fair Value Reconciliation of Level 3 Assets and Liabilities Measured at Fair Value on a Recurring Basis, Valuation Technique

Mark-to-Market Derivatives (Exelon and ComEd)

The table below discloses the significant inputs to the forward curve used to value mark-to-market derivatives.


Type of trade	Fair Value as of March 31, 2022		Fair Value as of December 31, 2021		Valuation Technique	Unobservable Input	2022 Range & Arithmetic Average				2021 Range & Arithmetic Average
Mark-to-market derivatives	$	(144)	$	(219)	Discounted Cash Flow	Forward heat rate(a)	8.90x	-	9.10x	9.00x	9x	-	10x	9.13x
						Marketability reserve	4%	-	5%	4.35%	3%	-	7%	4.77%
						Renewable factor	92%	-	120%	98%	92%	-	120%	97%

__________

(a)Quoted forward natural gas rates are utilized to project the forward power curve for the delivery of energy at specified future dates.

Commitments and Contingencies (Tables)

3 Months Ended

Mar. 31, 2022

Commitments and Contingencies Disclosure [Abstract]

PHI Merger Commitments

The following amounts represent total commitment costs that have been recorded since the acquisition date and the total remaining obligations for Exelon, PHI, Pepco, DPL, and ACE as of March 31, 2022:


Description	Exelon		PHI		Pepco		DPL		ACE
Total commitments	$	513	$	320	$	120	$	89	$	111
Remaining commitments(a)	65		55		46		6		3

__________

(a)Remaining commitments extend through 2026 and include rate credits, energy efficiency programs and delivery system modernization.

Commercial Commitments

The Registrants’ commercial commitments as of March 31, 2022, representing commitments potentially triggered by future events were as follows:


			Expiration within
	Total		2022		2023		2024		2025		2026		2027 and beyond
Exelon
Letters of credit	$	14	$	12	$	2	$	—	$	—	$	—	$	—
Surety bonds(a)	201		188		11		2		—		—		—
Financing trust guarantees	378		—		—		—		—		—		378
Guaranteed lease residual values(b)	30		1		3		6		5		5		10
Total commercial commitments	$	623	$	201	$	16	$	8	$	5	$	5	$	388

ComEd
Letters of credit	$	7	$	7	$	—	$	—	$	—	$	—	$	—
Surety bonds(a)	17		12		3		2		—		—		—
Financing trust guarantees	200		—		—		—		—		—		200
Total commercial commitments	$	224	$	19	$	3	$	2	$	—	$	—	$	200

PECO
Letters of credit	$	1	$	1	$	—	$	—	$	—	$	—	$	—
Surety bonds(a)	3		2		1		—		—		—		—
Financing trust guarantees	178		—		—		—		—		—		178
Total commercial commitments	$	182	$	3	$	1	$	—	$	—	$	—	$	178

BGE
Letters of credit	$	2	$	2	$	—	$	—	$	—	$	—	$	—
Surety bonds(a)	4		3		1		—		—		—		—
Total commercial commitments	$	6	$	5	$	1	$	—	$	—	$	—	$	—

PHI

Surety bonds(a)	$	94	$	91	$	3	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	30		1		3		6		5		5		10
Total commercial commitments	$	124	$	92	$	6	$	6	$	5	$	5	$	10

Pepco

Surety bonds(a)	$	84	$	84	$	—	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	10		—		1		2		2		2		3
Total commercial commitments	$	94	$	84	$	1	$	2	$	2	$	2	$	3

DPL

Surety bonds(a)	$	6	$	3	$	3	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	13		1		1		3		2		2		4
Total commercial commitments	$	19	$	4	$	4	$	3	$	2	$	2	$	4

ACE
Surety bonds(a)	$	4	$	4	$	—	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	7		—		1		1		1		1		3
Total commercial commitments	$	11	$	4	$	1	$	1	$	1	$	1	$	3

__________

(a)Surety bonds — Guarantees issued related to contract and commercial agreements, excluding bid bonds.

Accrued environmental liabilities


	March 31, 2022				December 31, 2021
	Total environmental investigation and remediation liabilities		Portion of total related to MGP investigation and remediation		Total environmental investigation and remediation liabilities		Portion of total related to MGP investigation and remediation
Exelon	$	354	$	305	$	352	$	303
ComEd	279		279		279		279
PECO	21		20		22		20
BGE	7		6		6		4
PHI	42		—		42		—
Pepco	40		—		40		—
DPL	1		—		1		—
ACE	1		—		1		—

Changes in Accumulated Other Comprehensive Income (Tables)

3 Months Ended

Mar. 31, 2022

Changes in Accumulated Other Comprehensive Income [Abstract]

Schedule of Changes in Accumulated Other Comprehensive Income (Loss)

The following tables present changes in Exelon's AOCI, net of tax, by component:


Three Months Ended March 31, 2022	Cash Flow Hedges		Pension and Non-Pension Postretirement Benefit Plan Items(a)		Foreign Currency Items		Total
Balance at December 31, 2021	$	(6)	$	(2,721)	$	(23)	$	(2,750)
Separation of Constellation	6		1,994		23		2,023

Amounts reclassified from AOCI	—		14		—		14
Net current-period OCI	—		14		—		14
Balance at March 31, 2022	$	—	$	(713)	$	—	$	(713)


Three Months Ended March 31, 2021	Losses on Cash Flow Hedges		Pension and Non-Pension Postretirement Benefit Plan Items(a)		Foreign Currency Items		Total
Balance at December 31, 2020	$	(5)	$	(3,372)	$	(23)	$	(3,400)
OCI before reclassifications	—		(2)		1		(1)
Amounts reclassified from AOCI	—		55		—		55
Net current-period OCI	—		53		1		54
Balance at March 31, 2021	$	(5)	$	(3,319)	$	(22)	$	(3,346)

______

Schedule of Income Taxes Allocated to Other Comprehensive Income (Loss) Components

The following table presents income tax benefit (expense) allocated to each component of Exelon's other comprehensive income (loss):


	Three Months Ended March 31,
		2022		2021
Pension and non-pension postretirement benefit plans:
Prior service benefit reclassified to periodic benefit cost		$	—	$	1
Actuarial loss reclassified to periodic benefit cost		(5)		(19)

Supplemental Financial Information (Tables)

3 Months Ended

Mar. 31, 2022

Supplemental Financial Information [Abstract]

Taxes Other Than Income Taxes

The following tables provide additional information about material items recorded in the Registrants' Consolidated Statements of Operations and Comprehensive Income:


	Taxes other than income taxes
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE










Three Months Ended March 31, 2022
Utility taxes(a)	$	221	$	78	$	38	$	27	$	78	$	70	$	7	$	1
Property	94		10		4		46		34		23		10		1
Payroll	37		7		4		4		7		2		1		1

Three Months Ended March 31, 2021
Utility taxes(a)	$	193	$	59	$	35	$	25	$	74	$	67	$	6	$	1
Property	86		8		4		42		32		21		10		1
Payroll	33		7		4		5		7		2		1		—

_________

Schedule of Other Nonoperating Income, by Component


	Other, net
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Three Months Ended March 31, 2022

AFUDC — Equity	$	36	$	8	$	7	$	6	$	15	$	11	$	2	$	2
Non-service net periodic benefit cost	17		—		—		—		—		—		—		—

Three Months Ended March 31, 2021

AFUDC — Equity	$	28	$	4	$	6	$	7	$	11	$	9	$	1	$	1
Non-service net periodic benefit cost	20		—		—		—		—		—		—		—

Cash Flow Supplemental Disclosures

The following tables provide additional information about material items recorded in the Registrants' Consolidated Statements of Cash Flows.


	Depreciation and amortization
	Exelon(a)		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Three Months Ended March 31, 2022
Property, plant, and equipment(b)	$	726	$	254	$	88	$	117	$	164	$	72	$	45	$	41
Amortization of regulatory assets(b)	179		67		4		54		54		36		12		6
Amortization of intangible assets, net(b)	6		—		—		—		—		—		—		—
Amortization of energy contract assets and liabilities(c)	3		—		—		—		—		—		—		—
Nuclear fuel(d)	66		—		—		—		—		—		—		—
ARO accretion(e)	44		—		—		—		—		—		—		—
Total depreciation, amortization, and accretion	$	1,024	$	321	$	92	$	171	$	218	$	108	$	57	$	47

Three Months Ended March 31, 2021
Property, plant, and equipment(b)	$	1,522	$	239	$	82	$	106	$	154	$	67	$	42	$	37
Amortization of regulatory assets(b)	160		53		4		46		56		35		11		10
Amortization of intangible assets, net(b)	15		—		—		—		—		—		—		—
Amortization of energy contract assets and liabilities(c)	4		—		—		—		—		—		—		—
Nuclear fuel(d)	276		—		—		—		—		—		—		—
ARO accretion(e)	127		—		—		—		—		—		—		—
Total depreciation, amortization, and accretion	$	2,104	$	292	$	86	$	152	$	210	$	102	$	53	$	47

__________

(a)Exelon's amounts include amounts related to Generation prior to the separation. See Note 2 — Discontinued Operations for additional information.

(b)Included in Depreciation and amortization in the Registrants' Consolidated Statements of Operations and Comprehensive Income.

(c)Included in Operating revenues or Purchased power and fuel expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income.

(d)Included in Purchased fuel expense in Exelon's Consolidated Statement of Operations and Comprehensive Income.

(e)Included in Operating and maintenance expense in Exelon's Consolidated Statement of Operations and Comprehensive Income.


	Other non-cash operating activities
	Exelon(a)		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Three Months Ended March 31, 2022
Pension and non-pension postretirement benefit costs	$	44	$	16	$	(2)	$	12	$	13	$	2	$	1	$	3
Allowance for credit losses	78		17		27		18		18		9		6		3
Other decommissioning-related activity	36		—		—		—		—		—		—		—
Energy-related options	60		—		—		—		—		—		—		—
True-up adjustments to decoupling mechanisms and formula rates(b)	(29)		(40)		(6)		12		5		7		1		(3)


Long-term incentive plan	25		—		—		—		—		—		—		—


Amortization of operating ROU asset	23		1		—		7		7		2		2		1


AFUDC — Equity	(36)		(8)		(7)		(6)		(15)		(11)		(2)		(2)

Three Months Ended March 31, 2021
Pension and non-pension postretirement benefit costs	$	95	$	32	$	2	$	14	$	12	$	2	$	1	$	3
Allowance for credit losses	85		13		24		4		10		5		4		1
Other decommissioning-related activity	(322)		—		—		—		—		—		—		—
Energy-related options	17		—		—		—		—		—		—		—
True-up adjustments to decoupling mechanisms and formula rates(b)	(129)		(54)		(10)		(18)		(46)		(26)		(9)		(11)


Long-term incentive plan	32		—		—		—		—		—		—		—


Amortization of operating ROU asset	37		—		—		7		7		1		3		1


AFUDC — Equity	(28)		(4)		(6)		(7)		(11)		(9)		(1)		(1)

__________

(a)Exelon's amounts include amounts related to Generation prior to the separation. See Note 2 — Discontinued Operations for additional information.


	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
March 31, 2022
Cash and cash equivalents	$	2,476	$	343	$	26	$	41	$	796	$	502	$	120	$	168
Restricted cash and cash equivalents	430		246		8		34		106		34		73		—
Restricted cash included in other long-term assets	92		92		—		—		—		—		—		—
Total cash, restricted cash, and cash equivalents	$	2,998	$	681	$	34	$	75	$	902	$	536	$	193	$	168

December 31, 2021
Cash and cash equivalents	$	672	$	131	$	36	$	51	$	136	$	34	$	28	$	29
Restricted cash and cash equivalents	321		210		8		4		77		34		43		—
Restricted cash included in other long-term assets	44		43		—		—		—		—		—		—
Cash, restricted cash, and cash equivalents from discontinued operations	582		—		—		—		—		—		—		—
Total cash, restricted cash, and cash equivalents	$	1,619	$	384	$	44	$	55	$	213	$	68	$	71	$	29

March 31, 2021
Cash and cash equivalents	$	1,908	$	86	$	48	$	21	$	558	$	134	$	64	$	353
Restricted cash and cash equivalents	374		270		7		1		37		33		—		4
Restricted cash included in other long-term assets	52		43		—		—		9		—		—		9
Total cash, restricted cash, and cash equivalents(a)	$	2,334	$	399	$	55	$	22	$	604	$	167	$	64	$	366

December 31, 2020
Cash and cash equivalents	$	663	$	83	$	19	$	144	$	111	$	30	$	15	$	17
Restricted cash and cash equivalents	438		279		7		1		39		35		—		3
Restricted cash included in other long-term assets	53		43		—		—		10		—		—		10
Cash, restricted cash, and cash equivalents - Held for Sale	12		—		—		—		—		—		—		—
Total cash, restricted cash, and cash equivalents(a)	$	1,166	$	405	$	26	$	145	$	160	$	65	$	15	$	30

__________

(a)Exelon's amounts include amounts related to Generation prior to the separation. See Note 2 — Discontinued Operations for additional information.

For additional information on restricted cash see Note 1 — Significant Accounting Policies of the Exelon 2021 Form 10-K.

Supplemental Balance Sheet Disclosures

The following table provides additional information about material items recorded in the Registrants' Consolidated Balance Sheets.


	Accrued expenses
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
March 31, 2022
Compensation-related accruals(a)	$	370	$	95	$	51	$	48	$	73	$	26	$	15	$	12
Taxes accrued	258		95		15		78		94		85		10		9
Interest accrued	346		66		36		39		77		37		21		17

December 31, 2021
Compensation-related accruals(a)	$	596	$	155	$	77	$	78	$	113	$	35	$	20	$	17
Taxes accrued	253		94		14		53		96		88		9		11
Interest accrued	297		116		41		44		52		28		8		11

__________

(a)Primarily includes accrued payroll, bonuses and other incentives, vacation, and benefits.

Related Party Transactions (Tables)

3 Months Ended

Mar. 31, 2022

Operating Revenues and Purchased Power and Fuel


	Three Months Ended March 31,
	2022		2021
ComEd(a)	$	59	$	85
PECO(b)	33		42
BGE(c)	18		72
PHI	51		100
Pepco(d)	39		75
DPL(e)	10		21
ACE(f)	2		4

__________

(a)ComEd had an ICC-approved RFP contract with Generation to provide a portion of ComEd’s electric supply requirements. ComEd also purchased RECs and ZECs from Generation.

(c)BGE received a portion of its energy requirements from Generation under its MDPSC-approved market-based SOS and gas commodity programs.

(d)Pepco received electric supply from Generation under contracts executed through Pepco's competitive procurement process approved by the MDPSC and DCPSC.

(e)DPL received a portion of its energy requirements from Generation under its MDPSC and DEPSC approved market-based SOS commodity programs.

(f)ACE received electric supply from Generation under contracts executed through ACE's competitive procurement process approved by the NJBPU.

BSC and PHISCO Service Companies

The following table presents the service company costs allocated to the Registrants:


		Operating and maintenance from affiliates					Capitalized costs
	Three Months Ended March 31,					Three Months Ended March 31,
		2022		2021			2022		2021
Exelon
BSC							$	205	$	114
PHISCO							19		17
ComEd
BSC		$	85	$	71		85		45
PECO
BSC		49		39			36		17
BGE
BSC		51		43			38		20
PHI
BSC		50		39			46		32
PHISCO							19		17
Pepco
BSC		29		22			17		13
PHISCO		29		30			8		7

DPL
BSC		18		14			14		10
PHISCO		24		25			6		5

ACE
BSC		15		12			15		8
PHISCO		21		22			5		5

Current Receivables From/Payables To Affiliates

The following tables present current receivables from affiliates and current payables to affiliates:

March 31, 2022


				Receivables from affiliates:
	Payables to affiliates:			ComEd			PECO			BGE			Pepco			DPL			ACE			BSC			PHISCO			Other			Total
ComEd					$	—		$	—		$	—		$	—		$	—		$	64		$	—		$	2		$	66
PECO		$	—					—			—			—			—			33			—			5			38
BGE		—			—						—			—			—			35			—			2			37
PHI		—			—			—			—			—			—			7			1			10			18
Pepco		—			—			—						—			—			19			15			—			34
DPL		—			—			—			—						—			3			12			—			15
ACE		—			—			—			—			—						12			11			—			23
Other		3			—			—			—			—			—			—			—						3
Total		$	3		$	—		$	—		$	—		$	—		$	—		$	173		$	39		$	19		$	234

December 31, 2021


				Receivables from affiliates:
	Payables to affiliates:			ComEd			PECO			BGE			Pepco			DPL			ACE			Generation			BSC			PHISCO			Other			Total
ComEd					$	—		$	—		$	—		$	—		$	—		41			$	71		$	—		$	9		$	121
PECO		$	—					—			—			—			—			30			36			—			4			70
BGE		—			—						—			—			—			4			41			—			3			48
PHI		—			1			—			—			—			1			—			5			—			9			16
Pepco		—			—			1						1			1			20			21			12			3			59
DPL		—			—			—			—						—			4			17			11			1			33
ACE		—			—			—			—			—						7			13			9			2			31
Generation		13			—			—			—			—			—						102			—			16			131
Other		3			—			—			—			—			—			11			—			—						14
Total		$	16		$	1		$	1		$	—		$	1		$	2		$	117		$	306		$	32		$	47		$	523

Long Term Debt to Financing Trusts

The following table presents Long-term debt to financing trusts:


	March 31, 2022						December 31, 2021
	Exelon		ComEd		PECO		Exelon		ComEd		PECO
ComEd Financing III	$	206	$	205	$	—	$	206	$	205	$	—
PECO Trust III	81		—		81		81		—		81
PECO Trust IV	103		—		103		103		—		103
Total	$	390	$	205	$	184	$	390	$	205	$	184

Significant Accounting Policies (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021	Jan. 01, 2021
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Retained earnings/Undistributed earnings (losses)	$ 4,028		$ 16,942
Deferred income taxes and unamortized investment tax credits	11,089		10,611
Net income (loss)	598	$ (264)
Atlantic City Electric Company [Member]
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Retained earnings/Undistributed earnings (losses)	(8)		(15)
Deferred income taxes and unamortized investment tax credits	692		682
Net income (loss)	26	14
Pepco Holdings LLC [Member]
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Retained earnings/Undistributed earnings (losses)	(182)		(210)
Deferred income taxes and unamortized investment tax credits	2,723		$ 2,675
Net income (loss)	130	128
Atlantic City Electric Company [Member] \| Atlantic City Electric Company [Member]
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Retained earnings/Undistributed earnings (losses)				$ 8
Regulatory Liabilities				11
Deferred income taxes and unamortized investment tax credits				$ 3
Net income (loss)		$ 1
Pepco Holdings LLC [Member] \| Pepco Holdings LLC [Member]
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Net income (loss)	$ 8

The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest.

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The cumulative amount of the reporting entity's undistributed earnings or deficit.

+ References + Details

Discontinued Operations and Disposal Groups (Details) - USD ($) $ in Millions	2 Months Ended	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2022	Feb. 01, 2022	Jan. 31, 2022
Discontinued Operations - Income Statement
Discontinued Operation, Intra-Entity Amounts, Discontinued Operation after Disposal, Expense	$ 56
Exelon Generation Co L L C [Member]
Discontinued Operations - Income Statement
Net assets			$ (11,573)
Discontinued Operation, Intra-Entity Amounts, Discontinued Operation after Disposal, Expense	9
Corporate, Non-Segment [Member]
Discontinued Operations - Income Statement
Common Stock, Shares, Issued			326,663,937
Separation Cash Payment				$ 1,750
Proceeds from Sale and Collection of Notes Receivable		$ 258
Corporate, Non-Segment [Member] \| ShortTermDebtSOFRplus0.75Jan2023
Discontinued Operations - Income Statement
Short-term Bank Loans and Notes Payable	1,150	1,150
Corporate, Non-Segment [Member] \| SMBCTermLoanJuly2023 \| Notes Payable to Banks [Member]
Discontinued Operations - Income Statement
Debt Instrument, Face Amount	300	300
Corporate, Non-Segment [Member] \| USBTermLoanJuly2023 \| Notes Payable to Banks [Member]
Discontinued Operations - Income Statement
Debt Instrument, Face Amount	300	300
Corporate, Non-Segment [Member] \| PNCTermLoanJuly2023 \| Notes Payable to Banks [Member]
Discontinued Operations - Income Statement
Debt Instrument, Face Amount	$ 250	$ 250

Discontinued Operations and Disposal Groups (Details) - Income Statement - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Discontinued Operations - Income Statement
Revenue from Related Parties	$ 6	$ 7
Operating and maintenance	1,178	1,083
Cost, Depreciation and Amortization	817	757
Taxes, Miscellaneous	354	317
Costs and Expenses	4,427	3,808
Other, net	137	58
Nonoperating Income (Expense)	(201)	(260)
Income taxes	218	39
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	117	(789)
Net income (loss) attributable to noncontrolling interests	1	25
Net Income (Loss) from Discontinued Operations Available to Common Shareholders, Basic	116	(814)
Total transaction and transition costs incurred related to the Separation	52	3
Total transaction costs relating to the Separation	19
Exelon Generation Co L L C [Member]
Discontinued Operations - Income Statement
Revenue from Contract with Customer, Including Assessed Tax	1,855	5,265
Revenue from Related Parties	161	294
Disposal Group, Including Discontinued Operation, Revenue	2,016	5,559
Purchased power and/or fuel	1,138	4,610
Operating and maintenance	371	904
Cost, Depreciation and Amortization	94	940
Taxes, Miscellaneous	44	121
Costs and Expenses	1,647	6,575
Gain (Loss) on Disposition of Assets	10	71
Disposal Group, Including Discontinued Operation, Operating Income (Loss)	379	(945)
Disposal Group, Including Discontinued Operation, Interest Expense	(20)	(68)
Other, net	(281)	167
Nonoperating Income (Expense)	(301)	99
Discontinued Operation, Income (Loss) from Discontinued Operation, before Income Tax	78	(846)
Income taxes	(40)	(58)
Income (Loss) from Equity Method Investments	(1)	(1)
Income (Loss) from Discontinued Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	117	(789)
Net income (loss) attributable to noncontrolling interests	1	25
Net Income (Loss) from Discontinued Operations Available to Common Shareholders, Basic	116	(814)
Total transition costs relating to the Separation	2	1
Total transaction costs relating to the Separation	$ 50	$ 2

Discontinued Operations and Disposal Groups (Details) - Balance Sheet - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021	Mar. 31, 2021	Dec. 31, 2020
Discontinued Operations - Income Statement
Restricted cash	$ 430	$ 321	$ 374	$ 438
Customer accounts receivable	2,365	2,189
Accounts Receivable, Allowance for Credit Loss, Current	(389)	(320)
Other accounts receivable	1,148	1,068
Allowance for Credit Loss, Receivable, Other, Current	(81)	(72)
Other Receivables, Net, Current	1,067	996
Fossil fuel and emission allowances	39	105
Materials and supplies inventory, net	473	476
Current assets of discontinued operations	0	7,835
Accumulated depreciation and amortization	14,878	14,430
Investments	244	250
Other Assets, Noncurrent	1,045	885
Property, plant, and equipment, deferred debits, and other assets of discontinued operations	0	38,509
Assets	92,698	133,013
Short-term Debt	1,900	1,248
Long-term Debt and Lease Obligation, Current	2,154	2,153
Mark-to-market derivative liabilities (current liabilities)	0	18
Current liabilities of discontinued operations	0	7,940
Long-term Debt, Excluding Current Maturities	35,008	30,749
Deferred income taxes and unamortized investment tax credits	11,089	10,611
Asset retirement obligations, noncurrent	273	271
Derivative Liability, Noncurrent	144	201
Other	2,187	1,573
Long-term debt, deferred credits, and other liabilities of discontinued operations	0	25,676
Liabilities	$ 69,207	98,218
Exelon Generation Co L L C [Member]
Discontinued Operations - Income Statement
Disposal Group, Including Discontinued Operation, Cash and Cash Equivalents		510
Restricted cash		72
Customer accounts receivable		1,724
Accounts Receivable, Allowance for Credit Loss, Current		(55)
Disposal Group, Including Discontinued Operation, Accounts, Notes and Loans Receivable, Net		1,669
Other accounts receivable		596
Allowance for Credit Loss, Receivable, Other, Current		(4)
Other Receivables, Net, Current		592
Mark-to-market derivative assets, current		2,169
Fossil fuel and emission allowances		284
Materials and supplies inventory, net		1,004
Renewable energy credits, current		529
Disposal Group, Including Discontinued Operations, Assets, Current - Assets held for sale		13
Disposal Group, Including Discontinued Operation, Other Assets, Current		993
Current assets of discontinued operations		7,835
Accumulated depreciation and amortization		15,888
Disposal Group, Including Discontinued Operation, Property, Plant and Equipment, Noncurrent		19,661
Nuclear decommissioning trust funds		15,938
Investments		193
Derivative Asset, Noncurrent		949
Other Assets, Noncurrent		1,768
Property, plant, and equipment, deferred debits, and other assets of discontinued operations		38,509
Assets		46,344
Short-term Debt		2,082
Long-term Debt and Lease Obligation, Current		1,220
Disposal Group, Including Discontinued Operation, Accounts Payable, Current		1,757
Disposal Group, Including Discontinued Operation, Accrued Liabilities, Current		818
Mark-to-market derivative liabilities (current liabilities)		981
Energy Marketing Accounts Payable		779
Disposal Group, Including Discontinued Operations, Assets, Current - Liabilities held for sale		3
Disposal Group, Including Discontinued Operation, Other Liabilities, Current		300
Current liabilities of discontinued operations		7,940
Long-term Debt, Excluding Current Maturities		4,575
Deferred income taxes and unamortized investment tax credits		3,583
Asset retirement obligations, noncurrent		12,819
Disposal Group, Including Discontinued Operation, Pension Plan Benefit Obligation, Noncurrent		939
Disposal Group, Including Discontinued Operation, Postretirement Plan Benefit Obligation, Noncurrent		876
Spent Nuclear Fuel Obligation, Noncurrent		1,210
Derivative Liability, Noncurrent		513
Other		1,161
Long-term debt, deferred credits, and other liabilities of discontinued operations		25,676
Liabilities		$ 33,616

Discontinued Operations and Disposal Groups (Details) - Cash Flows - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Discontinued Operations - Income Statement
Depreciation, Amortization and Accretion, Net	$ 1,024	$ 2,104
Gain (Loss) on Sale of Assets and Asset Impairment Charges	(10)	(71)
Deferred income taxes and amortization of investment tax credits	110	(142)
Net fair value changes related to derivatives	(59)	(178)
Net realized and unrealized (gains) losses on NDT funds	205	(118)
Net unrealized (gains) losses on equity investments	16	23
Other non-cash operating activities	(232)	170
Payments to Acquire Property, Plant, and Equipment	(1,922)	(2,140)
Collection of deferred purchase price	169	1,574
Decrease in capital expenditures not paid	(322)	(324)
Increase in deferred purchase price	348	1,339
Increase in PPE related to ARO update	(335)	2
Exelon Generation Co L L C [Member]
Discontinued Operations - Income Statement
Depreciation, Amortization and Accretion, Net	207	1,346
Gain (Loss) on Sale of Assets and Asset Impairment Charges	9	(71)
Deferred income taxes and amortization of investment tax credits	(143)	(234)
Net fair value changes related to derivatives	(59)	(178)
Net realized and unrealized (gains) losses on NDT funds	205	(118)
Net unrealized (gains) losses on equity investments	16	23
Other non-cash operating activities	36	(332)
Payments to Acquire Property, Plant, and Equipment	(227)	(394)
Collection of deferred purchase price	169	1,574
Decrease in capital expenditures not paid	(128)	(37)
Increase in deferred purchase price	348	1,339
Increase in PPE related to ARO update	$ 335	$ 0

Mergers, Acquisitions, and Dispositions - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Business Dispositions
Gain (Loss) on Sale of Assets and Asset Impairment Charges	$ 10	$ 71

Regulatory Matters - Narrative (Details) $ in Millions	3 Months Ended
Regulatory Matters - Narrative (Details) $ in Millions	Mar. 31, 2022 USD ($)
PECO Energy Co [Member]
Regulatory Matters Additional Narrative Information [Line Items]
Increase (Decrease) in Regulatory Assets	$ 66
Increase (Decrease) in Regulatory Liabilities	(112)
PECO Energy Co [Member] \| Nuclear Decommissioning [Member]
Regulatory Matters Additional Narrative Information [Line Items]
Increase (Decrease) in Regulatory Liabilities	(111)
PECO Energy Co [Member] \| Deferred Income Tax Charge [Member]
Regulatory Matters Additional Narrative Information [Line Items]
Increase (Decrease) in Regulatory Assets	60
Baltimore Gas and Electric Company [Member]
Regulatory Matters Additional Narrative Information [Line Items]
Increase (Decrease) in Regulatory Assets	(50)
Increase (Decrease) in Regulatory Liabilities	(53)
Baltimore Gas and Electric Company [Member] \| Deferred Income Tax Charge [Member]
Regulatory Matters Additional Narrative Information [Line Items]
Increase (Decrease) in Regulatory Liabilities	(65)
Baltimore Gas and Electric Company [Member] \| Electric Energy and Natural Gas Cost [Member]
Regulatory Matters Additional Narrative Information [Line Items]
Increase (Decrease) in Regulatory Assets	(19)
Baltimore Gas and Electric Company [Member] \| Energy Efficiency and Demand Response Programs
Regulatory Matters Additional Narrative Information [Line Items]
Increase (Decrease) in Regulatory Assets	(16)
Atlantic City Electric Company [Member]
Regulatory Matters Additional Narrative Information [Line Items]
Contract Termination Liability	203
Increase (Decrease) in Regulatory Assets	205
Increase (Decrease) in Regulatory Liabilities	(19)
Atlantic City Electric Company [Member] \| Other Current Liabilities
Regulatory Matters Additional Narrative Information [Line Items]
Contract Termination Liability	85
Atlantic City Electric Company [Member] \| Other Noncurrent Liabilities
Regulatory Matters Additional Narrative Information [Line Items]
Contract Termination Liability	118
Atlantic City Electric Company [Member] \| Deferred Income Tax Charge [Member]
Regulatory Matters Additional Narrative Information [Line Items]
Increase (Decrease) in Regulatory Liabilities	(9)
Atlantic City Electric Company [Member] \| Electric Transmission Formula Rate Annual Reconciliations [Member]
Regulatory Matters Additional Narrative Information [Line Items]
Increase (Decrease) in Regulatory Liabilities	$ (5)

Regulatory Matters - Schedule of Pending Rate Cases (Details) - USD ($) $ in Millions	Apr. 15, 2022	Mar. 31, 2022	Feb. 28, 2022
Commonwealth Edison Co [Member] \| Illinois 2022 Electric Distribution Base Rate Case
Regulatory Matters Pending Rate Cases [Line Items]
Requested Revenue Requirement Increase (Decrease)	$ 199
Commonwealth Edison Co [Member] \| Illinois 2022 Electric Distribution Base Rate Case \| 2023
Regulatory Matters Pending Rate Cases [Line Items]
Requested Return on Equity, Percentage	7.85%
Public Utilities, Requested Rate Increase (Decrease), Initial Revenue Requirement, Amount	$ 144
Requested Return on Distribution Rate Base, Percentage	5.94%
Basis points for ComEd's Revenue Requirement	580
Commonwealth Edison Co [Member] \| Illinois 2022 Electric Distribution Base Rate Case \| 2021
Regulatory Matters Pending Rate Cases [Line Items]
Requested Return on Equity, Percentage	7.78%
Public Utilities Requested Rate Increase (Decrease), Prior Year Annual Reconciliation	$ 55
Requested Return on Distribution Rate Base, Percentage	5.91%
Basis points for ComEd's Revenue Requirement	580
Commonwealth Edison Co [Member] \| Illinois 2022 Electric Distribution Base Rate Case \| Performance Metrics Penalty \| 2021
Regulatory Matters Pending Rate Cases [Line Items]
Basis points for ComEd's Revenue Requirement	7
PECO Energy Co [Member] \| Pennsylvania 2022 Natural Gas Distribution Base Rate Case
Regulatory Matters Pending Rate Cases [Line Items]
Requested Revenue Requirement Increase (Decrease)		$ 82
Requested Return on Equity, Percentage		10.95%
Delmarva Power and Light Company [Member] \| Delaware 2022 Natural Gas Distribution Base Rate Case
Regulatory Matters Pending Rate Cases [Line Items]
Requested Revenue Requirement Increase (Decrease)			$ 15
Requested Return on Equity, Percentage			10.30%

Regulatory Matters - Annual Electric Transmission Fillings (Details) - USD ($) $ in Millions	Apr. 29, 2022	Apr. 27, 2022
Commonwealth Edison Co [Member] \| 2022 Transmission Formula Rate Annual Update [Domain]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 24
Annual Reconciliation Increase	(24)
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount	$ 0
Public Utilities, Approved Equity Capital Structure, Percentage	8.11%
Public Utilities, Approved Return on Equity, Percentage	11.50%
Cap on Equity Component of Rate of Return on Common Equity in Federal Energy Regulatory Committee Complaint	55.00%
Basis points for Transmission Formula Rate	50
Baltimore Gas and Electric Company [Member] \| 2022 Transmission Formula Rate Annual Update [Domain]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount		$ 25
Annual Reconciliation Increase		(4)
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount		$ 16
Public Utilities, Approved Equity Capital Structure, Percentage		7.30%
Public Utilities, Approved Return on Equity, Percentage		10.50%
Basis points for Transmission Formula Rate		50
Baltimore Gas and Electric Company [Member] \| 2022 Transmission Formula Rate Revenue Reduction
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount		$ 5

Regulatory Matters - Capitalized Ratemaking Amount Not Recognized (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes	$ 49	$ 43
Commonwealth Edison Co [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes	2	1
PECO Energy Co [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes	0	0
Baltimore Gas and Electric Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes	34	37
Pepco Holdings LLC [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes	13	5
Potomac Electric Power Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes	11	3
Delmarva Power and Light Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes	2	2
Atlantic City Electric Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes	$ 0	$ 0

Segment Information - Narrative (Details)	3 Months Ended
Segment Information - Narrative (Details)	Mar. 31, 2022 Reportable_segment
Segment Reporting Information [Line Items]
Number of reportable segments	6
Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Number of reportable segments	3

Segment Information - Reconciliation to Consolidated Financial Statements (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
Segment Reporting Information [Line Items]
Revenues	$ 5,327	$ 4,632
Revenue from Related Parties	6	7
Depreciation and Amortization	817	757
Operating Expenses	4,427	3,808
Interest expense, net	338	318
Income (Loss) before income taxes	699	564
Income taxes	218	39
Net income (loss)	598	(264)
Capital expenditures	1,922	2,140
Assets	92,698		$ 133,013
Income (Loss) from Continuing Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	481	525
Other Segments
Segment Reporting Information [Line Items]
Assets			86,677
Continuing Operations
Segment Reporting Information [Line Items]
Capital expenditures	1,695	1,746
Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenues	1,404	1,244
Revenue from Related Parties	3	3
Income (Loss) before income taxes	137	136
Income taxes	7	8
Net income (loss)	130	128
Capital expenditures	409	456
Assets	25,636		24,744
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues	(588)	(501)
Revenue from Related Parties	(587)	(497)
Depreciation and Amortization	0	0
Operating Expenses	(531)	(339)
Interest expense, net	0	0
Income (Loss) before income taxes	(43)	(149)
Income taxes	(10)	(12)
Capital expenditures	0	0
Assets	(4,156)		(8,319)
Income (Loss) from Continuing Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	(33)	(137)
Intersegment Eliminations [Member] \| Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenues	(97)	(96)
Revenue from Related Parties	(97)	(96)
Depreciation and Amortization	0	0
Operating Expenses	(97)	(96)
Interest expense, net	0	0
Income (Loss) before income taxes	0	0
Income taxes	0	0
Net income (loss)	0	0
Capital expenditures	0	0
Assets	(44)		(60)
Commonwealth Edison Co [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenues	1,734	1,535
Depreciation and Amortization	321	292
Operating Expenses	1,406	1,210
Interest expense, net	100	96
Income (Loss) before income taxes	240	236
Income taxes	52	39
Capital expenditures	617	613
Assets	37,013		36,470
Income (Loss) from Continuing Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	188	197
Commonwealth Edison Co [Member] \| Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties	6	6
PECO Energy Co [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenues	1,047	889
Depreciation and Amortization	92	86
Operating Expenses	793	679
Interest expense, net	41	38
Income (Loss) before income taxes	220	177
Income taxes	14	10
Capital expenditures	344	295
Assets	14,113		13,824
Income (Loss) from Continuing Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	206	167
PECO Energy Co [Member] \| Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties	1	2
Baltimore Gas and Electric Company [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenues	1,154	974
Depreciation and Amortization	171	152
Operating Expenses	919	752
Interest expense, net	35	34
Income (Loss) before income taxes	207	196
Income taxes	9	(13)
Capital expenditures	303	336
Assets	12,509		12,324
Income (Loss) from Continuing Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	198	209
Baltimore Gas and Electric Company [Member] \| Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties	7	6
Pepco Holdings LLC [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenues	1,404	1,244
Depreciation and Amortization	218	210
Operating Expenses	1,215	1,058
Interest expense, net	69	67
Income (Loss) before income taxes	137	136
Income taxes	7	8
Net income (loss)	130	128
Capital expenditures	409	456
Assets	25,636		24,744
Income (Loss) from Continuing Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	130	128
Pepco Holdings LLC [Member] \| Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties	3	3
Potomac Electric Power Company [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenues	614	553
Depreciation and Amortization	108	102
Operating Expenses	547	466
Interest expense, net	36	34
Income (Loss) before income taxes	44	65
Income taxes	(2)	6
Net income (loss)	46	59
Capital expenditures	218	220
Assets	10,458		9,903
Potomac Electric Power Company [Member] \| Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties	1	1
Delmarva Power and Light Company [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenues	431	382
Depreciation and Amortization	57	53
Operating Expenses	357	309
Interest expense, net	16	15
Income (Loss) before income taxes	60	61
Income taxes	4	5
Net income (loss)	56	56
Capital expenditures	103	112
Assets	5,573		5,412
Delmarva Power and Light Company [Member] \| Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties	1	2
Atlantic City Electric Company [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenues	349	310
Depreciation and Amortization	47	47
Operating Expenses	311	282
Interest expense, net	14	15
Income (Loss) before income taxes	27	14
Income taxes	1	0
Net income (loss)	26	14
Capital expenditures	87	123
Assets	4,929		4,556
Atlantic City Electric Company [Member] \| Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties	1	1
Corporate and Other [Member] \| Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Revenues	576	491
Depreciation and Amortization	15	17
Operating Expenses	625	448
Interest expense, net	93	83
Income (Loss) before income taxes	(62)	(32)
Income taxes	146	7
Capital expenditures	22	46
Assets	7,583		7,634
Income (Loss) from Continuing Operations, Net of Tax, Including Portion Attributable to Noncontrolling Interest	(208)	(39)
Corporate and Other [Member] \| Corporate, Non-Segment [Member] \| Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenues	107	95
Depreciation and Amortization	6	8
Operating Expenses	97	97
Interest expense, net	3	3
Income (Loss) before income taxes	6	(4)
Income taxes	4	(3)
Net income (loss)	2	(1)
Capital expenditures	1	1
Assets	4,720		$ 4,933
Corporate and Other [Member] \| Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties	576	487
Corporate and Other [Member] \| Intersegment Eliminations [Member] \| Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties	97	95
Rate-regulated electric revenues [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	4,522	3,991
Rate-regulated electric revenues [Member] \| Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	1,323	1,124
Rate-regulated electric revenues [Member] \| Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	(7)	(7)
Rate-regulated electric revenues [Member] \| Intersegment Eliminations [Member] \| Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	7	(4)
Rate-regulated electric revenues [Member] \| Commonwealth Edison Co [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	1,734	1,535
Rate-regulated electric revenues [Member] \| PECO Energy Co [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	741	661
Rate-regulated electric revenues [Member] \| Baltimore Gas and Electric Company [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	736	632
Rate-regulated electric revenues [Member] \| Pepco Holdings LLC [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	1,318	1,170
Rate-regulated electric revenues [Member] \| Potomac Electric Power Company [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	614	553
Rate-regulated electric revenues [Member] \| Delmarva Power and Light Company [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	348	311
Rate-regulated electric revenues [Member] \| Atlantic City Electric Company [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	349	310
Rate-regulated electric revenues [Member] \| Corporate and Other [Member] \| Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated electric revenues [Member] \| Corporate and Other [Member] \| Corporate, Non-Segment [Member] \| Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	805	641
Rate-regulated natural gas revenues [Member] \| Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	83	71
Rate-regulated natural gas revenues [Member] \| Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	(2)	0
Rate-regulated natural gas revenues [Member] \| Intersegment Eliminations [Member] \| Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] \| Commonwealth Edison Co [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] \| PECO Energy Co [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	306	228
Rate-regulated natural gas revenues [Member] \| Baltimore Gas and Electric Company [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	418	342
Rate-regulated natural gas revenues [Member] \| Pepco Holdings LLC [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	83	71
Rate-regulated natural gas revenues [Member] \| Potomac Electric Power Company [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] \| Delmarva Power and Light Company [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	83	71
Rate-regulated natural gas revenues [Member] \| Atlantic City Electric Company [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] \| Corporate and Other [Member] \| Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] \| Corporate and Other [Member] \| Corporate, Non-Segment [Member] \| Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Shared service and other revenues [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Shared service and other revenues [Member] \| Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	(579)	(494)
Shared service and other revenues [Member] \| Intersegment Eliminations [Member] \| Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	(104)	(92)
Shared service and other revenues [Member] \| Commonwealth Edison Co [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Shared service and other revenues [Member] \| PECO Energy Co [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Shared service and other revenues [Member] \| Baltimore Gas and Electric Company [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Shared service and other revenues [Member] \| Pepco Holdings LLC [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	3	3
Shared service and other revenues [Member] \| Potomac Electric Power Company [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Shared service and other revenues [Member] \| Delmarva Power and Light Company [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Shared service and other revenues [Member] \| Atlantic City Electric Company [Member] \| Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Shared service and other revenues [Member] \| Corporate and Other [Member] \| Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	576	491
Shared service and other revenues [Member] \| Corporate and Other [Member] \| Corporate, Non-Segment [Member] \| Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	$ 107	$ 95

Accounts Receivable - Allowance for Credit Losses Rollforward (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Accounts, Notes, Loans and Financing Receivable [Line Items]
Current period provision for expected credit losses	$ (78)	$ (85)
Commonwealth Edison Co [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Current period provision for expected credit losses	(17)	(13)
PECO Energy Co [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Current period provision for expected credit losses	(27)	(24)
Baltimore Gas and Electric Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Current period provision for expected credit losses	(18)	(4)
Pepco Holdings LLC [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Current period provision for expected credit losses	(18)	(10)
Potomac Electric Power Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Current period provision for expected credit losses	(9)	(5)
Delmarva Power and Light Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Current period provision for expected credit losses	(6)	(4)
Atlantic City Electric Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Current period provision for expected credit losses	(3)	(1)
Customer accounts receivable
Accounts, Notes, Loans and Financing Receivable [Line Items]
Beginning balance	320	334
Current period provision for expected credit losses	110	70
Writeoffs, net of recoveries	41	27
Ending balance	389	377
Customer accounts receivable \| Commonwealth Edison Co [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Beginning balance	73	97
Current period provision for expected credit losses	26	21
Writeoffs, net of recoveries	7	15
Ending balance	92	103
Customer accounts receivable \| PECO Energy Co [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Beginning balance	105	116
Current period provision for expected credit losses	31	20
Writeoffs, net of recoveries	11	6
Ending balance	125	130
Customer accounts receivable \| Baltimore Gas and Electric Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Beginning balance	38	35
Current period provision for expected credit losses	26	9
Writeoffs, net of recoveries	5	1
Ending balance	59	43
Customer accounts receivable \| Pepco Holdings LLC [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Beginning balance	104	86
Current period provision for expected credit losses	27	20
Writeoffs, net of recoveries	18	5
Ending balance	113	101
Customer accounts receivable \| Potomac Electric Power Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Beginning balance	37	32
Current period provision for expected credit losses	11	11
Writeoffs, net of recoveries	8	2
Ending balance	40	41
Customer accounts receivable \| Delmarva Power and Light Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Beginning balance	18	22
Current period provision for expected credit losses	7	6
Writeoffs, net of recoveries	1	3
Ending balance	24	25
Customer accounts receivable \| Atlantic City Electric Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Beginning balance	49	32
Current period provision for expected credit losses	9	3
Writeoffs, net of recoveries	9	0
Ending balance	49	35
Other receivables
Accounts, Notes, Loans and Financing Receivable [Line Items]
Beginning balance	72	71
Current period provision for expected credit losses	14	10
Writeoffs, net of recoveries	5	2
Ending balance	81	79
Other receivables \| Commonwealth Edison Co [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Beginning balance	17	21
Current period provision for expected credit losses	4	1
Writeoffs, net of recoveries	1	0
Ending balance	20	22
Other receivables \| PECO Energy Co [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Beginning balance	7	8
Current period provision for expected credit losses	3	4
Writeoffs, net of recoveries	1	1
Ending balance	9	11
Other receivables \| Baltimore Gas and Electric Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Beginning balance	9	9
Current period provision for expected credit losses	3	1
Writeoffs, net of recoveries	1	1
Ending balance	11	9
Other receivables \| Pepco Holdings LLC [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Beginning balance	39	33
Current period provision for expected credit losses	4	4
Writeoffs, net of recoveries	2	0
Ending balance	41	37
Other receivables \| Potomac Electric Power Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Beginning balance	16	13
Current period provision for expected credit losses	2	2
Writeoffs, net of recoveries	0	0
Ending balance	18	15
Other receivables \| Delmarva Power and Light Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Beginning balance	8	9
Current period provision for expected credit losses	1	1
Writeoffs, net of recoveries	0	0
Ending balance	9	10
Other receivables \| Atlantic City Electric Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Beginning balance	15	11
Current period provision for expected credit losses	1	1
Writeoffs, net of recoveries	2	0
Ending balance	$ 14	$ 12

Accounts Receivable - Unbilled Customer Revenue (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled customer revenue	$ 629	$ 747
Commonwealth Edison Co [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled customer revenue	189	240
PECO Energy Co [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled customer revenue	127	161
Baltimore Gas and Electric Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled customer revenue	139	171
Pepco Holdings LLC [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled customer revenue	174	175
Potomac Electric Power Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled customer revenue	89	82
Delmarva Power and Light Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled customer revenue	50	53
Atlantic City Electric Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled customer revenue	$ 35	$ 40

Accounts Receivable - Purchases and Sales of Accounts Receivable (Detail) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Purchase	$ 1,044	$ 1,023
Commonwealth Edison Co [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Purchase	248	266
PECO Energy Co [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Purchase	292	290
Baltimore Gas and Electric Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Purchase	222	199
Pepco Holdings LLC [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Purchase	282	268
Potomac Electric Power Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Purchase	174	166
Delmarva Power and Light Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Purchase	57	56
Atlantic City Electric Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Purchase	51	46
Exelon Generation Co LLC Affiliate [Member] \| Baltimore Gas and Electric Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Related Parties, Purchase	$ 4	$ 12

Early Plant Retirements - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Property, Plant and Equipment [Line Items]
Cost, Depreciation and Amortization	$ 817	$ 757

Early Plant Retirements - Implications of Potential Early Plant Retirement on Balance Sheet (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Implications of Potential Early Plant Retirement [Line Items]
Materials and supplies inventory, net	$ 473	$ 476
Property, plant and equipment, net	$ 65,465	$ 64,558

Nuclear Decommissioning - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Nuclear Decommissioning Additional Narrative Information [Line Items]
Increase in PPE related to ARO update	$ (335)	$ 2

Nuclear Decommissioning - Rollforward of Nuclear Decommissioning ARO (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Accretion expense	$ 44	$ 127

Asset Impairments - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Property, Plant and Equipment [Line Items]
Impairment of Long-Lived Assets Held-for-use	$ 0	$ 1
Net income (loss) attributable to noncontrolling interests	1	25
Deferred income taxes and amortization of investment tax credits	$ 110	$ (142)

Income Taxes - Narrative (Details) $ in Millions	3 Months Ended
Income Taxes - Narrative (Details) $ in Millions	Mar. 31, 2022 USD ($)
Income Tax Additional Narrative Information [Line Items]
Income tax expense related to separation	$ 148
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Amount	67
Valuation Allowance, Deferred Tax Asset, Increase (Decrease), Amount	40
Income Tax Credits and Adjustments	15
Income Taxes Receivable, Current	55
Notes Payable, Current	11
Notes Payable, Noncurrent	484
State and Local Jurisdiction [Member] \| Atlantic City Electric Company [Member]
Income Tax Additional Narrative Information [Line Items]
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit	14
Federal and State
Income Tax Additional Narrative Information [Line Items]
Income Tax Credits and Adjustments	17
Total transaction costs taxes relating to the Separation	$ 24

Income Taxes - Reconciliation to Effective Tax Rate (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal statutory rate	21.00%	21.00%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	21.10%	2.80%
Plant basis differences	(3.60%)	(3.40%)
Excess deferred tax amortization	(11.50%)	(12.00%)
Amortization of investment tax credit, including deferred taxes on basis difference	(0.10%)	(0.10%)
Effective Income Tax Rate Reconciliation, Tax Credit, Other, Percent	1.70%	(0.30%)
Other	2.60%	(1.10%)
Effective income tax rate	31.20%	6.90%
Effective Income Tax Rate Reconciliation, State and Local Income Taxes, Amount	$ 67
Valuation Allowance, Deferred Tax Asset, Increase (Decrease), Amount	40
Income Tax Credits and Adjustments	15
Total transaction costs relating to the Separation	$ 19
Commonwealth Edison Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal statutory rate	21.00%	21.00%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	8.00%	6.80%
Plant basis differences	(0.60%)	(0.60%)
Excess deferred tax amortization	(6.30%)	(6.90%)
Amortization of investment tax credit, including deferred taxes on basis difference	(0.10%)	(0.10%)
Effective Income Tax Rate Reconciliation, Tax Credit, Other, Percent	(0.30%)	(0.20%)
Other	0.00%	(3.50%)
Effective income tax rate	21.70%	16.50%
PECO Energy Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal statutory rate	21.00%	21.00%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	(0.10%)	(1.60%)
Plant basis differences	(11.30%)	(10.50%)
Excess deferred tax amortization	(3.20%)	(3.20%)
Amortization of investment tax credit, including deferred taxes on basis difference	0.00%	0.00%
Effective Income Tax Rate Reconciliation, Tax Credit, Other, Percent	0.00%	0.00%
Other	0.00%	(0.10%)
Effective income tax rate	6.40%	5.60%
Baltimore Gas and Electric Company [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal statutory rate	21.00%	21.00%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	2.40%	(10.10%)
Plant basis differences	(0.90%)	(1.40%)
Excess deferred tax amortization	(17.60%)	(15.50%)
Amortization of investment tax credit, including deferred taxes on basis difference	(0.10%)	(0.10%)
Effective Income Tax Rate Reconciliation, Tax Credit, Other, Percent	(0.40%)	(0.40%)
Other	(0.10%)	(0.10%)
Effective income tax rate	4.30%	(6.60%)
Pepco Holdings LLC [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal statutory rate	21.00%	21.00%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	3.70%	6.10%
Plant basis differences	(1.60%)	(1.50%)
Excess deferred tax amortization	(17.70%)	(19.30%)
Amortization of investment tax credit, including deferred taxes on basis difference	(0.10%)	(0.10%)
Effective Income Tax Rate Reconciliation, Tax Credit, Other, Percent	(0.40%)	(0.20%)
Other	0.20%	(0.10%)
Effective income tax rate	5.10%	5.90%
Potomac Electric Power Company [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal statutory rate	21.00%	21.00%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	(4.50%)	5.50%
Plant basis differences	(2.60%)	(2.10%)
Excess deferred tax amortization	(17.40%)	(15.10%)
Amortization of investment tax credit, including deferred taxes on basis difference	0.00%	0.00%
Effective Income Tax Rate Reconciliation, Tax Credit, Other, Percent	(0.40%)	(0.20%)
Other	(0.60%)	0.10%
Effective income tax rate	(4.50%)	9.20%
Delmarva Power and Light Company [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal statutory rate	21.00%	21.00%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	6.20%	6.40%
Plant basis differences	(0.70%)	(0.70%)
Excess deferred tax amortization	(19.40%)	(18.50%)
Amortization of investment tax credit, including deferred taxes on basis difference	(0.20%)	(0.20%)
Effective Income Tax Rate Reconciliation, Tax Credit, Other, Percent	(0.30%)	(0.10%)
Other	0.10%	0.30%
Effective income tax rate	6.70%	8.20%
Atlantic City Electric Company [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal statutory rate	21.00%	21.00%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	6.80%	6.90%
Plant basis differences	(1.30%)	(0.90%)
Excess deferred tax amortization	(22.20%)	(28.70%)
Amortization of investment tax credit, including deferred taxes on basis difference	(0.20%)	(0.20%)
Effective Income Tax Rate Reconciliation, Tax Credit, Other, Percent	(0.30%)	(0.30%)
Other	(0.10%)	2.20%
Effective income tax rate	3.70%	0.00%

Income Taxes - Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Income Tax Contingency [Line Items]
Unrecognized Tax Benefits	$ 146	$ 143
Income Taxes Receivable, Noncurrent	50
Pepco Holdings LLC [Member]
Income Tax Contingency [Line Items]
Unrecognized Tax Benefits	56	56
Atlantic City Electric Company [Member]
Income Tax Contingency [Line Items]
Unrecognized Tax Benefits	$ 16	$ 16

Retirement Benefits - Narrative (Details) - USD ($) $ in Millions	2 Months Ended	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2022	Feb. 01, 2022
Defined Benefit Plan Disclosure [Line Items]
Increase (Decrease) in Obligation, Pension Benefits	$ (921)	$ (24)
Increase (Decrease) in Obligation, Other Postretirement Benefits	(893)	5
Accumulated Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), after Tax	5	5	$ (1,994)
Defined Benefit Plan Amounts Recognized In Regulatory Assets Before Tax	14	(30)
Defined Benefit Plan Amounts Recognized In Regulatory Liabilities Before Tax	$ 5	$ (3)
Pension Plan, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected return on assets		7000000.00%
Discount rate		3240000.00%
Other Postretirement Benefit Plan, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected return on assets		6440000.00%
Discount rate		3200000.00%

Retirement Benefits - Calculation of Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Amortization of:
Non-service net periodic benefit cost	$ 17	$ 20
Pension Plan, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	61	74
Interest cost	110	102
Expected return on assets	(209)	(213)
Amortization of:
Prior service cost (credit)	1	1
Actuarial loss	76	100
Curtailment benefits	0	0
Non-service net periodic benefit cost	39	64
Other Postretirement Benefit Plan, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	10	14
Interest cost	19	17
Expected return on assets	(25)	(26)
Amortization of:
Prior service cost (credit)	(5)	(6)
Actuarial loss	4	7
Curtailment benefits	0	(1)
Non-service net periodic benefit cost	$ 3	$ 5

Retirement Benefits - Defined Contribution Savings Plans (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Defined Benefit Plan Disclosure [Line Items]
Savings Plans Matching Contributions	$ 20	$ 20
Commonwealth Edison Co [Member]
Defined Benefit Plan Disclosure [Line Items]
Savings Plans Matching Contributions	8	8
PECO Energy Co [Member]
Defined Benefit Plan Disclosure [Line Items]
Savings Plans Matching Contributions	3	3
Baltimore Gas and Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Savings Plans Matching Contributions	2	2
Pepco Holdings LLC [Member]
Defined Benefit Plan Disclosure [Line Items]
Savings Plans Matching Contributions	3	3
Potomac Electric Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Savings Plans Matching Contributions	1	1
Delmarva Power and Light Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Savings Plans Matching Contributions	1	1
Atlantic City Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Savings Plans Matching Contributions	$ 0	$ 0

Amount of contribution received by defined benefit plan from employer which increases plan assets.

+ References + Details

Derivative Financial Instruments - Narrative (Details) MWh in Millions, $ in Millions	1 Months Ended
	Jun. 30, 2012 MWh	Mar. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)
Derivative [Line Items]
Other		$ 964	$ 766
Commonwealth Edison Co [Member]
Derivative [Line Items]
Long-term Purchase Commitment, Minimum Energy Volume Required \| MWh	1.3
Other		161	133
PECO Energy Co [Member]
Derivative [Line Items]
Other		41	35
Incremental Collateral For Loss Of Investment Grade Credit Rating		39
Baltimore Gas and Electric Company [Member]
Derivative [Line Items]
Other		61	48
Incremental Collateral For Loss Of Investment Grade Credit Rating		62
Delmarva Power and Light Company [Member]
Derivative [Line Items]
Other		88	59
Incremental Collateral For Loss Of Investment Grade Credit Rating		16
Atlantic City Electric Company [Member]
Derivative [Line Items]
Other		18	12
Pepco Holdings LLC [Member]
Derivative [Line Items]
Other		215	171
Commodity Contract [Member] \| External Counterparties \| Collateral [Member]
Derivative [Line Items]
Other		192
Commodity Contract [Member] \| Commonwealth Edison Co [Member] \| External Counterparties \| Collateral [Member]
Derivative [Line Items]
Other		72	41
Commodity Contract [Member] \| Delmarva Power and Light Company [Member] \| External Counterparties \| Collateral [Member]
Derivative [Line Items]
Other		73	$ 43
Commodity Contract [Member] \| Pepco Holdings LLC [Member] \| External Counterparties \| Collateral [Member]
Derivative [Line Items]
Other		$ 86

Debt and Credit Agreements - Narrative (Details) - Corporate [Member] $ in Millions	3 Months Ended
	Mar. 31, 2022 USD ($)
Debt Instrument [Line Items]
Notes Receivable, Related Parties	$ 319
Proceeds from Sale and Collection of Notes Receivable	258
ShortTermDebt03232017
Short-term Debt [Line Items]
Short-term Bank Loans and Notes Payable	$ 500
ShortTermDebt03232017 \| London Interbank Offered Rate (LIBOR) [Member]
Short-term Debt [Line Items]
Debt Instrument, Interest Rate Terms	SOFR plus 0.65
ShortTermDebt03312021.1
Short-term Debt [Line Items]
Short-term Bank Loans and Notes Payable	$ 150
ShortTermDebt03312021.1 \| London Interbank Offered Rate (LIBOR) [Member]
Short-term Debt [Line Items]
Debt Instrument, Interest Rate Terms	LIBOR plus 0.65
ShortTermDebtSOFRplus0.75Jan2023
Short-term Debt [Line Items]
Short-term Bank Loans and Notes Payable	$ 1,150
ShortTermDebtSOFRplus0.75Jan2023 \| Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate
Short-term Debt [Line Items]
Debt Instrument, Interest Rate Terms	0.75
ShortTermDebtSOFRplus075PLUS22.5BPincreaseJan2023 \| Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate
Short-term Debt [Line Items]
Debt Instrument, Interest Rate Terms	22.5

Debt and Credit Agreements - Commercial Paper Borrowings (Details) - Commercial Paper [Member] - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Short-term Debt [Line Items]
Commercial Paper	$ 250	$ 599
Short-term Debt, Weighted Average Interest Rate, at Point in Time	0.87%	0.35%
Corporate [Member]
Short-term Debt [Line Items]
Commercial Paper	$ 0	$ 0
Commonwealth Edison Co [Member]
Short-term Debt [Line Items]
Commercial Paper	0	0
PECO Energy Co [Member]
Short-term Debt [Line Items]
Commercial Paper	0	0
Baltimore Gas and Electric Company [Member]
Short-term Debt [Line Items]
Commercial Paper	$ 250	$ 130
Short-term Debt, Weighted Average Interest Rate, at Point in Time	0.87%	0.37%
Pepco Holdings LLC [Member]
Short-term Debt [Line Items]
Commercial Paper	$ 0	$ 469
Short-term Debt, Weighted Average Interest Rate, at Point in Time	0.00%	0.35%
Potomac Electric Power Company [Member]
Short-term Debt [Line Items]
Commercial Paper	$ 0	$ 175
Short-term Debt, Weighted Average Interest Rate, at Point in Time	0.00%	0.33%
Delmarva Power and Light Company [Member]
Short-term Debt [Line Items]
Commercial Paper	$ 0	$ 149
Short-term Debt, Weighted Average Interest Rate, at Point in Time	0.00%	0.36%
Atlantic City Electric Company [Member]
Short-term Debt [Line Items]
Commercial Paper	$ 0	$ 145
Short-term Debt, Weighted Average Interest Rate, at Point in Time	0.00%	0.35%

Summary of Revolving Credit Agreements (Details) - Revolving Credit Facility [Member] $ in Millions	Mar. 31, 2022 USD ($)
Commonwealth Edison Co [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 1,000
Commonwealth Edison Co [Member] \| Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate
Line of Credit Facility [Line Items]
Line of Credit Facility, Interest Rate at Period End	1.00%
PECO Energy Co [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 600
PECO Energy Co [Member] \| Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate
Line of Credit Facility [Line Items]
Line of Credit Facility, Interest Rate at Period End	0.90%
Baltimore Gas and Electric Company [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 600
Baltimore Gas and Electric Company [Member] \| Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate
Line of Credit Facility [Line Items]
Line of Credit Facility, Interest Rate at Period End	0.90%
Potomac Electric Power Company [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 300
Potomac Electric Power Company [Member] \| Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate
Line of Credit Facility [Line Items]
Line of Credit Facility, Interest Rate at Period End	1.075%
Delmarva Power and Light Company [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 300
Delmarva Power and Light Company [Member] \| Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate
Line of Credit Facility [Line Items]
Line of Credit Facility, Interest Rate at Period End	1.00%
Atlantic City Electric Company [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 300
Atlantic City Electric Company [Member] \| Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate
Line of Credit Facility [Line Items]
Line of Credit Facility, Interest Rate at Period End	1.075%
Corporate, Non-Segment [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	$ 900
Corporate, Non-Segment [Member] \| Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate
Line of Credit Facility [Line Items]
Line of Credit Facility, Interest Rate at Period End	1.275%

Debt and Credit Agreements - Issuance of Long-Term Debt (Details) $ in Millions	Mar. 31, 2022 USD ($)
Corporate [Member] \| SMBCTermLoanJuly2023 \| Notes Payable to Banks [Member]
Debt Instrument [Line Items]
Interest Rate	0.65%
Debt Instrument, Face Amount	$ 300
Corporate [Member] \| USBTermLoanJuly2023 \| Notes Payable to Banks [Member]
Debt Instrument [Line Items]
Interest Rate	0.65%
Debt Instrument, Face Amount	$ 300
Corporate [Member] \| PNCTermLoanJuly2023 \| Notes Payable to Banks [Member]
Debt Instrument [Line Items]
Interest Rate	0.65%
Debt Instrument, Face Amount	$ 250
Corporate [Member] \| Notes275Mar2027 \| Notes Payable to Banks [Member]
Debt Instrument [Line Items]
Interest Rate	2.75%
Debt Instrument, Face Amount	$ 650
Corporate [Member] \| Notes335Mar2032 \| Notes Payable to Banks [Member]
Debt Instrument [Line Items]
Interest Rate	3.35%
Debt Instrument, Face Amount	$ 650
Corporate [Member] \| Notes410Mar2052 \| Notes Payable to Banks [Member]
Debt Instrument [Line Items]
Interest Rate	4.10%
Debt Instrument, Face Amount	$ 700
Commonwealth Edison Co [Member] \| FMB315Mar2032 \| First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Interest Rate	3.15%
Debt Instrument, Face Amount	$ 300
Commonwealth Edison Co [Member] \| FMB385Mar2052 \| First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Interest Rate	3.85%
Debt Instrument, Face Amount	$ 450
Potomac Electric Power Company [Member] \| FMB397Mar2052 \| First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Interest Rate	3.97%
Debt Instrument, Face Amount	$ 400
Potomac Electric Power Company [Member] \| FMB336Sept2032 \| First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Interest Rate	3.35%
Debt Instrument, Face Amount	$ 225
Delmarva Power and Light Company [Member] \| Bonds105July2020 [Member] \| First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Interest Rate	3.06%
Debt Instrument, Face Amount	$ 125
Atlantic City Electric Company [Member] \| FMB230Mar2031 \| First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Interest Rate	2.27%
Debt Instrument, Face Amount	$ 25
Atlantic City Electric Company [Member] \| FMB324June2050 [Member] \| First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Interest Rate	3.06%
Debt Instrument, Face Amount	$ 150

Fair Value of Financial Assets and Liabilities - Fair Value Assets Liabilities Measured On Recurring Basis Unobservable Input Reconciliation (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Fair Value, Inputs, Level 3 [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	$ (182)	$ (267)
Total realized / unrealized gains (losses)
Included in net income	1	1
Included in regulatory assets	75	6
Purchases, sales, issuances and settlements
Transfers out of Level 3	(1)
Ending Balance	(107)	(260)
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	1	1
Commonwealth Edison Co [Member] \| Derivative [Member] \| Interest Rate Swap [Member]
Footnotes To Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Abstract]
Realized Investment Gains (Losses)	6	8
Commonwealth Edison Co [Member] \| Fair Value, Inputs, Level 3 [Member] \| Derivative [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	(219)	(301)
Total realized / unrealized gains (losses)
Included in net income	0	0
Included in regulatory assets	75	6
Purchases, sales, issuances and settlements
Transfers out of Level 3	0
Ending Balance	(144)	(295)
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	0	0
Footnotes To Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Abstract]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Period Increase (Decrease)	(69)	(2)
Pepco Holdings LLC [Member] \| Fair Value, Inputs, Level 3 [Member] \| 6311 Life Insurance [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	35	34
Total realized / unrealized gains (losses)
Included in net income	1	1
Included in regulatory assets	0	0
Purchases, sales, issuances and settlements
Transfers out of Level 3	0
Ending Balance	36	35
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	1	1
Potomac Electric Power Company [Member] \| Fair Value, Inputs, Level 3 [Member] \| 6311 Life Insurance [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	35	34
Total realized / unrealized gains (losses)
Included in net income	1	1
Included in regulatory assets	0	0
Purchases, sales, issuances and settlements
Transfers out of Level 3	0
Ending Balance	36	35
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	$ 1	$ 1

Fair Value of Financial Assets and Liabilities - Fair Value Assets And Liabilities Measured On Recurring Basis Gain Loss Included In Earnings (Details) - Fair Value, Inputs, Level 3 [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Fair Value Assets And Liabilities Measured On Recurring Basis Gain Loss Included In Earnings [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	$ (1)	$ (1)
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	$ 1	$ 1

Fair Value of Financial Assets and Liabilities - Fair Value Inputs Assets Quantitative Information (Details) - Fair Value, Inputs, Level 3 [Member] - Derivative [Member] $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	$ (144)	$ (219)
Discounted Cash Flow [Member] \| Minimum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Derivative Asset (Liability) Net, Measurement Input	0.04	0.03
Forward heat rate	890.00%	900.00%
Fair Value Inputs Renewable Factor	92.00%	92.00%
Discounted Cash Flow [Member] \| Maximum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Derivative Asset (Liability) Net, Measurement Input	0.05	0.07
Forward heat rate	910.00%	1000.00%
Fair Value Inputs Renewable Factor	120.00%	120.00%
Discounted Cash Flow [Member] \| Arithmetic Average [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Derivative Asset (Liability) Net, Measurement Input	0.0435	0.0477
Forward heat rate	900.00%	913.00%
Fair Value Inputs Renewable Factor	98.00%	97.00%
Commonwealth Edison Co [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	$ (144)	$ (219)
Commonwealth Edison Co [Member] \| Discounted Cash Flow [Member] \| Minimum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Derivative Asset (Liability) Net, Measurement Input	0.04	0.03
Forward heat rate	890.00%	900.00%
Fair Value Inputs Renewable Factor	92.00%	92.00%
Commonwealth Edison Co [Member] \| Discounted Cash Flow [Member] \| Maximum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Derivative Asset (Liability) Net, Measurement Input	0.05	0.07
Forward heat rate	910.00%	1000.00%
Fair Value Inputs Renewable Factor	120.00%	120.00%
Commonwealth Edison Co [Member] \| Discounted Cash Flow [Member] \| Arithmetic Average [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Derivative Asset (Liability) Net, Measurement Input	0.0435	0.0477
Forward heat rate	900.00%	913.00%
Fair Value Inputs Renewable Factor	98.00%	97.00%

Commitments and Contingencies - Narrative (Details) $ in Millions		1 Months Ended	12 Months Ended
	Mar. 23, 2016 MW	Nov. 30, 2020 USD ($)	Dec. 31, 2022 MW	Dec. 31, 2018 MW	Dec. 31, 2017 MW	Mar. 31, 2022 USD ($) MGPSite	Dec. 31, 2021 USD ($)
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment						$ 623
Accrual for Environmental Loss Contingencies, Gross						354	$ 352
Commonwealth Edison Co [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment						$ 224
Mgp Site Contingency Monitoring Count \| MGPSite						21
Accrual for Environmental Loss Contingencies, Gross						$ 279	279
Deferred Prosecution Agreement Payments		$ 200
Customer Refund Liability, Noncurrent						38
PECO Energy Co [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment						$ 182
Mgp Site Contingency Monitoring Count \| MGPSite						6
Accrual for Environmental Loss Contingencies, Gross						$ 21	22
Baltimore Gas and Electric Company [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment						$ 6
Mgp Site Contingency Monitoring Count \| MGPSite						4
Accrual for Environmental Loss Contingencies, Gross						$ 7	6
Pepco Holdings LLC [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment						124
Accrual for Environmental Loss Contingencies, Gross						42	42
Potomac Electric Power Company [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment						94
Accrual for Environmental Loss Contingencies, Gross						40	40
Delmarva Power and Light Company [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment						$ 19
Mgp Site Contingency Count \| MGPSite						1
Accrual for Environmental Loss Contingencies, Gross						$ 1	$ 1
Pepco Holdings Inc [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment						513
Pepco Holdings Inc [Member] \| Pepco Holdings LLC [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment						320
Pepco Holdings Inc [Member] \| Potomac Electric Power Company [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment						120
Pepco Holdings Inc [Member] \| Delmarva Power and Light Company [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment						$ 89
Wind Assets [Member] \| Pepco Holdings Inc [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Non-Financial Commitment \| MW	100
Wind Assets [Member] \| Pepco Holdings Inc [Member] \| Delmarva Power and Light Company [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Purchase Commitment \| MW	120			40	40
Wind Assets [Member] \| Pepco Holdings Inc [Member] \| Delmarva Power and Light Company [Member] \| Forecast [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Purchase Commitment \| MW			40

Commitments and Contingencies - Merger Commitment (Details) $ in Millions	Mar. 31, 2022 USD ($)
Other Commitments [Line Items]
Other Commitment	$ 623
Pepco Holdings LLC [Member]
Other Commitments [Line Items]
Other Commitment	124
Potomac Electric Power Company [Member]
Other Commitments [Line Items]
Other Commitment	94
Delmarva Power and Light Company [Member]
Other Commitments [Line Items]
Other Commitment	19
Atlantic City Electric Company [Member]
Other Commitments [Line Items]
Other Commitment	11
Pepco Holdings Inc [Member]
Other Commitments [Line Items]
Other Commitment	513
Pepco Holdings Inc [Member] \| Remaining commitment
Other Commitments [Line Items]
Other Commitment	65
Pepco Holdings Inc [Member] \| Pepco Holdings LLC [Member]
Other Commitments [Line Items]
Other Commitment	320
Pepco Holdings Inc [Member] \| Pepco Holdings LLC [Member] \| Remaining commitment
Other Commitments [Line Items]
Other Commitment	55
Pepco Holdings Inc [Member] \| Potomac Electric Power Company [Member]
Other Commitments [Line Items]
Other Commitment	120
Pepco Holdings Inc [Member] \| Potomac Electric Power Company [Member] \| Remaining commitment
Other Commitments [Line Items]
Other Commitment	46
Pepco Holdings Inc [Member] \| Delmarva Power and Light Company [Member]
Other Commitments [Line Items]
Other Commitment	89
Pepco Holdings Inc [Member] \| Delmarva Power and Light Company [Member] \| Remaining commitment
Other Commitments [Line Items]
Other Commitment	6
Pepco Holdings Inc [Member] \| Atlantic City Electric Company [Member]
Other Commitments [Line Items]
Other Commitment	111
Pepco Holdings Inc [Member] \| Atlantic City Electric Company [Member] \| Remaining commitment
Other Commitments [Line Items]
Other Commitment	$ 3

Commitments and Contingencies - Schedule of Accruals for Environmental Matters (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Site Contingency [Line Items]
Total environmental investigation and remediation reserve	$ 354	$ 352
Commonwealth Edison Co [Member]
Site Contingency [Line Items]
Total environmental investigation and remediation reserve	279	279
PECO Energy Co [Member]
Site Contingency [Line Items]
Total environmental investigation and remediation reserve	21	22
Baltimore Gas and Electric Company [Member]
Site Contingency [Line Items]
Total environmental investigation and remediation reserve	7	6
Pepco Holdings LLC [Member]
Site Contingency [Line Items]
Total environmental investigation and remediation reserve	42	42
Potomac Electric Power Company [Member]
Site Contingency [Line Items]
Total environmental investigation and remediation reserve	40	40
Delmarva Power and Light Company [Member]
Site Contingency [Line Items]
Total environmental investigation and remediation reserve	1	1
Atlantic City Electric Company [Member]
Site Contingency [Line Items]
Total environmental investigation and remediation reserve	1	1
Accrual For MGP Investigation And Remediation [Member]
Site Contingency [Line Items]
Total environmental investigation and remediation reserve	305	303
Accrual For MGP Investigation And Remediation [Member] \| Commonwealth Edison Co [Member]
Site Contingency [Line Items]
Total environmental investigation and remediation reserve	279	279
Accrual For MGP Investigation And Remediation [Member] \| PECO Energy Co [Member]
Site Contingency [Line Items]
Total environmental investigation and remediation reserve	20	20
Accrual For MGP Investigation And Remediation [Member] \| Baltimore Gas and Electric Company [Member]
Site Contingency [Line Items]
Total environmental investigation and remediation reserve	6	4
Accrual For MGP Investigation And Remediation [Member] \| Pepco Holdings LLC [Member]
Site Contingency [Line Items]
Total environmental investigation and remediation reserve	0	0
Accrual For MGP Investigation And Remediation [Member] \| Potomac Electric Power Company [Member]
Site Contingency [Line Items]
Total environmental investigation and remediation reserve	0	0
Accrual For MGP Investigation And Remediation [Member] \| Delmarva Power and Light Company [Member]
Site Contingency [Line Items]
Total environmental investigation and remediation reserve	0	0
Accrual For MGP Investigation And Remediation [Member] \| Atlantic City Electric Company [Member]
Site Contingency [Line Items]
Total environmental investigation and remediation reserve	$ 0	$ 0

Changes in Accumulated Other Comprehensive Income - Schedule of Changes in AOCI (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Movement in Accumulated Other Comprehensive Income [Roll Forward]
Beginning balance	$ 34,795	$ 34,868
Other comprehensive income (loss), net of income taxes	14	54
Ending balance	23,491	34,313
Gains (Losses) on Cash Flow Hedges
Movement in Accumulated Other Comprehensive Income [Roll Forward]
Beginning balance	(6)	(5)
OCI before reclassifications		0
Amounts reclassified from AOCI	0	0
Other comprehensive income (loss), net of income taxes	0	0
Ending balance	0	(5)
Gains (Losses) on Cash Flow Hedges \| Exelon Generation Co L L C [Member]
Movement in Accumulated Other Comprehensive Income [Roll Forward]
Other comprehensive income (loss), net of income taxes	6
Pension and Non-Pension Postretirement Benefit Plan Items
Movement in Accumulated Other Comprehensive Income [Roll Forward]
Beginning balance	(2,721)	(3,372)
OCI before reclassifications		(2)
Amounts reclassified from AOCI	14	55
Other comprehensive income (loss), net of income taxes	14	53
Ending balance	(713)	(3,319)
Pension and Non-Pension Postretirement Benefit Plan Items \| Exelon Generation Co L L C [Member]
Movement in Accumulated Other Comprehensive Income [Roll Forward]
Other comprehensive income (loss), net of income taxes	1,994
Foreign Currency Items
Movement in Accumulated Other Comprehensive Income [Roll Forward]
Beginning balance	(23)	(23)
OCI before reclassifications		1
Amounts reclassified from AOCI	0	0
Other comprehensive income (loss), net of income taxes	0	1
Ending balance	0	(22)
Foreign Currency Items \| Exelon Generation Co L L C [Member]
Movement in Accumulated Other Comprehensive Income [Roll Forward]
Other comprehensive income (loss), net of income taxes	23
Total
Movement in Accumulated Other Comprehensive Income [Roll Forward]
Beginning balance	(2,750)	(3,400)
OCI before reclassifications		(1)
Amounts reclassified from AOCI	14	55
Other comprehensive income (loss), net of income taxes	14	54
Ending balance	(713)	$ (3,346)
Total \| Exelon Generation Co L L C [Member]
Movement in Accumulated Other Comprehensive Income [Roll Forward]
Other comprehensive income (loss), net of income taxes	$ 2,023

Changes in Accumulated Other Comprehensive Income - Income Taxes Allocated to Other Comprehensive Income (Loss) Components (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Prior service costs
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other Comprehensive Income (Loss), Tax	$ 0	$ 1
Actuarial losses
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other Comprehensive Income (Loss), Tax	$ (5)	$ (19)

Amount of tax expense (benefit) allocated to other comprehensive income (loss).

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
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-Name Accounting Standards Codification
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Reference 6: http://www.xbrl.org/2003/role/disclosureRef
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Reference 8: http://www.xbrl.org/2003/role/disclosureRef
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Reference 9: http://www.xbrl.org/2003/role/disclosureRef
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Reference 11: http://www.xbrl.org/2003/role/disclosureRef
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Variable Interest Entities - Narrative (Details) $ in Millions	Mar. 31, 2022 USD ($)
Variable Interest Entity [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 73

Variable Interest Entities - Assets and Liabilities of Consolidated VIES (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021	Mar. 31, 2021	Dec. 31, 2020
Variable Interest Entity [Line Items]
Cash and cash equivalents	$ 2,476	$ 672	$ 1,908	$ 663
Restricted cash and cash equivalents	430	321	374	438
Accounts receivable, net
Customer	1,976	1,869
Inventory, net
Materials and supplies	473	476
Current assets of discontinued operations	0	7,835
Other current assets	463	387
Total current assets	8,145	13,957
Property, plant and equipment, net	65,465	64,558
Other Assets, Noncurrent	1,045	885
Assets	92,698	133,013
Long-term debt due within one year	2,154	2,153
Accounts payable	2,175	2,379
Accrued expenses	1,029	1,137
Unamortized energy contract liabilities	13	89
Current liabilities of discontinued operations	0	7,940
Other	964	766
Total current liabilities	8,635	16,111
Long-term debt	35,008	30,749
Asset retirement obligations, noncurrent	273	271
Unamortized energy contract liabilities	42	146
Other	2,187	1,573
Liabilities	69,207	98,218
Pepco Holdings LLC [Member]
Variable Interest Entity [Line Items]
Cash and cash equivalents	796	136	558	111
Restricted cash and cash equivalents	106	77	37	39
Accounts receivable, net
Customer	505	512
Inventory, net
Materials and supplies	209	209
Other current assets	69	69
Total current assets	2,368	1,692
Property, plant and equipment, net	16,701	16,498
Other Assets, Noncurrent	253	258
Assets	25,636	24,744
Long-term debt due within one year	400	399
Accounts payable	522	578
Accrued expenses	264	281
Unamortized energy contract liabilities	13	89
Other	215	171
Total current liabilities	1,748	2,246
Long-term debt	7,833	7,148
Asset retirement obligations, noncurrent	70	70
Unamortized energy contract liabilities	42	146
Other	661	570
Liabilities	14,319	14,159
Atlantic City Electric Company [Member]
Variable Interest Entity [Line Items]
Cash and cash equivalents	168	29	353	17
Restricted cash and cash equivalents	0	0	$ 4	$ 3
Accounts receivable, net
Customer	128	141
Inventory, net
Other current assets	5	3
Total current assets	540	333
Property, plant and equipment, net	3,763	3,729
Other Assets, Noncurrent	37	37
Assets	4,929	4,556
Long-term debt due within one year	3	3
Accounts payable	139	165
Accrued expenses	43	44
Other	18	12
Total current liabilities	349	445
Long-term debt	1,754	1,579
Other	165	49
Liabilities	$ 3,174	$ 2,981

Variable Interest Entities - Summary of Significant Unconsolidated VIEs (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Variable Interest Entity [Line Items]
Total assets	$ 92,698	$ 133,013
Total liabilities	$ 69,207	$ 98,218

Sum of the carrying amounts as of the balance sheet date of all assets that are recognized. Assets are probable future economic benefits obtained or controlled by an entity as a result of past transactions or events.

Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef
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Reference 5: http://www.xbrl.org/2003/role/disclosureRef
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Sum of the carrying amounts as of the balance sheet date of all liabilities that are recognized. Liabilities are probable future sacrifices of economic benefits arising from present obligations of an entity to transfer assets or provide services to other entities in the future.

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