Cover Page
Cover Page | 9 Months Ended |
Sep. 30, 2019shares | |
Document Type | 10-Q |
Document Quarterly Report | true |
Document Period End Date | Sep. 30, 2019 |
Document Transition Report | false |
Entity File Number | 001-16169 |
Entity Registrant Name | EXELON CORPORATION |
Entity Tax Identification Number | 23-2990190 |
Entity Incorporation, State or Country Code | PA |
Entity Address, Address Line One | 10 South Dearborn Street |
Entity Address, Address Line Two | P.O. Box 805379 |
Entity Address, City or Town | Chicago |
Entity Address, State or Province | IL |
Entity Address, Postal Zip Code | 60680-5379 |
City Area Code | (800) |
Local Phone Number | 483-3220 |
Title of 12(b) Security | Common stock, without par value |
Trading Symbol | EXC |
Security Exchange Name | NASDAQ |
Entity Current Reporting Status | Yes |
Entity Interactive Data Current | Yes |
Entity Filer Category | Large Accelerated Filer |
Entity Small Business | false |
Entity Emerging Growth Company | false |
Entity Shell Company | false |
Entity Common Stock Shares Outstanding | 972,108,865 |
Document Fiscal Year Focus | 2019 |
Document Fiscal Period Focus | Q3 |
Current Fiscal Year End Date | --12-31 |
Entity Central Index Key | 0001109357 |
Amendment Flag | false |
Exelon Generation Co L L C [Member] | |
Entity File Number | 333-85496 |
Entity Registrant Name | EXELON GENERATION COMPANY, LLC |
Entity Tax Identification Number | 23-3064219 |
Entity Incorporation, State or Country Code | PA |
Entity Address, Address Line One | 300 Exelon Way |
Entity Address, City or Town | Kennett Square |
Entity Address, State or Province | PA |
Entity Address, Postal Zip Code | 19348-2473 |
City Area Code | (610) |
Local Phone Number | 765-5959 |
Entity Filer Category | Non-accelerated Filer |
Entity Small Business | false |
Entity Emerging Growth Company | false |
Entity Central Index Key | 0001168165 |
Commonwealth Edison Co [Member] | |
Entity File Number | 001-01839 |
Entity Registrant Name | COMMONWEALTH EDISON COMPANY |
Entity Tax Identification Number | 36-0938600 |
Entity Incorporation, State or Country Code | IL |
Entity Address, Address Line One | 440 South LaSalle Street |
Entity Address, City or Town | Chicago |
Entity Address, State or Province | IL |
Entity Address, Postal Zip Code | 60605-1028 |
City Area Code | (312) |
Local Phone Number | 394-4321 |
Entity Filer Category | Non-accelerated Filer |
Entity Small Business | false |
Entity Emerging Growth Company | false |
Entity Common Stock Shares Outstanding | 127,021,343 |
Entity Central Index Key | 0000022606 |
PECO Energy Co [Member] | |
Entity File Number | 000-16844 |
Entity Registrant Name | PECO ENERGY COMPANY |
Entity Tax Identification Number | 23-0970240 |
Entity Incorporation, State or Country Code | PA |
Entity Address, Address Line One | P.O. Box 8699 |
Entity Address, Address Line Two | 2301 Market Street |
Entity Address, City or Town | Philadelphia |
Entity Address, State or Province | PA |
Entity Address, Postal Zip Code | 19101-8699 |
City Area Code | (215) |
Local Phone Number | 841-4000 |
Title of 12(b) Security | Cumulative Preferred Security, Series D |
Trading Symbol | EXC/28 |
Security Exchange Name | NYSE |
Entity Filer Category | Non-accelerated Filer |
Entity Small Business | false |
Entity Emerging Growth Company | false |
Entity Common Stock Shares Outstanding | 170,478,507 |
Entity Central Index Key | 0000078100 |
Baltimore Gas and Electric Company [Member] | |
Entity File Number | 001-01910 |
Entity Registrant Name | BALTIMORE GAS AND ELECTRIC COMPANY |
Entity Tax Identification Number | 52-0280210 |
Entity Incorporation, State or Country Code | MD |
Entity Address, Address Line One | 2 Center Plaza |
Entity Address, Address Line Two | 110 West Fayette Street |
Entity Address, City or Town | Baltimore |
Entity Address, State or Province | MD |
Entity Address, Postal Zip Code | 21201-3708 |
City Area Code | (410) |
Local Phone Number | 234-5000 |
Entity Filer Category | Non-accelerated Filer |
Entity Small Business | false |
Entity Emerging Growth Company | false |
Entity Common Stock Shares Outstanding | 1,000 |
Entity Central Index Key | 0000009466 |
Pepco Holdings LLC [Member] | |
Entity File Number | 001-31403 |
Entity Registrant Name | PEPCO HOLDINGS LLC |
Entity Tax Identification Number | 52-2297449 |
Entity Incorporation, State or Country Code | DE |
Entity Address, Address Line One | 701 Ninth Street, N.W. |
Entity Address, City or Town | Washington, District of Columbia |
Entity Address, Postal Zip Code | 20068 |
City Area Code | (202) |
Local Phone Number | 872-2000 |
Entity Filer Category | Non-accelerated Filer |
Entity Small Business | false |
Entity Emerging Growth Company | false |
Entity Central Index Key | 0001135971 |
Potomac Electric Power Company [Member] | |
Entity File Number | 001-01072 |
Entity Registrant Name | POTOMAC ELECTRIC POWER COMPANY |
Entity Tax Identification Number | 53-0127880 |
Entity Incorporation, State or Country Code | DC |
Entity Address, Address Line One | 701 Ninth Street, N.W. |
Entity Address, City or Town | Washington, District of Columbia |
Entity Address, Postal Zip Code | 20068 |
City Area Code | (202) |
Local Phone Number | 872-2000 |
Entity Filer Category | Non-accelerated Filer |
Entity Small Business | false |
Entity Emerging Growth Company | false |
Entity Common Stock Shares Outstanding | 100 |
Entity Central Index Key | 0000079732 |
Delmarva Power and Light Company [Member] | |
Entity File Number | 001-01405 |
Entity Registrant Name | DELMARVA POWER & LIGHT COMPANY |
Entity Tax Identification Number | 51-0084283 |
Entity Incorporation, State or Country Code | DE |
Entity Address, Address Line One | 500 North Wakefield Drive |
Entity Address, City or Town | Newark |
Entity Address, State or Province | DE |
Entity Address, Postal Zip Code | 19702 |
City Area Code | (202) |
Local Phone Number | 872-2000 |
Entity Filer Category | Non-accelerated Filer |
Entity Small Business | false |
Entity Emerging Growth Company | false |
Entity Common Stock Shares Outstanding | 1,000 |
Entity Central Index Key | 0000027879 |
Atlantic City Electric Company [Member] | |
Entity File Number | 001-03559 |
Entity Registrant Name | ATLANTIC CITY ELECTRIC COMPANY |
Entity Tax Identification Number | 21-0398280 |
Entity Incorporation, State or Country Code | NJ |
Entity Address, Address Line One | 500 North Wakefield Drive |
Entity Address, City or Town | Newark |
Entity Address, State or Province | DE |
Entity Address, Postal Zip Code | 19702 |
City Area Code | (202) |
Local Phone Number | 872-2000 |
Entity Filer Category | Non-accelerated Filer |
Entity Small Business | false |
Entity Emerging Growth Company | false |
Entity Common Stock Shares Outstanding | 8,546,017 |
Entity Central Index Key | 0000008192 |
VIRGINIA | Potomac Electric Power Company [Member] | |
Entity Incorporation, State or Country Code | VA |
VIRGINIA | Delmarva Power and Light Company [Member] | |
Entity Incorporation, State or Country Code | VA |
Consolidated Statements of Oper
Consolidated Statements of Operations and Comprehensive Income (Unaudited) - USD ($) shares in Millions, $ in Millions | 3 Months Ended | 9 Months Ended | |||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2019 | Sep. 30, 2018 | ||
Operating revenues | |||||
Revenues from alternative revenue programs | $ (80) | $ (25) | $ (98) | $ (41) | |
Operating revenues from affiliates | 0 | 0 | 0 | 0 | |
Total operating revenues | 8,929 | 9,403 | 26,096 | 27,170 | |
Operating expenses | |||||
Operating and maintenance | 2,072 | 2,346 | 6,419 | 7,036 | |
Depreciation and amortization | 1,083 | 1,105 | 3,237 | 3,284 | |
Taxes other than income | 452 | 469 | 1,316 | 1,342 | |
Total operating expenses | 7,559 | 8,252 | 22,703 | 24,036 | |
Gain on sales of assets and businesses | (17) | (5) | 19 | 55 | |
Operating income | 1,353 | 1,146 | 3,412 | 3,189 | |
Other income and (deductions) | |||||
Interest expense, net | (403) | (387) | (1,202) | (1,119) | |
Interest expense to affiliates | (6) | (6) | (19) | (19) | |
Other, net | 158 | 194 | 837 | 212 | |
Total other income and (deductions) | (251) | (199) | (384) | (926) | |
Income before income taxes | 1,102 | 947 | 3,028 | 2,263 | |
Income taxes | 172 | 137 | 626 | 262 | |
Equity in losses of unconsolidated affiliates | (170) | (10) | (182) | (22) | |
Net income | 760 | 800 | 2,220 | 1,979 | |
Net income attributable to noncontrolling interests | (12) | 67 | 56 | 121 | |
Net income (loss) attributable to common shareholders | 772 | 733 | 2,164 | 1,858 | |
Other comprehensive income (loss), net of income taxes | |||||
Prior service benefit reclassified to periodic benefit cost | (16) | (17) | (49) | (50) | |
Actuarial loss reclassified to periodic benefit cost | 37 | 62 | 111 | 186 | |
Pension and non-pension postretirement benefit plan valuation adjustment | 6 | 5 | (32) | 22 | |
Unrealized (loss) gain on cash flow hedges | 0 | 0 | 0 | 12 | |
Unrealized (loss) gain on investments in unconsolidated affiliates | 5 | 0 | 1 | 3 | |
Unrealized gain (loss) on foreign currency translation | (2) | 2 | 2 | (4) | |
Other comprehensive income | 30 | 52 | 33 | 169 | |
Comprehensive income | 790 | 852 | 2,253 | 2,148 | |
Comprehensive (loss) income attributable to noncontrolling interests | (9) | 67 | 57 | 123 | |
Comprehensive income attributable to common shareholders/membership interest | $ 799 | $ 785 | $ 2,196 | $ 2,025 | |
Average shares of common stock outstanding: | |||||
Basic average shares of common stock outstanding | 973 | 968 | 972 | 967 | |
Assumed exercise and/or distributions of stock-based awards | 1 | 2 | 1 | 2 | |
Diluted average shares of common stock outstanding | [1] | 974 | 970 | 973 | 969 |
Earnings per average common share: | |||||
Basic earnings per average common share | $ 0.79 | $ 0.76 | $ 2.23 | $ 1.92 | |
Diluted earnings per average common share | $ 0.79 | $ 0.76 | $ 2.22 | $ 1.92 | |
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount | 2 | 3 | |||
Exelon Generation Co L L C [Member] | |||||
Operating revenues | |||||
Operating revenues from affiliates | $ 275 | $ 308 | $ 844 | $ 979 | |
Total operating revenues | 4,774 | 5,278 | 14,280 | 15,368 | |
Operating expenses | |||||
Purchased power and/or fuel from affiliates | 3 | 3 | 7 | 10 | |
Operating and maintenance | 947 | 1,218 | 3,131 | 3,643 | |
Operating and maintenance from affiliates | 140 | 152 | 439 | 483 | |
Depreciation and amortization | 407 | 468 | 1,221 | 1,383 | |
Taxes other than income | 129 | 143 | 394 | 414 | |
Total operating expenses | 4,274 | 4,961 | 13,333 | 14,475 | |
Gain on sales of assets and businesses | (18) | (6) | 15 | 48 | |
Operating income | 482 | 311 | 962 | 941 | |
Other income and (deductions) | |||||
Interest expense, net | (101) | (93) | (310) | (278) | |
Interest expense to affiliates | (8) | (8) | (26) | (27) | |
Other, net | 128 | 179 | 729 | 164 | |
Total other income and (deductions) | 19 | 78 | 393 | (141) | |
Income before income taxes | 501 | 389 | 1,355 | 800 | |
Income taxes | 87 | 78 | 388 | 110 | |
Equity in losses of unconsolidated affiliates | (170) | (11) | (183) | (23) | |
Net income | 244 | 300 | 784 | 667 | |
Net income attributable to noncontrolling interests | (13) | 66 | 56 | 120 | |
Net income attributable to membership interest | 257 | 234 | 728 | 547 | |
Other comprehensive income (loss), net of income taxes | |||||
Unrealized (loss) gain on cash flow hedges | 0 | 0 | 0 | 12 | |
Unrealized (loss) gain on investments in unconsolidated affiliates | 5 | 0 | 1 | 3 | |
Unrealized gain (loss) on foreign currency translation | (2) | 2 | 2 | (4) | |
Other comprehensive income | 3 | 2 | 3 | 11 | |
Comprehensive income | 247 | 302 | 787 | 678 | |
Comprehensive (loss) income attributable to noncontrolling interests | (10) | 66 | 57 | 122 | |
Comprehensive income attributable to common shareholders/membership interest | 257 | 236 | 730 | 556 | |
Commonwealth Edison Co [Member] | |||||
Operating revenues | |||||
Revenues from alternative revenue programs | (56) | (15) | (98) | (27) | |
Operating revenues from affiliates | 4 | 4 | 13 | 23 | |
Total operating revenues | 1,583 | 1,598 | 4,342 | 4,508 | |
Operating expenses | |||||
Purchased power and/or fuel from affiliates | 83 | 123 | 270 | 421 | |
Operating and maintenance | 267 | 276 | 771 | 785 | |
Operating and maintenance from affiliates | 73 | 61 | 196 | 189 | |
Depreciation and amortization | 259 | 237 | 767 | 696 | |
Taxes other than income | 80 | 82 | 228 | 238 | |
Total operating expenses | 1,256 | 1,275 | 3,431 | 3,610 | |
Gain on sales of assets and businesses | 1 | 0 | 4 | 5 | |
Operating income | 328 | 323 | 915 | 903 | |
Other income and (deductions) | |||||
Interest expense, net | (87) | (82) | (258) | (251) | |
Interest expense to affiliates | (4) | (3) | (10) | (10) | |
Other, net | 8 | 7 | 27 | 21 | |
Total other income and (deductions) | (83) | (78) | (241) | (240) | |
Income before income taxes | 245 | 245 | 674 | 663 | |
Income taxes | 45 | 52 | 130 | 140 | |
Net income | 200 | 193 | 544 | 523 | |
Other comprehensive income (loss), net of income taxes | |||||
Comprehensive income | 200 | 193 | 544 | 523 | |
PECO Energy Co [Member] | |||||
Operating revenues | |||||
Revenues from alternative revenue programs | (11) | 1 | (16) | 2 | |
Operating revenues from affiliates | 1 | 2 | 4 | 5 | |
Total operating revenues | 778 | 757 | 2,333 | 2,275 | |
Operating expenses | |||||
Purchased power and/or fuel from affiliates | 43 | 34 | 122 | 94 | |
Operating and maintenance | 182 | 184 | 531 | 572 | |
Operating and maintenance from affiliates | 37 | 35 | 112 | 114 | |
Depreciation and amortization | 83 | 75 | 247 | 224 | |
Taxes other than income | 47 | 46 | 126 | 125 | |
Total operating expenses | 595 | 603 | 1,783 | 1,853 | |
Gain on sales of assets and businesses | 0 | 0 | 0 | 1 | |
Operating income | 183 | 154 | 550 | 423 | |
Other income and (deductions) | |||||
Interest expense, net | (30) | (28) | (91) | (85) | |
Interest expense to affiliates | (3) | (4) | (9) | (11) | |
Other, net | 4 | 2 | 11 | 4 | |
Total other income and (deductions) | (29) | (30) | (89) | (92) | |
Income before income taxes | 154 | 124 | 461 | 331 | |
Income taxes | 14 | (2) | 51 | (5) | |
Net income | 140 | 126 | 410 | 336 | |
Other comprehensive income (loss), net of income taxes | |||||
Comprehensive income | 140 | 126 | 410 | 336 | |
Baltimore Gas and Electric Company [Member] | |||||
Operating revenues | |||||
Revenues from alternative revenue programs | (5) | (6) | 11 | (23) | |
Operating revenues from affiliates | 6 | 6 | 18 | 18 | |
Total operating revenues | 703 | 731 | 2,327 | 2,369 | |
Operating expenses | |||||
Purchased power and/or fuel from affiliates | 64 | 68 | 196 | 195 | |
Operating and maintenance | 157 | 144 | 451 | 462 | |
Operating and maintenance from affiliates | 39 | 38 | 118 | 116 | |
Depreciation and amortization | 116 | 110 | 368 | 358 | |
Taxes other than income | 65 | 64 | 195 | 188 | |
Total operating expenses | 612 | 628 | 1,936 | 2,005 | |
Gain on sales of assets and businesses | 0 | 0 | 0 | 1 | |
Operating income | 91 | 103 | 391 | 365 | |
Other income and (deductions) | |||||
Interest expense, net | (31) | (27) | (89) | (78) | |
Other, net | 7 | 5 | 18 | 14 | |
Total other income and (deductions) | (24) | (22) | (71) | (64) | |
Income before income taxes | 67 | 81 | 320 | 301 | |
Income taxes | 12 | 18 | 59 | 59 | |
Net income | 55 | 63 | 261 | 242 | |
Other comprehensive income (loss), net of income taxes | |||||
Comprehensive income | 55 | 63 | 261 | 242 | |
Pepco Holdings LLC [Member] | |||||
Operating revenues | |||||
Revenues from alternative revenue programs | (9) | (5) | 4 | 7 | |
Operating revenues from affiliates | 4 | 3 | 11 | 11 | |
Total operating revenues | 1,380 | 1,361 | 3,700 | 3,688 | |
Operating expenses | |||||
Purchased power and/or fuel from affiliates | 83 | 82 | 254 | 268 | |
Operating and maintenance | 254 | 261 | 706 | 751 | |
Operating and maintenance from affiliates | 36 | 31 | 105 | 106 | |
Depreciation and amortization | 193 | 192 | 562 | 555 | |
Taxes other than income | 122 | 123 | 342 | 343 | |
Total operating expenses | 1,124 | 1,116 | 3,106 | 3,165 | |
Operating income | 256 | 245 | 594 | 523 | |
Other income and (deductions) | |||||
Interest expense, net | (66) | (65) | (197) | (193) | |
Other, net | 13 | 11 | 39 | 33 | |
Total other income and (deductions) | (53) | (54) | (158) | (160) | |
Income before income taxes | 203 | 191 | 436 | 363 | |
Income taxes | 14 | 4 | 25 | 28 | |
Equity in losses of unconsolidated affiliates | 0 | 0 | 1 | 1 | |
Net income | 189 | 187 | 412 | 336 | |
Other comprehensive income (loss), net of income taxes | |||||
Comprehensive income attributable to common shareholders/membership interest | 189 | 187 | 412 | 336 | |
Potomac Electric Power Company [Member] | |||||
Operating revenues | |||||
Revenues from alternative revenue programs | (3) | (4) | 10 | 6 | |
Operating revenues from affiliates | 2 | 2 | 5 | 5 | |
Total operating revenues | 642 | 628 | 1,748 | 1,708 | |
Operating expenses | |||||
Purchased power and/or fuel from affiliates | 65 | 46 | 188 | 143 | |
Operating and maintenance | 85 | 84 | 208 | 216 | |
Operating and maintenance from affiliates | 50 | 52 | 156 | 167 | |
Depreciation and amortization | 95 | 99 | 281 | 286 | |
Taxes other than income | 104 | 104 | 286 | 288 | |
Total operating expenses | 515 | 516 | 1,444 | 1,454 | |
Operating income | 127 | 112 | 304 | 254 | |
Other income and (deductions) | |||||
Interest expense, net | (33) | (32) | (100) | (96) | |
Other, net | 9 | 7 | 22 | 23 | |
Total other income and (deductions) | (24) | (25) | (78) | (73) | |
Income before income taxes | 103 | 87 | 226 | 181 | |
Income taxes | 5 | (2) | 9 | 7 | |
Net income | 98 | 89 | 217 | 174 | |
Other comprehensive income (loss), net of income taxes | |||||
Comprehensive income | 98 | 89 | 217 | 174 | |
Delmarva Power and Light Company [Member] | |||||
Operating revenues | |||||
Revenues from alternative revenue programs | (6) | 0 | (6) | 5 | |
Operating revenues from affiliates | 1 | 2 | 5 | 6 | |
Total operating revenues | 319 | 328 | 987 | 1,001 | |
Operating expenses | |||||
Purchased power and/or fuel from affiliates | 14 | 26 | 50 | 103 | |
Operating and maintenance | 43 | 44 | 127 | 137 | |
Operating and maintenance from affiliates | 37 | 38 | 113 | 119 | |
Depreciation and amortization | 46 | 47 | 138 | 135 | |
Taxes other than income | 15 | 15 | 43 | 43 | |
Total operating expenses | 268 | 277 | 820 | 859 | |
Operating income | 51 | 51 | 167 | 142 | |
Other income and (deductions) | |||||
Interest expense, net | (15) | (15) | (45) | (42) | |
Other, net | 2 | 2 | 10 | 7 | |
Total other income and (deductions) | (13) | (13) | (35) | (35) | |
Income before income taxes | 38 | 38 | 132 | 107 | |
Income taxes | 5 | 5 | 16 | 17 | |
Net income | 33 | 33 | 116 | 90 | |
Other comprehensive income (loss), net of income taxes | |||||
Comprehensive income | 33 | 33 | 116 | 90 | |
Atlantic City Electric Company [Member] | |||||
Operating revenues | |||||
Revenues from alternative revenue programs | 1 | (1) | 0 | (4) | |
Operating revenues from affiliates | 1 | 1 | 2 | 2 | |
Total operating revenues | 419 | 406 | 966 | 981 | |
Operating expenses | |||||
Purchased power and/or fuel from affiliates | 3 | 10 | 16 | 21 | |
Operating and maintenance | 54 | 52 | 142 | 146 | |
Operating and maintenance from affiliates | 32 | 33 | 99 | 104 | |
Depreciation and amortization | 43 | 38 | 114 | 107 | |
Taxes other than income | 1 | 1 | 4 | 4 | |
Total operating expenses | 340 | 322 | 838 | 847 | |
Operating income | 79 | 84 | 128 | 134 | |
Other income and (deductions) | |||||
Interest expense, net | (15) | (16) | (44) | (48) | |
Other, net | 1 | 1 | 5 | 2 | |
Total other income and (deductions) | (14) | (15) | (39) | (46) | |
Income before income taxes | 65 | 69 | 89 | 88 | |
Income taxes | 2 | 8 | 2 | 12 | |
Net income | 63 | 61 | 87 | 76 | |
Other comprehensive income (loss), net of income taxes | |||||
Comprehensive income | 63 | 61 | 87 | 76 | |
Generation commodities and services | |||||
Operating revenues | |||||
Revenue from Contract with Customer, Including Assessed Tax | 4,499 | 4,971 | 13,436 | 14,387 | |
Operating expenses | |||||
Purchased power and/or fuel | 2,648 | 2,977 | 8,142 | 8,542 | |
Generation commodities and services | Exelon Generation Co L L C [Member] | |||||
Operating revenues | |||||
Revenue from Contract with Customer, Including Assessed Tax | 4,499 | 4,970 | 13,436 | 14,389 | |
Operating expenses | |||||
Purchased power and/or fuel | 2,648 | 2,977 | 8,141 | 8,542 | |
Rate-regulated utility revenues | |||||
Operating revenues | |||||
Revenue from Contract with Customer, Including Assessed Tax | 4,510 | 4,457 | 12,758 | 12,824 | |
Operating expenses | |||||
Purchased power and/or fuel | 1,304 | 1,355 | 3,589 | 3,832 | |
Electricity, US Regulated | Commonwealth Edison Co [Member] | |||||
Operating revenues | |||||
Revenue from Contract with Customer, Including Assessed Tax | 1,635 | 1,609 | 4,427 | 4,512 | |
Operating expenses | |||||
Purchased power and/or fuel | 494 | 496 | 1,199 | 1,281 | |
Electricity, US Regulated | PECO Energy Co [Member] | |||||
Operating revenues | |||||
Revenue from Contract with Customer, Including Assessed Tax | 726 | 697 | 1,914 | 1,886 | |
Operating expenses | |||||
Purchased power and/or fuel | 185 | 215 | 461 | 576 | |
Electricity, US Regulated | Baltimore Gas and Electric Company [Member] | |||||
Operating revenues | |||||
Revenue from Contract with Customer, Including Assessed Tax | 623 | 652 | 1,814 | 1,847 | |
Operating expenses | |||||
Purchased power and/or fuel | 159 | 183 | 480 | 510 | |
Electricity, US Regulated | Pepco Holdings LLC [Member] | |||||
Operating revenues | |||||
Revenue from Contract with Customer, Including Assessed Tax | 1,365 | 1,340 | 3,570 | 3,541 | |
Operating expenses | |||||
Purchased power and/or fuel | 428 | 415 | 1,086 | 1,077 | |
Electricity, US Regulated | Potomac Electric Power Company [Member] | |||||
Operating revenues | |||||
Revenue from Contract with Customer, Including Assessed Tax | 643 | 630 | 1,733 | 1,697 | |
Operating expenses | |||||
Purchased power and/or fuel | 116 | 131 | 325 | 354 | |
Electricity, US Regulated | Delmarva Power and Light Company [Member] | |||||
Operating revenues | |||||
Revenue from Contract with Customer, Including Assessed Tax | 304 | 302 | 872 | 861 | |
Operating expenses | |||||
Purchased power and/or fuel | 105 | 96 | 298 | 258 | |
Electricity, US Regulated | Atlantic City Electric Company [Member] | |||||
Operating revenues | |||||
Revenue from Contract with Customer, Including Assessed Tax | 417 | 406 | 964 | 983 | |
Operating expenses | |||||
Purchased power and/or fuel | 207 | 188 | 463 | 465 | |
Natural Gas, US Regulated | PECO Energy Co [Member] | |||||
Operating revenues | |||||
Revenue from Contract with Customer, Including Assessed Tax | 62 | 57 | 431 | 382 | |
Operating expenses | |||||
Purchased power and/or fuel | 18 | 14 | 184 | 148 | |
Natural Gas, US Regulated | Baltimore Gas and Electric Company [Member] | |||||
Operating revenues | |||||
Revenue from Contract with Customer, Including Assessed Tax | 79 | 79 | 484 | 527 | |
Operating expenses | |||||
Purchased power and/or fuel | 12 | 21 | 128 | 176 | |
Natural Gas, US Regulated | Pepco Holdings LLC [Member] | |||||
Operating revenues | |||||
Revenue from Contract with Customer, Including Assessed Tax | 20 | 23 | 115 | 129 | |
Operating expenses | |||||
Purchased power and/or fuel | 8 | 12 | 51 | 65 | |
Natural Gas, US Regulated | Delmarva Power and Light Company [Member] | |||||
Operating revenues | |||||
Revenue from Contract with Customer, Including Assessed Tax | 20 | 24 | 116 | 129 | |
Operating expenses | |||||
Purchased power and/or fuel | $ 8 | $ 11 | $ 51 | $ 64 | |
[1] | The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was immaterial for the three and nine months ended September 30, 2019 and approximately 2 million and 3 million for the three and nine months ended September 30, 2018 , respectively. |
Consolidated Statements of Cash
Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions | 9 Months Ended | |
Sep. 30, 2019 | Sep. 30, 2018 | |
Cash flows from operating activities | ||
Net income | $ 2,220 | $ 1,979 |
Adjustments to reconcile net income to net cash flows provided by operating activities: | ||
Depreciation, amortization and accretion, including nuclear fuel and energy contract amortization | 4,393 | 4,511 |
Asset impairments | 174 | 49 |
Gain on sales of assets and businesses | (15) | (55) |
Deferred income taxes and amortization of investment tax credits | 412 | 97 |
Net fair value changes related to derivatives | 96 | 67 |
Net realized and unrealized gains on NDT funds | (467) | (21) |
Other non-cash operating activities | 460 | 804 |
Changes in assets and liabilities: | ||
Accounts receivable | 445 | (167) |
Inventories | (94) | (24) |
Accounts payable and accrued expenses | (671) | 84 |
Option premiums received (paid), net | 13 | (36) |
Collateral (posted) received, net | (254) | 222 |
Income taxes | 143 | 166 |
Pension and non-pension postretirement benefit contributions | (377) | (362) |
Other assets and liabilities | (1,079) | (639) |
Net cash flows provided by operating activities | 5,399 | 6,675 |
Cash flows from investing activities | ||
Capital expenditures | (5,259) | (5,497) |
Proceeds from NDT fund sales | 8,443 | 6,379 |
Investment in NDT funds | (8,437) | (6,553) |
Acquisition of assets and businesses, net | 0 | (57) |
Proceeds from sales of assets and businesses | 17 | 90 |
Other investing activities | 21 | 29 |
Net cash flows used in investing activities | (5,215) | (5,609) |
Cash flows from financing activities | ||
Changes in short-term borrowings | 430 | (218) |
Proceeds from short-term borrowings with maturities greater than 90 days | 0 | 126 |
Repayments on short-term borrowings with maturities greater than 90 days | (125) | (1) |
Issuance of long-term debt | 1,576 | 2,664 |
Retirement of long-term debt | (644) | (1,480) |
Dividends paid on common stock | (1,055) | (999) |
Proceeds from employee stock plans | 94 | 67 |
Other financing activities | (63) | (94) |
Net cash flows provided by (used in) financing activities | 213 | 65 |
Increase (Decrease) in cash, cash equivalents and restricted cash | 397 | 1,131 |
Cash, cash equivalents and restricted cash at beginning of period | 1,781 | 1,190 |
Cash, cash equivalents and restricted cash at end of period | 2,178 | 2,321 |
Supplemental Cash Flow Information | ||
Increase (decrease) in capital expenditures not paid | (96) | (175) |
Increase in PPE related to ARO update | 344 | 67 |
Exelon Generation Co L L C [Member] | ||
Cash flows from operating activities | ||
Net income | 784 | 667 |
Adjustments to reconcile net income to net cash flows provided by operating activities: | ||
Depreciation, amortization and accretion, including nuclear fuel and energy contract amortization | 2,377 | 2,608 |
Asset impairments | 174 | 49 |
Gain on sales of assets and businesses | (15) | (48) |
Deferred income taxes and amortization of investment tax credits | 201 | (278) |
Net fair value changes related to derivatives | 102 | 73 |
Net realized and unrealized gains on NDT funds | (467) | (21) |
Other non-cash operating activities | (95) | 187 |
Changes in assets and liabilities: | ||
Accounts receivable | 395 | 126 |
Receivables from and payables to affiliates, net | (12) | (7) |
Inventories | (36) | (10) |
Accounts payable and accrued expenses | (428) | (59) |
Option premiums received (paid), net | 13 | (36) |
Collateral (posted) received, net | (292) | 228 |
Income taxes | 327 | 220 |
Pension and non-pension postretirement benefit contributions | (165) | (134) |
Other assets and liabilities | (390) | (154) |
Net cash flows provided by operating activities | 2,473 | 3,411 |
Cash flows from investing activities | ||
Capital expenditures | (1,282) | (1,660) |
Proceeds from NDT fund sales | 8,443 | 6,379 |
Investment in NDT funds | (8,437) | (6,553) |
Acquisition of assets and businesses, net | 0 | (57) |
Proceeds from sales of assets and businesses | 17 | 90 |
Other investing activities | (6) | (5) |
Net cash flows used in investing activities | (1,265) | (1,806) |
Cash flows from financing activities | ||
Issuance of long-term debt | 41 | 14 |
Retirement of long-term debt | (196) | (100) |
Changes in Exelon/PHI intercompany money pool | (100) | (54) |
Distributions to member | (674) | (688) |
Contributions from member | 0 | 54 |
Other financing activities | (37) | (46) |
Net cash flows provided by (used in) financing activities | (966) | (820) |
Increase (Decrease) in cash, cash equivalents and restricted cash | 242 | 785 |
Cash, cash equivalents and restricted cash at beginning of period | 903 | 554 |
Cash, cash equivalents and restricted cash at end of period | 1,145 | 1,339 |
Supplemental Cash Flow Information | ||
Increase (decrease) in capital expenditures not paid | (24) | (226) |
Increase in PPE related to ARO update | 342 | 47 |
Commonwealth Edison Co [Member] | ||
Cash flows from operating activities | ||
Net income | 544 | 523 |
Adjustments to reconcile net income to net cash flows provided by operating activities: | ||
Depreciation, amortization and accretion, including nuclear fuel and energy contract amortization | 767 | 696 |
Deferred income taxes and amortization of investment tax credits | 115 | 214 |
Other non-cash operating activities | 180 | 187 |
Changes in assets and liabilities: | ||
Accounts receivable | (38) | (190) |
Receivables from and payables to affiliates, net | (27) | 8 |
Inventories | (16) | 4 |
Accounts payable and accrued expenses | (132) | (38) |
Collateral (posted) received, net | 43 | (10) |
Income taxes | 25 | (65) |
Pension and non-pension postretirement benefit contributions | (71) | (41) |
Other assets and liabilities | (245) | (170) |
Net cash flows provided by operating activities | 1,145 | 1,118 |
Cash flows from investing activities | ||
Capital expenditures | (1,413) | (1,540) |
Other investing activities | 25 | 22 |
Net cash flows used in investing activities | (1,388) | (1,518) |
Cash flows from financing activities | ||
Changes in short-term borrowings | 387 | 0 |
Issuance of long-term debt | 400 | 1,350 |
Retirement of long-term debt | (300) | (840) |
Contributions from parent | 187 | 387 |
Dividends paid on common stock | (380) | (345) |
Other financing activities | (10) | (16) |
Net cash flows provided by (used in) financing activities | 284 | 536 |
Increase (Decrease) in cash, cash equivalents and restricted cash | 41 | 136 |
Cash, cash equivalents and restricted cash at beginning of period | 330 | 144 |
Cash, cash equivalents and restricted cash at end of period | 371 | 280 |
Supplemental Cash Flow Information | ||
Increase (decrease) in capital expenditures not paid | (52) | (28) |
PECO Energy Co [Member] | ||
Cash flows from operating activities | ||
Net income | 410 | 336 |
Adjustments to reconcile net income to net cash flows provided by operating activities: | ||
Depreciation, amortization and accretion, including nuclear fuel and energy contract amortization | 247 | 224 |
Gain on sales of assets and businesses | 0 | (1) |
Deferred income taxes and amortization of investment tax credits | 6 | 5 |
Other non-cash operating activities | 28 | 41 |
Changes in assets and liabilities: | ||
Accounts receivable | 46 | (85) |
Receivables from and payables to affiliates, net | (12) | 1 |
Inventories | (3) | (13) |
Accounts payable and accrued expenses | (32) | (1) |
Income taxes | (15) | (16) |
Pension and non-pension postretirement benefit contributions | (26) | (25) |
Other assets and liabilities | (111) | 26 |
Net cash flows provided by operating activities | 538 | 492 |
Cash flows from investing activities | ||
Capital expenditures | (675) | (615) |
Other investing activities | 7 | 6 |
Net cash flows used in investing activities | (668) | (609) |
Cash flows from financing activities | ||
Issuance of long-term debt | 325 | 700 |
Retirement of long-term debt | 0 | (500) |
Contributions from parent | 174 | 71 |
Dividends paid on common stock | (268) | (300) |
Other financing activities | (6) | (22) |
Net cash flows provided by (used in) financing activities | 225 | (51) |
Increase (Decrease) in cash, cash equivalents and restricted cash | 95 | (168) |
Cash, cash equivalents and restricted cash at beginning of period | 135 | 275 |
Cash, cash equivalents and restricted cash at end of period | 230 | 107 |
Supplemental Cash Flow Information | ||
Increase (decrease) in capital expenditures not paid | 42 | 4 |
Baltimore Gas and Electric Company [Member] | ||
Cash flows from operating activities | ||
Net income | 261 | 242 |
Adjustments to reconcile net income to net cash flows provided by operating activities: | ||
Depreciation, amortization and accretion, including nuclear fuel and energy contract amortization | 368 | 358 |
Deferred income taxes and amortization of investment tax credits | 66 | 82 |
Other non-cash operating activities | 63 | 42 |
Changes in assets and liabilities: | ||
Accounts receivable | 110 | 72 |
Receivables from and payables to affiliates, net | (14) | (4) |
Inventories | (5) | (8) |
Accounts payable and accrued expenses | (28) | (3) |
Collateral (posted) received, net | (5) | 1 |
Income taxes | (43) | (48) |
Pension and non-pension postretirement benefit contributions | (45) | (50) |
Other assets and liabilities | (65) | (9) |
Net cash flows provided by operating activities | 663 | 675 |
Cash flows from investing activities | ||
Capital expenditures | (842) | (667) |
Other investing activities | 4 | 8 |
Net cash flows used in investing activities | (838) | (659) |
Cash flows from financing activities | ||
Changes in short-term borrowings | (35) | (77) |
Issuance of long-term debt | 400 | 300 |
Contributions from parent | 104 | 18 |
Dividends paid on common stock | (169) | (157) |
Other financing activities | (7) | (2) |
Net cash flows provided by (used in) financing activities | 293 | 82 |
Increase (Decrease) in cash, cash equivalents and restricted cash | 118 | 98 |
Cash, cash equivalents and restricted cash at beginning of period | 13 | 18 |
Cash, cash equivalents and restricted cash at end of period | 131 | 116 |
Supplemental Cash Flow Information | ||
Increase (decrease) in capital expenditures not paid | 6 | 44 |
Pepco Holdings LLC [Member] | ||
Cash flows from operating activities | ||
Net income | 412 | 336 |
Adjustments to reconcile net income to net cash flows provided by operating activities: | ||
Depreciation, amortization and accretion, including nuclear fuel and energy contract amortization | 562 | 555 |
Deferred income taxes and amortization of investment tax credits | 8 | 50 |
Other non-cash operating activities | 122 | 109 |
Changes in assets and liabilities: | ||
Accounts receivable | (64) | (89) |
Receivables from and payables to affiliates, net | 1 | 10 |
Inventories | (36) | 0 |
Accounts payable and accrued expenses | 0 | 115 |
Income taxes | (11) | (31) |
Pension and non-pension postretirement benefit contributions | (15) | (66) |
Other assets and liabilities | (102) | (144) |
Net cash flows provided by operating activities | 877 | 845 |
Cash flows from investing activities | ||
Capital expenditures | (1,006) | (988) |
Other investing activities | 3 | 2 |
Net cash flows used in investing activities | (1,003) | (986) |
Cash flows from financing activities | ||
Changes in short-term borrowings | 78 | (141) |
Proceeds from short-term borrowings with maturities greater than 90 days | 0 | 125 |
Repayments on short-term borrowings with maturities greater than 90 days | (125) | 0 |
Issuance of long-term debt | 410 | 300 |
Retirement of long-term debt | (130) | (33) |
Changes in Exelon/PHI intercompany money pool | 10 | 10 |
Distributions to member | (429) | (232) |
Contributions from member | 283 | 237 |
Other financing activities | (5) | (6) |
Net cash flows provided by (used in) financing activities | 92 | 260 |
Increase (Decrease) in cash, cash equivalents and restricted cash | (34) | 119 |
Cash, cash equivalents and restricted cash at beginning of period | 186 | 95 |
Cash, cash equivalents and restricted cash at end of period | 152 | 214 |
Supplemental Cash Flow Information | ||
Increase (decrease) in capital expenditures not paid | (62) | 54 |
Potomac Electric Power Company [Member] | ||
Cash flows from operating activities | ||
Net income | 217 | 174 |
Adjustments to reconcile net income to net cash flows provided by operating activities: | ||
Depreciation, amortization and accretion, including nuclear fuel and energy contract amortization | 281 | 286 |
Deferred income taxes and amortization of investment tax credits | 12 | (5) |
Other non-cash operating activities | 43 | 42 |
Changes in assets and liabilities: | ||
Accounts receivable | (49) | (36) |
Receivables from and payables to affiliates, net | 4 | (9) |
Inventories | (23) | 6 |
Accounts payable and accrued expenses | (12) | 104 |
Income taxes | (23) | (18) |
Pension and non-pension postretirement benefit contributions | (10) | (11) |
Other assets and liabilities | (55) | (137) |
Net cash flows provided by operating activities | 385 | 396 |
Cash flows from investing activities | ||
Capital expenditures | (455) | (475) |
Other investing activities | 2 | 3 |
Net cash flows used in investing activities | (453) | (472) |
Cash flows from financing activities | ||
Changes in short-term borrowings | (28) | 38 |
Issuance of long-term debt | 260 | 100 |
Retirement of long-term debt | (118) | (8) |
Contributions from parent | 129 | 85 |
Dividends paid on common stock | (173) | (128) |
Other financing activities | (3) | (4) |
Net cash flows provided by (used in) financing activities | 67 | 83 |
Increase (Decrease) in cash, cash equivalents and restricted cash | (1) | 7 |
Cash, cash equivalents and restricted cash at beginning of period | 53 | 40 |
Cash, cash equivalents and restricted cash at end of period | 52 | 47 |
Supplemental Cash Flow Information | ||
Increase (decrease) in capital expenditures not paid | (7) | 15 |
Delmarva Power and Light Company [Member] | ||
Cash flows from operating activities | ||
Net income | 116 | 90 |
Adjustments to reconcile net income to net cash flows provided by operating activities: | ||
Depreciation, amortization and accretion, including nuclear fuel and energy contract amortization | 138 | 135 |
Deferred income taxes and amortization of investment tax credits | (2) | 24 |
Other non-cash operating activities | 21 | 16 |
Changes in assets and liabilities: | ||
Accounts receivable | 29 | 13 |
Receivables from and payables to affiliates, net | (7) | (14) |
Inventories | (7) | (3) |
Accounts payable and accrued expenses | 3 | 18 |
Income taxes | 11 | 0 |
Pension and non-pension postretirement benefit contributions | (1) | 0 |
Other assets and liabilities | (22) | 13 |
Net cash flows provided by operating activities | 279 | 292 |
Cash flows from investing activities | ||
Capital expenditures | (245) | (254) |
Other investing activities | 1 | 1 |
Net cash flows used in investing activities | (244) | (253) |
Cash flows from financing activities | ||
Changes in short-term borrowings | 57 | (216) |
Issuance of long-term debt | 0 | 200 |
Retirement of long-term debt | 0 | (4) |
Contributions from parent | 0 | 150 |
Dividends paid on common stock | (105) | (58) |
Other financing activities | 0 | (3) |
Net cash flows provided by (used in) financing activities | (48) | 69 |
Increase (Decrease) in cash, cash equivalents and restricted cash | (13) | 108 |
Cash, cash equivalents and restricted cash at beginning of period | 24 | 2 |
Cash, cash equivalents and restricted cash at end of period | 11 | 110 |
Supplemental Cash Flow Information | ||
Increase (decrease) in capital expenditures not paid | (13) | 20 |
Atlantic City Electric Company [Member] | ||
Cash flows from operating activities | ||
Net income | 87 | 76 |
Adjustments to reconcile net income to net cash flows provided by operating activities: | ||
Depreciation, amortization and accretion, including nuclear fuel and energy contract amortization | 114 | 107 |
Deferred income taxes and amortization of investment tax credits | 2 | 24 |
Other non-cash operating activities | 21 | 24 |
Changes in assets and liabilities: | ||
Accounts receivable | (44) | (66) |
Receivables from and payables to affiliates, net | (4) | (3) |
Inventories | (4) | (2) |
Accounts payable and accrued expenses | 27 | 21 |
Income taxes | 5 | (3) |
Pension and non-pension postretirement benefit contributions | 0 | (6) |
Other assets and liabilities | (18) | (12) |
Net cash flows provided by operating activities | 186 | 160 |
Cash flows from investing activities | ||
Capital expenditures | (300) | (247) |
Other investing activities | 0 | (1) |
Net cash flows used in investing activities | (300) | (248) |
Cash flows from financing activities | ||
Changes in short-term borrowings | 49 | 37 |
Proceeds from short-term borrowings with maturities greater than 90 days | 0 | 125 |
Repayments on short-term borrowings with maturities greater than 90 days | (125) | 0 |
Issuance of long-term debt | 150 | 0 |
Retirement of long-term debt | (13) | (22) |
Contributions from parent | 155 | 0 |
Dividends paid on common stock | (100) | (46) |
Other financing activities | (1) | 0 |
Net cash flows provided by (used in) financing activities | 115 | 94 |
Increase (Decrease) in cash, cash equivalents and restricted cash | 1 | 6 |
Cash, cash equivalents and restricted cash at beginning of period | 30 | 31 |
Cash, cash equivalents and restricted cash at end of period | 31 | 37 |
Supplemental Cash Flow Information | ||
Increase (decrease) in capital expenditures not paid | $ (37) | $ 16 |
Consolidated Balance Sheets (Un
Consolidated Balance Sheets (Unaudited) - USD ($) $ in Millions | Sep. 30, 2019 | Dec. 31, 2018 | |
Current Assets | |||
Cash and cash equivalents | $ 1,683 | $ 1,349 | |
Restricted cash and cash equivalents | 309 | 247 | |
Accounts receivable, net | |||
Customer | 4,188 | 4,607 | |
Other | 1,085 | 1,256 | |
Mark-to-market derivative assets, current | 601 | 804 | |
Unamortized energy contract assets, current | 49 | 48 | |
Inventories, net | |||
Fossil fuel and emission allowances | 325 | 334 | |
Materials and supplies | 1,458 | 1,351 | |
Regulatory assets, current | 1,194 | 1,222 | |
Assets held for sale | 18 | 904 | |
Other | 1,296 | 1,238 | |
Total current assets | 12,206 | 13,360 | |
Property, plant and equipment, net | 78,593 | 76,707 | |
Deferred debits and other assets | |||
Regulatory assets, noncurrent | 8,122 | 8,237 | |
Nuclear decommissioning trust funds | 12,706 | 11,661 | |
Investments | 471 | 625 | |
Goodwill | 6,677 | 6,677 | |
Mark-to-market derivative assets, noncurrent | 487 | 452 | |
Unamortized energy contract assets, noncurrent | 353 | 372 | |
Other | 3,123 | 1,575 | |
Total deferred debits and other assets | 31,939 | 29,599 | |
Total assets | [1] | 122,738 | 119,666 |
Current Liabilities | |||
Short-term borrowings | 1,019 | 714 | |
Long-term debt due within one year | 4,248 | 1,349 | |
Accounts payable | 3,348 | 3,800 | |
Accrued expenses | 1,877 | 2,112 | |
Payable to affiliates, current | 5 | 5 | |
Regulatory liabilities, current | 400 | 644 | |
Mark-to-market derivative liabilities, current | 239 | 475 | |
Unamortized energy contract liabilities, current | 138 | 149 | |
Renewable energy credit obligation | 375 | 344 | |
Liabilities held for sale | 11 | 777 | |
Other | 1,425 | 1,035 | |
Total current liabilities | 13,085 | 11,404 | |
Long-term debt | 32,056 | 34,075 | |
Long-term debt to financing trusts | 390 | 390 | |
Deferred credits and other liabilities | |||
Deferred income taxes and unamortized investment tax credits | 12,133 | 11,330 | |
Asset retirement obligations, noncurrent | 10,089 | 9,679 | |
Pension obligations | 3,712 | 3,988 | |
Non-pension postretirement benefit obligations | 2,029 | 1,928 | |
Spent nuclear fuel obligation | 1,193 | 1,171 | |
Regulatory liabilities, noncurrent | 9,792 | 9,559 | |
Mark-to-market derivative liabilities, noncurrent | 416 | 479 | |
Unamortized energy contract liabilities, noncurrent | 368 | 463 | |
Other | 3,123 | 2,130 | |
Total deferred credits and other liabilities | 42,855 | 40,727 | |
Total liabilities | [1] | 88,386 | 86,596 |
Commitments and contingencies | |||
Shareholders' equity | |||
Common stock | 19,238 | 19,116 | |
Treasury stock, at cost | (123) | (123) | |
Retained earnings/Undistributed earnings | 15,871 | 14,766 | |
Accumulated other comprehensive loss, net | (2,963) | (2,995) | |
Total shareholders’ equity | 32,023 | 30,764 | |
Member’s equity | |||
Noncontrolling Interests | 2,329 | 2,306 | |
Total equity | 34,352 | 33,070 | |
Total liabilities and shareholders’ equity | 122,738 | 119,666 | |
Variable Interest Entity, Consolidated, Assets, Pledged | 9,465 | 9,667 | |
Variable Interest Entity, Consolidated, Liabilities, No Recourse | 3,517 | 3,548 | |
Exelon Generation Co L L C [Member] | |||
Current Assets | |||
Cash and cash equivalents | 1,019 | 750 | |
Restricted cash and cash equivalents | 126 | 153 | |
Accounts receivable, net | |||
Customer | 2,587 | 2,941 | |
Other | 337 | 562 | |
Mark-to-market derivative assets, current | 602 | 804 | |
Receivable from affiliates, current | 166 | 173 | |
Unamortized energy contract assets, current | 49 | 49 | |
Inventories, net | |||
Fossil fuel and emission allowances | 243 | 251 | |
Materials and supplies | 1,010 | 963 | |
Assets held for sale | 18 | 904 | |
Other | 1,002 | 883 | |
Total current assets | 7,159 | 8,433 | |
Property, plant and equipment, net | 23,591 | 23,981 | |
Deferred debits and other assets | |||
Nuclear decommissioning trust funds | 12,706 | 11,661 | |
Investments | 248 | 414 | |
Goodwill | 47 | 47 | |
Mark-to-market derivative assets, noncurrent | 483 | 452 | |
Prepaid pension asset | 1,472 | 1,421 | |
Unamortized energy contract assets, noncurrent | 352 | 371 | |
Deferred income taxes | 11 | 21 | |
Other | 1,915 | 755 | |
Total deferred debits and other assets | 17,234 | 15,142 | |
Total assets | [2] | 47,984 | 47,556 |
Current Liabilities | |||
Long-term debt due within one year | 2,706 | 906 | |
Accounts payable | 1,583 | 1,847 | |
Accrued expenses | 762 | 898 | |
Payable to affiliates, current | 134 | 139 | |
Borrowings from Exelon/PHI intercompany money pool | 0 | 100 | |
Mark-to-market derivative liabilities, current | 212 | 449 | |
Unamortized energy contract liabilities, current | 21 | 31 | |
Renewable energy credit obligation | 374 | 343 | |
Liabilities held for sale | 11 | 777 | |
Other | 541 | 279 | |
Total current liabilities | 6,344 | 5,769 | |
Long-term debt | 5,018 | 6,989 | |
Long-term debt to affiliates | 889 | 898 | |
Deferred credits and other liabilities | |||
Deferred income taxes and unamortized investment tax credits | 3,607 | 3,383 | |
Asset retirement obligations, noncurrent | 9,855 | 9,450 | |
Non-pension postretirement benefit obligations | 885 | 900 | |
Spent nuclear fuel obligation | 1,193 | 1,171 | |
Payables to affiliates, noncurrent | 2,960 | 2,606 | |
Mark-to-market derivative liabilities, noncurrent | 163 | 252 | |
Unamortized energy contract liabilities, noncurrent | 11 | 20 | |
Other | 1,466 | 610 | |
Total deferred credits and other liabilities | 20,140 | 18,392 | |
Total liabilities | [2] | 32,391 | 32,048 |
Commitments and contingencies | |||
Shareholders' equity | |||
Retained earnings/Undistributed earnings | 3,778 | 3,724 | |
Accumulated other comprehensive loss, net | (36) | (38) | |
Member’s equity | |||
Membership interest | 9,525 | 9,518 | |
Total members' equity | 13,267 | 13,204 | |
Noncontrolling Interests | 2,326 | 2,304 | |
Total equity | 15,593 | 15,508 | |
Total liabilities and shareholders’ equity | 47,984 | 47,556 | |
Variable Interest Entity, Consolidated, Assets, Pledged | 9,443 | 9,634 | |
Variable Interest Entity, Consolidated, Liabilities, No Recourse | 3,467 | 3,480 | |
Commonwealth Edison Co [Member] | |||
Current Assets | |||
Cash and cash equivalents | 76 | 135 | |
Restricted cash and cash equivalents | 124 | 29 | |
Accounts receivable, net | |||
Customer | 561 | 539 | |
Other | 322 | 320 | |
Receivable from affiliates, current | 27 | 20 | |
Inventories, net | |||
Inventories, net | 162 | 148 | |
Regulatory assets, current | 286 | 293 | |
Other | 48 | 86 | |
Total current assets | 1,606 | 1,570 | |
Property, plant and equipment, net | 22,795 | 22,058 | |
Deferred debits and other assets | |||
Regulatory assets, noncurrent | 1,436 | 1,307 | |
Investments | 6 | 6 | |
Goodwill | 2,625 | 2,625 | |
Receivable from affiliates, noncurrent | 2,487 | 2,217 | |
Prepaid pension asset | 1,020 | 1,035 | |
Other | 351 | 395 | |
Total deferred debits and other assets | 7,925 | 7,585 | |
Total assets | 32,326 | 31,213 | |
Current Liabilities | |||
Short-term borrowings | 387 | 0 | |
Long-term debt due within one year | 500 | 300 | |
Accounts payable | 520 | 607 | |
Accrued expenses | 275 | 373 | |
Payable to affiliates, current | 87 | 119 | |
Customer deposits | 116 | 111 | |
Regulatory liabilities, current | 193 | 293 | |
Mark-to-market derivative liabilities, current | 27 | 26 | |
Other | 138 | 96 | |
Total current liabilities | 2,243 | 1,925 | |
Long-term debt | 7,696 | 7,801 | |
Long-term debt to financing trusts | 205 | 205 | |
Deferred credits and other liabilities | |||
Deferred income taxes and unamortized investment tax credits | 4,016 | 3,813 | |
Asset retirement obligations, noncurrent | 120 | 118 | |
Non-pension postretirement benefit obligations | 185 | 201 | |
Regulatory liabilities, noncurrent | 6,390 | 6,050 | |
Mark-to-market derivative liabilities, noncurrent | 253 | 223 | |
Other | 621 | 630 | |
Total deferred credits and other liabilities | 11,585 | 11,035 | |
Total liabilities | 21,729 | 20,966 | |
Commitments and contingencies | |||
Shareholders' equity | |||
Common stock | 1,588 | 1,588 | |
Other paid-in capital | 7,509 | 7,322 | |
Retained deficit unappropriated | (1,639) | (1,639) | |
Retained earnings appropriated | 3,139 | 2,976 | |
Total shareholders’ equity | 10,597 | 10,247 | |
Member’s equity | |||
Total liabilities and shareholders’ equity | 32,326 | 31,213 | |
PECO Energy Co [Member] | |||
Current Assets | |||
Cash and cash equivalents | 224 | 130 | |
Restricted cash and cash equivalents | 6 | 5 | |
Accounts receivable, net | |||
Customer | 286 | 321 | |
Other | 118 | 151 | |
Receivable from affiliates, current | 7 | 0 | |
Inventories, net | |||
Fossil fuel and emission allowances | 41 | 38 | |
Materials and supplies | 37 | 37 | |
Prepaid utility taxes | 34 | 0 | |
Regulatory assets, current | 63 | 81 | |
Other | 27 | 19 | |
Total current assets | 843 | 782 | |
Property, plant and equipment, net | 9,100 | 8,610 | |
Deferred debits and other assets | |||
Regulatory assets, noncurrent | 540 | 460 | |
Investments | 26 | 25 | |
Receivable from affiliates, noncurrent | 473 | 389 | |
Prepaid pension asset | 367 | 349 | |
Other | 30 | 27 | |
Total deferred debits and other assets | 1,436 | 1,250 | |
Total assets | 11,379 | 10,642 | |
Current Liabilities | |||
Accounts payable | 382 | 370 | |
Accrued expenses | 97 | 113 | |
Payable to affiliates, current | 54 | 59 | |
Customer deposits | 69 | 68 | |
Regulatory liabilities, current | 93 | 175 | |
Other | 27 | 24 | |
Total current liabilities | 722 | 809 | |
Long-term debt | 3,404 | 3,084 | |
Long-term debt to financing trusts | 184 | 184 | |
Deferred credits and other liabilities | |||
Deferred income taxes and unamortized investment tax credits | 2,034 | 1,933 | |
Asset retirement obligations, noncurrent | 28 | 27 | |
Non-pension postretirement benefit obligations | 289 | 288 | |
Regulatory liabilities, noncurrent | 503 | 421 | |
Other | 79 | 76 | |
Total deferred credits and other liabilities | 2,933 | 2,745 | |
Total liabilities | 7,243 | 6,822 | |
Commitments and contingencies | |||
Shareholders' equity | |||
Common stock | 2,752 | 2,578 | |
Retained earnings/Undistributed earnings | 1,384 | 1,242 | |
Total shareholders’ equity | 4,136 | 3,820 | |
Member’s equity | |||
Total liabilities and shareholders’ equity | 11,379 | 10,642 | |
Baltimore Gas and Electric Company [Member] | |||
Current Assets | |||
Cash and cash equivalents | 130 | 7 | |
Restricted cash and cash equivalents | 1 | 6 | |
Accounts receivable, net | |||
Customer | 242 | 353 | |
Other | 110 | 90 | |
Receivable from affiliates, current | 1 | 1 | |
Inventories, net | |||
Fossil fuel and emission allowances | 34 | 36 | |
Materials and supplies | 46 | 39 | |
Prepaid utility taxes | 0 | 74 | |
Regulatory assets, current | 180 | 177 | |
Other | 7 | 3 | |
Total current assets | 751 | 786 | |
Property, plant and equipment, net | 8,796 | 8,243 | |
Deferred debits and other assets | |||
Regulatory assets, noncurrent | 386 | 398 | |
Investments | 7 | 5 | |
Prepaid pension asset | 276 | 279 | |
Other | 88 | 5 | |
Total deferred debits and other assets | 757 | 687 | |
Total assets | 10,304 | 9,716 | |
Current Liabilities | |||
Short-term borrowings | 0 | 35 | |
Accounts payable | 245 | 295 | |
Accrued expenses | 165 | 155 | |
Payable to affiliates, current | 51 | 65 | |
Customer deposits | 120 | 120 | |
Regulatory liabilities, current | 21 | 77 | |
Other | 63 | 27 | |
Total current liabilities | 665 | 774 | |
Long-term debt | 3,270 | 2,876 | |
Deferred credits and other liabilities | |||
Deferred income taxes and unamortized investment tax credits | 1,329 | 1,222 | |
Asset retirement obligations, noncurrent | 22 | 24 | |
Non-pension postretirement benefit obligations | 198 | 201 | |
Regulatory liabilities, noncurrent | 1,158 | 1,192 | |
Other | 112 | 73 | |
Total deferred credits and other liabilities | 2,819 | 2,712 | |
Total liabilities | 6,754 | 6,362 | |
Commitments and contingencies | |||
Shareholders' equity | |||
Common stock | 1,818 | 1,714 | |
Retained earnings/Undistributed earnings | 1,732 | 1,640 | |
Total shareholders’ equity | 3,550 | 3,354 | |
Member’s equity | |||
Total liabilities and shareholders’ equity | 10,304 | 9,716 | |
Pepco Holdings LLC [Member] | |||
Current Assets | |||
Cash and cash equivalents | 99 | 124 | |
Restricted cash and cash equivalents | 38 | 43 | |
Accounts receivable, net | |||
Customer | 512 | 453 | |
Other | 189 | 177 | |
Inventories, net | |||
Fossil fuel and emission allowances | 8 | 9 | |
Materials and supplies | 203 | 163 | |
Regulatory assets, current | 479 | 489 | |
Other | 50 | 75 | |
Total current assets | 1,578 | 1,533 | |
Property, plant and equipment, net | 13,968 | 13,446 | |
Deferred debits and other assets | |||
Regulatory assets, noncurrent | 2,095 | 2,312 | |
Investments | 135 | 130 | |
Goodwill | 4,005 | 4,005 | |
Prepaid pension asset | 426 | 486 | |
Deferred income taxes | 13 | 12 | |
Other | 356 | 60 | |
Total deferred debits and other assets | 7,030 | 7,005 | |
Total assets | [3] | 22,576 | 21,984 |
Current Liabilities | |||
Short-term borrowings | 132 | 179 | |
Long-term debt due within one year | 118 | 125 | |
Accounts payable | 416 | 496 | |
Accrued expenses | 279 | 256 | |
Payable to affiliates, current | 95 | 94 | |
Borrowings from Exelon/PHI intercompany money pool | 10 | 0 | |
Customer deposits | 118 | 116 | |
Regulatory liabilities, current | 78 | 84 | |
Unamortized energy contract liabilities, current | 117 | 119 | |
Other | 152 | 123 | |
Total current liabilities | 1,515 | 1,592 | |
Long-term debt | 6,376 | 6,134 | |
Deferred credits and other liabilities | |||
Deferred income taxes and unamortized investment tax credits | 2,289 | 2,146 | |
Asset retirement obligations, noncurrent | 57 | 52 | |
Non-pension postretirement benefit obligations | 99 | 103 | |
Regulatory liabilities, noncurrent | 1,725 | 1,864 | |
Unamortized energy contract liabilities, noncurrent | 357 | 442 | |
Other | 610 | 369 | |
Total deferred credits and other liabilities | 5,137 | 4,976 | |
Total liabilities | [3] | 13,028 | 12,702 |
Commitments and contingencies | |||
Shareholders' equity | |||
Retained earnings/Undistributed earnings | 45 | 62 | |
Member’s equity | |||
Membership interest | 9,503 | 9,220 | |
Total members' equity | 9,548 | 9,282 | |
Total equity | 9,548 | 9,282 | |
Total liabilities and shareholders’ equity | 22,576 | 21,984 | |
Variable Interest Entity, Consolidated, Assets, Pledged | 22 | 33 | |
Variable Interest Entity, Consolidated, Liabilities, No Recourse | 50 | 69 | |
Potomac Electric Power Company [Member] | |||
Current Assets | |||
Cash and cash equivalents | 18 | 16 | |
Restricted cash and cash equivalents | 34 | 37 | |
Accounts receivable, net | |||
Customer | 258 | 225 | |
Other | 114 | 81 | |
Receivable from affiliates, current | 0 | 1 | |
Inventories, net | |||
Inventories, net | 118 | 93 | |
Regulatory assets, current | 252 | 270 | |
Other | 12 | 37 | |
Total current assets | 806 | 760 | |
Property, plant and equipment, net | 6,734 | 6,460 | |
Deferred debits and other assets | |||
Regulatory assets, noncurrent | 577 | 643 | |
Investments | 109 | 105 | |
Prepaid pension asset | 301 | 316 | |
Other | 76 | 15 | |
Total deferred debits and other assets | 1,063 | 1,079 | |
Total assets | 8,603 | 8,299 | |
Current Liabilities | |||
Short-term borrowings | 12 | 40 | |
Long-term debt due within one year | 8 | 15 | |
Accounts payable | 177 | 214 | |
Accrued expenses | 144 | 126 | |
Payable to affiliates, current | 65 | 62 | |
Customer deposits | 56 | 54 | |
Regulatory liabilities, current | 9 | 7 | |
Merger related obligation | 38 | 38 | |
Current portion of DC PLUG obligation | 30 | 30 | |
Other | 25 | 42 | |
Total current liabilities | 564 | 628 | |
Long-term debt | 2,852 | 2,704 | |
Deferred credits and other liabilities | |||
Deferred income taxes and unamortized investment tax credits | 1,150 | 1,064 | |
Asset retirement obligations, noncurrent | 41 | 37 | |
Non-pension postretirement benefit obligations | 23 | 29 | |
Regulatory liabilities, noncurrent | 749 | 822 | |
Other | 311 | 275 | |
Total deferred credits and other liabilities | 2,274 | 2,227 | |
Total liabilities | 5,690 | 5,559 | |
Commitments and contingencies | |||
Shareholders' equity | |||
Common stock | 1,765 | 1,636 | |
Retained earnings/Undistributed earnings | 1,148 | 1,104 | |
Total shareholders’ equity | 2,913 | 2,740 | |
Member’s equity | |||
Total liabilities and shareholders’ equity | 8,603 | 8,299 | |
Delmarva Power and Light Company [Member] | |||
Current Assets | |||
Cash and cash equivalents | 11 | 23 | |
Restricted cash and cash equivalents | 0 | 1 | |
Accounts receivable, net | |||
Customer | 112 | 134 | |
Other | 37 | 46 | |
Inventories, net | |||
Fossil fuel and emission allowances | 8 | 9 | |
Materials and supplies | 47 | 37 | |
Prepaid utility taxes | 15 | 17 | |
Regulatory assets, current | 62 | 59 | |
Other | 5 | 10 | |
Total current assets | 297 | 336 | |
Property, plant and equipment, net | 3,941 | 3,821 | |
Deferred debits and other assets | |||
Regulatory assets, noncurrent | 221 | 231 | |
Goodwill | 8 | 8 | |
Prepaid pension asset | 175 | 186 | |
Other | 82 | 6 | |
Total deferred debits and other assets | 486 | 431 | |
Total assets | 4,724 | 4,588 | |
Current Liabilities | |||
Short-term borrowings | 57 | 0 | |
Long-term debt due within one year | 91 | 91 | |
Accounts payable | 90 | 111 | |
Accrued expenses | 59 | 39 | |
Payable to affiliates, current | 26 | 33 | |
Customer deposits | 36 | 35 | |
Regulatory liabilities, current | 43 | 59 | |
Other | 33 | 7 | |
Total current liabilities | 435 | 375 | |
Long-term debt | 1,404 | 1,403 | |
Deferred credits and other liabilities | |||
Deferred income taxes and unamortized investment tax credits | 655 | 628 | |
Non-pension postretirement benefit obligations | 16 | 17 | |
Regulatory liabilities, noncurrent | 580 | 606 | |
Other | 114 | 50 | |
Total deferred credits and other liabilities | 1,365 | 1,301 | |
Total liabilities | 3,204 | 3,079 | |
Commitments and contingencies | |||
Shareholders' equity | |||
Common stock | 914 | 914 | |
Retained earnings/Undistributed earnings | 606 | 595 | |
Total shareholders’ equity | 1,520 | 1,509 | |
Member’s equity | |||
Total liabilities and shareholders’ equity | 4,724 | 4,588 | |
Atlantic City Electric Company [Member] | |||
Current Assets | |||
Cash and cash equivalents | 13 | 7 | |
Restricted cash and cash equivalents | 3 | 4 | |
Accounts receivable, net | |||
Customer | 142 | 95 | |
Other | 47 | 55 | |
Receivable from affiliates, current | 1 | 1 | |
Inventories, net | |||
Inventories, net | 37 | 33 | |
Prepaid utility taxes | 9 | 0 | |
Regulatory assets, current | 48 | 40 | |
Other | 7 | 5 | |
Total current assets | 307 | 240 | |
Property, plant and equipment, net | 3,124 | 2,966 | |
Deferred debits and other assets | |||
Regulatory assets, noncurrent | 370 | 386 | |
Prepaid pension asset | 56 | 67 | |
Other | 59 | 40 | |
Total deferred debits and other assets | 485 | 493 | |
Total assets | [4] | 3,916 | 3,699 |
Current Liabilities | |||
Short-term borrowings | 63 | 139 | |
Long-term debt due within one year | 19 | 18 | |
Accounts payable | 139 | 154 | |
Accrued expenses | 40 | 35 | |
Payable to affiliates, current | 24 | 28 | |
Customer deposits | 26 | 26 | |
Regulatory liabilities, current | 25 | 18 | |
Other | 11 | 4 | |
Total current liabilities | 347 | 422 | |
Long-term debt | 1,305 | 1,170 | |
Deferred credits and other liabilities | |||
Deferred income taxes and unamortized investment tax credits | 569 | 535 | |
Non-pension postretirement benefit obligations | 18 | 17 | |
Regulatory liabilities, noncurrent | 365 | 402 | |
Other | 44 | 27 | |
Total deferred credits and other liabilities | 996 | 981 | |
Total liabilities | [4] | 2,648 | 2,573 |
Commitments and contingencies | |||
Shareholders' equity | |||
Common stock | 1,134 | 979 | |
Retained earnings/Undistributed earnings | 134 | 147 | |
Total shareholders’ equity | 1,268 | 1,126 | |
Member’s equity | |||
Total liabilities and shareholders’ equity | 3,916 | 3,699 | |
Variable Interest Entity, Consolidated, Assets, Pledged | 18 | 23 | |
Variable Interest Entity, Consolidated, Liabilities, No Recourse | $ 46 | $ 59 | |
[1] | Exelon’s consolidated assets include $9,465 million and $9,667 million at September 30, 2019 and December 31, 2018 , respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Exelon’s consolidated liabilities include $3,517 million and $3,548 million at September 30, 2019 and December 31, 2018 , respectively, of certain VIEs for which the VIE creditors do not have recourse to Exelon. See Note 2 — Variable Interest Entities for additional information. | ||
[2] | Generation’s consolidated assets include $9,443 million and $9,634 million at September 30, 2019 and December 31, 2018 , respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Generation’s consolidated liabilities include $3,467 million and $3,480 million at September 30, 2019 and December 31, 2018 , respectively, of certain VIEs for which the VIE creditors do not have recourse to Generation. See Note 2 — Variable Interest Entities for additional information. | ||
[3] | PHI’s consolidated total assets include $22 million and $33 million at September 30, 2019 and December 31, 2018 , respectively, of PHI's consolidated VIE that can only be used to settle the liabilities of the VIE. PHI’s consolidated total liabilities include $50 million and $69 million at September 30, 2019 and December 31, 2018 , respectively, of PHI's consolidated VIE for which the VIE creditors do not have recourse to PHI. See Note 2 — Variable Interest Entities for additional information. | ||
[4] | ACE’s consolidated total assets include $18 million and $23 million at September 30, 2019 and December 31, 2018 , respectively, of ACE's consolidated VIE that can only be used to settle the liabilities of the VIE. ACE’s consolidated total liabilities include $46 million and $59 million at September 30, 2019 and December 31, 2018 , respectively, of ACE's consolidated VIE for which the VIE creditors do not have recourse to ACE. See Note 2 — Variable Interest Entities for additional information. |
Consolidated Balance Sheets (_2
Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) shares in Millions, $ in Millions | Sep. 30, 2019 | Dec. 31, 2018 |
Customer allowance for uncollectible accounts | $ 248 | $ 283 |
Other allowance for uncollectible accounts | 49 | 36 |
Accumulated depreciation and amortization | $ 23,590 | $ 22,902 |
Common Stock, Shares Authorized | 2,000 | 2,000 |
Common Stock, Shares, Outstanding | 972 | 968 |
Treasury Stock, Shares held | 2 | 2 |
Exelon Generation Co L L C [Member] | ||
Customer allowance for uncollectible accounts | $ 75 | $ 103 |
Other allowance for uncollectible accounts | 1 | 1 |
Accumulated depreciation and amortization | 11,972 | 12,206 |
Commonwealth Edison Co [Member] | ||
Customer allowance for uncollectible accounts | 65 | 61 |
Other allowance for uncollectible accounts | 21 | 20 |
Accumulated depreciation and amortization | 5,046 | 4,684 |
PECO Energy Co [Member] | ||
Customer allowance for uncollectible accounts | 54 | 53 |
Other allowance for uncollectible accounts | 7 | 8 |
Accumulated depreciation and amortization | 3,670 | 3,561 |
Baltimore Gas and Electric Company [Member] | ||
Customer allowance for uncollectible accounts | 13 | 16 |
Other allowance for uncollectible accounts | 4 | 4 |
Accumulated depreciation and amortization | 3,772 | 3,633 |
Pepco Holdings LLC [Member] | ||
Customer allowance for uncollectible accounts | 41 | 50 |
Other allowance for uncollectible accounts | 16 | 3 |
Accumulated depreciation and amortization | 1,124 | 841 |
Potomac Electric Power Company [Member] | ||
Customer allowance for uncollectible accounts | 16 | 20 |
Other allowance for uncollectible accounts | 8 | 1 |
Accumulated depreciation and amortization | 3,473 | 3,354 |
Delmarva Power and Light Company [Member] | ||
Customer allowance for uncollectible accounts | 10 | 12 |
Other allowance for uncollectible accounts | 1 | 1 |
Accumulated depreciation and amortization | 1,407 | 1,329 |
Atlantic City Electric Company [Member] | ||
Customer allowance for uncollectible accounts | 15 | 18 |
Other allowance for uncollectible accounts | 5 | 1 |
Accumulated depreciation and amortization | $ 1,192 | $ 1,137 |
Consolidated Statements of Chan
Consolidated Statements of Changes in Shareholders Equity (Unaudited) - USD ($) shares in Thousands, $ in Millions | Total | Common Stock [Member] | Treasury Stock [Member] | Retained Earnings [Member] | Accumulated Other Comprehensive Income (Loss) [Member] | Noncontrolling Interest [Member] | Other Comprehensive Income (Loss) [Member] | Exelon Generation Co L L C [Member] | Exelon Generation Co L L C [Member]Membership Interest [Member] | Exelon Generation Co L L C [Member]Retained Earnings, Unappropriated/Undistributed [Member] | Exelon Generation Co L L C [Member]Accumulated Other Comprehensive Income (Loss) [Member] | Exelon Generation Co L L C [Member]Noncontrolling Interest [Member] | Commonwealth Edison Co [Member] | Commonwealth Edison Co [Member]Common Stock [Member] | Commonwealth Edison Co [Member]Other Paid-in-Capital [Member] | Commonwealth Edison Co [Member]Retained Earnings, Unappropriated/Undistributed [Member] | Commonwealth Edison Co [Member]Retained Earnings, Appropriated | Commonwealth Edison Co [Member]Retained Earnings [Member] | PECO Energy Co [Member] | PECO Energy Co [Member]Common Stock [Member] | PECO Energy Co [Member]Retained Earnings [Member] | PECO Energy Co [Member]Accumulated Other Comprehensive Income (Loss) [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]Membership Interest [Member] | Pepco Holdings LLC [Member]Retained Earnings, Unappropriated/Undistributed [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, 2017 | 965,168 | ||||||||||||||||||||||||||||||||||||
Beginning balance at Dec. 31, 2017 | $ 32,187 | $ 18,964 | $ (123) | $ 14,081 | $ (3,026) | $ 2,291 | |||||||||||||||||||||||||||||||
Beginning Balance at Dec. 31, 2017 | $ 15,959 | $ 9,357 | $ 4,349 | $ (37) | $ 2,290 | $ 8,825 | $ 8,835 | $ (10) | |||||||||||||||||||||||||||||
Beginning Balance at Dec. 31, 2017 | $ 9,542 | $ 1,588 | $ 6,822 | $ (1,639) | $ 2,771 | $ 3,577 | $ 2,489 | $ 1,087 | $ 1 | $ 3,141 | $ 1,605 | $ 1,536 | $ 2,533 | $ 1,470 | $ 1,063 | $ 1,335 | $ 764 | $ 571 | $ 1,043 | $ 912 | $ 131 | ||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||
Net income | $ 636 | 585 | 51 | 186 | 136 | 50 | 165 | 165 | 113 | 113 | 0 | 128 | 128 | 65 | 65 | 31 | 31 | 31 | 31 | 7 | 7 | ||||||||||||||||
Stock issued during period, shares, long-term incentive plan activity | 1,685 | ||||||||||||||||||||||||||||||||||||
Stock issued during period, value, long-term incentive plan activity | $ (3) | (3) | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||
Stock issued during period, shares, employee stock purchase plan | 361 | ||||||||||||||||||||||||||||||||||||
Stock issued during period, value, employee stock purchase plan | $ 12 | 12 | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||
Changes in equity of noncontrolling interests | (9) | (9) | (9) | (9) | |||||||||||||||||||||||||||||||||
Common stock dividends | (334) | (334) | (114) | (114) | (287) | (287) | (52) | (52) | (25) | (25) | (36) | (36) | (9) | (9) | |||||||||||||||||||||||
Contributions from parent | 113 | 113 | |||||||||||||||||||||||||||||||||||
Distributions to member | (188) | (188) | (71) | (71) | |||||||||||||||||||||||||||||||||
Other comprehensive income (loss), net of income taxes | 71 | 1 | $ 72 | 7 | 0 | 6 | 1 | ||||||||||||||||||||||||||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | $ 4 | 14 | (10) | 3 | 6 | (3) | 0 | 1 | (1) | ||||||||||||||||||||||||||||
Ending balance (in shares) at Mar. 31, 2018 | 967,214 | ||||||||||||||||||||||||||||||||||||
Ending balance at Mar. 31, 2018 | $ 32,565 | 18,973 | (123) | 14,346 | (2,965) | 2,334 | |||||||||||||||||||||||||||||||
Ending Balance at Mar. 31, 2018 | 15,958 | 9,357 | 4,303 | (34) | 2,332 | 8,819 | 8,835 | (16) | |||||||||||||||||||||||||||||
Ending Balance at Mar. 31, 2018 | 9,706 | 1,588 | 6,935 | (1,639) | 2,822 | 3,403 | 2,489 | 914 | 0 | 3,217 | 1,605 | 1,612 | 2,539 | 1,470 | 1,069 | 1,330 | 764 | 566 | 1,041 | 912 | 129 | ||||||||||||||||
Beginning balance (in shares) at Dec. 31, 2017 | 965,168 | ||||||||||||||||||||||||||||||||||||
Beginning balance at Dec. 31, 2017 | $ 32,187 | 18,964 | (123) | 14,081 | (3,026) | 2,291 | |||||||||||||||||||||||||||||||
Beginning Balance at Dec. 31, 2017 | 15,959 | 9,357 | 4,349 | (37) | 2,290 | 8,825 | 8,835 | (10) | |||||||||||||||||||||||||||||
Beginning Balance at Dec. 31, 2017 | 9,542 | 1,588 | 6,822 | (1,639) | 2,771 | 3,577 | 2,489 | 1,087 | 1 | 3,141 | 1,605 | 1,536 | 2,533 | 1,470 | 1,063 | 1,335 | 764 | 571 | 1,043 | 912 | 131 | ||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||
Net income | 1,979 | 667 | 523 | 336 | 242 | 336 | 174 | 90 | 76 | ||||||||||||||||||||||||||||
Other comprehensive income (loss), net of income taxes | $ 169 | 167 | 11 | ||||||||||||||||||||||||||||||||||
Ending balance (in shares) at Sep. 30, 2018 | 968,842 | ||||||||||||||||||||||||||||||||||||
Ending balance at Sep. 30, 2018 | $ 33,388 | 19,063 | (123) | 14,949 | (2,869) | 2,368 | |||||||||||||||||||||||||||||||
Ending Balance at Sep. 30, 2018 | 15,960 | 9,411 | 4,214 | (31) | 2,366 | 9,166 | 9,072 | 94 | |||||||||||||||||||||||||||||
Ending Balance at Sep. 30, 2018 | 10,107 | 1,588 | 7,209 | (1,639) | 2,949 | 3,684 | 2,560 | 1,124 | 0 | 3,244 | 1,623 | 1,621 | 2,664 | 1,555 | 1,109 | 1,517 | 914 | 603 | 1,073 | 912 | 161 | ||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||
Appropriation of retained earnings for future dividends | (165) | 165 | $ 0 | ||||||||||||||||||||||||||||||||||
Beginning balance (in shares) at Mar. 31, 2018 | 967,214 | ||||||||||||||||||||||||||||||||||||
Beginning balance at Mar. 31, 2018 | $ 32,565 | 18,973 | (123) | 14,346 | (2,965) | 2,334 | |||||||||||||||||||||||||||||||
Beginning Balance at Mar. 31, 2018 | 15,958 | 9,357 | 4,303 | (34) | 2,332 | 8,819 | 8,835 | (16) | |||||||||||||||||||||||||||||
Beginning Balance at Mar. 31, 2018 | 9,706 | 1,588 | 6,935 | (1,639) | 2,822 | 3,403 | 2,489 | 914 | 0 | 3,217 | 1,605 | 1,612 | 2,539 | 1,470 | 1,069 | 1,330 | 764 | 566 | 1,041 | 912 | 129 | ||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||
Net income | $ 542 | 539 | 3 | 181 | 178 | 3 | 164 | 164 | 96 | 96 | 0 | 51 | 51 | 84 | 84 | 54 | 54 | 26 | 26 | 8 | 8 | ||||||||||||||||
Stock issued during period, shares, long-term incentive plan activity | 183 | ||||||||||||||||||||||||||||||||||||
Stock issued during period, value, long-term incentive plan activity | $ 20 | 20 | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||
Stock issued during period, shares, employee stock purchase plan | 342 | ||||||||||||||||||||||||||||||||||||
Stock issued during period, value, employee stock purchase plan | $ 15 | 15 | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||
Changes in equity of noncontrolling interests | (14) | (14) | (13) | (13) | |||||||||||||||||||||||||||||||||
Common stock dividends | $ (334) | (334) | (115) | (115) | (5) | (5) | (53) | (53) | (25) | (25) | (4) | (4) | (10) | (10) | |||||||||||||||||||||||
Contributions from parent | 112 | 112 | 41 | 41 | 0 | 0 | 235 | 235 | 85 | 85 | 150 | 150 | |||||||||||||||||||||||||
Distributions to member | (189) | (189) | (38) | (38) | |||||||||||||||||||||||||||||||||
Other comprehensive income (loss), net of income taxes | 44 | 1 | 45 | 2 | 0 | 1 | 1 | ||||||||||||||||||||||||||||||
Ending balance (in shares) at Jun. 30, 2018 | 967,739 | ||||||||||||||||||||||||||||||||||||
Ending balance at Jun. 30, 2018 | $ 32,839 | 19,008 | (123) | 14,551 | (2,921) | 2,324 | |||||||||||||||||||||||||||||||
Ending Balance at Jun. 30, 2018 | 15,939 | 9,357 | 4,292 | (33) | 2,323 | 9,100 | 9,070 | 30 | |||||||||||||||||||||||||||||
Ending Balance at Jun. 30, 2018 | 9,867 | 1,588 | 7,047 | (1,639) | 2,871 | 3,535 | 2,530 | 1,005 | 0 | 3,215 | 1,605 | 1,610 | 2,653 | 1,555 | 1,098 | 1,502 | 914 | 588 | 1,039 | 912 | 127 | ||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||
Appropriation of retained earnings for future dividends | (164) | 164 | 0 | ||||||||||||||||||||||||||||||||||
Net income | $ 800 | 733 | 67 | 300 | 234 | 66 | 193 | 193 | 126 | 126 | 0 | 63 | 63 | 187 | 187 | 89 | 89 | 33 | 33 | 61 | 61 | ||||||||||||||||
Stock issued during period, shares, long-term incentive plan activity | 809 | ||||||||||||||||||||||||||||||||||||
Stock issued during period, value, long-term incentive plan activity | $ 15 | 15 | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||
Stock issued during period, shares, employee stock purchase plan | 294 | ||||||||||||||||||||||||||||||||||||
Stock issued during period, value, employee stock purchase plan | $ 40 | 40 | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||
Changes in equity of noncontrolling interests | (23) | (23) | (23) | (23) | |||||||||||||||||||||||||||||||||
Common stock dividends | (335) | (335) | (115) | (115) | (7) | (7) | (52) | (52) | (78) | (78) | (18) | (18) | (27) | (27) | |||||||||||||||||||||||
Contributions from parent | 54 | 54 | 162 | 162 | 30 | 30 | 0 | 0 | 18 | 18 | 0 | 2 | 2 | ||||||||||||||||||||||||
Distributions to member | (312) | (312) | (123) | (123) | |||||||||||||||||||||||||||||||||
Other comprehensive income (loss), net of income taxes | $ 52 | 52 | 0 | 52 | 2 | 0 | 2 | 0 | |||||||||||||||||||||||||||||
Ending balance (in shares) at Sep. 30, 2018 | 968,842 | ||||||||||||||||||||||||||||||||||||
Ending balance at Sep. 30, 2018 | $ 33,388 | 19,063 | (123) | 14,949 | (2,869) | 2,368 | |||||||||||||||||||||||||||||||
Ending Balance at Sep. 30, 2018 | 15,960 | 9,411 | 4,214 | (31) | 2,366 | 9,166 | 9,072 | 94 | |||||||||||||||||||||||||||||
Ending Balance at Sep. 30, 2018 | 10,107 | 1,588 | 7,209 | (1,639) | 2,949 | 3,684 | 2,560 | 1,124 | 0 | 3,244 | 1,623 | 1,621 | 2,664 | 1,555 | 1,109 | 1,517 | 914 | 603 | 1,073 | 912 | 161 | ||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||
Appropriation of retained earnings for future dividends | (193) | 193 | 0 | ||||||||||||||||||||||||||||||||||
Appropriation of retained earnings for future dividends | 2,976 | ||||||||||||||||||||||||||||||||||||
Beginning balance (in shares) at Dec. 31, 2018 | 970,020 | ||||||||||||||||||||||||||||||||||||
Beginning balance at Dec. 31, 2018 | $ 33,070 | 19,116 | (123) | 14,766 | (2,995) | 2,306 | |||||||||||||||||||||||||||||||
Beginning Balance at Dec. 31, 2018 | 15,508 | 9,518 | 3,724 | (38) | 2,304 | 9,282 | 9,220 | 62 | |||||||||||||||||||||||||||||
Beginning Balance at Dec. 31, 2018 | 30,764 | 10,247 | 1,588 | 7,322 | (1,639) | 2,976 | 3,820 | 2,578 | 1,242 | 0 | 3,354 | 1,714 | 1,640 | 2,740 | 1,636 | 1,104 | 1,509 | 914 | 595 | 1,126 | 979 | 147 | |||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||
Net income | $ 966 | 907 | 59 | 422 | 363 | 59 | 157 | 157 | 168 | 168 | 0 | 160 | 160 | 117 | 117 | 55 | 55 | 53 | 53 | 10 | 10 | ||||||||||||||||
Stock issued during period, shares, long-term incentive plan activity | 2,446 | ||||||||||||||||||||||||||||||||||||
Stock issued during period, value, long-term incentive plan activity | $ (3) | (3) | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||
Stock issued during period, shares, employee stock purchase plan | 320 | ||||||||||||||||||||||||||||||||||||
Stock issued during period, value, employee stock purchase plan | $ 51 | 51 | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||
Changes in equity of noncontrolling interests | (17) | (17) | (17) | (17) | |||||||||||||||||||||||||||||||||
Sale of noncontrolling interests | 7 | 7 | 7 | 7 | |||||||||||||||||||||||||||||||||
Common stock dividends | $ (352) | (352) | (127) | (127) | (90) | (90) | (56) | (56) | (24) | (24) | (41) | (41) | (12) | (12) | |||||||||||||||||||||||
Contributions from parent | 63 | 63 | 145 | 145 | 0 | 0 | 19 | 19 | 14 | 14 | 5 | 5 | |||||||||||||||||||||||||
Distributions to member | (225) | (225) | (128) | (128) | |||||||||||||||||||||||||||||||||
Other comprehensive income (loss), net of income taxes | (17) | (1) | (18) | 1 | 0 | 2 | (1) | ||||||||||||||||||||||||||||||
Ending balance (in shares) at Mar. 31, 2019 | 972,786 | ||||||||||||||||||||||||||||||||||||
Ending balance at Mar. 31, 2019 | $ 33,704 | 19,171 | (123) | 15,321 | (3,012) | 2,347 | |||||||||||||||||||||||||||||||
Ending Balance at Mar. 31, 2019 | 15,696 | 9,525 | 3,862 | (36) | 2,345 | 9,290 | 9,239 | 51 | |||||||||||||||||||||||||||||
Ending Balance at Mar. 31, 2019 | 10,340 | 1,588 | 7,385 | (1,639) | 3,006 | 4,043 | 2,723 | 1,320 | 0 | 3,458 | 1,714 | 1,744 | 2,785 | 1,650 | 1,135 | 1,521 | 914 | 607 | 1,129 | 984 | 145 | ||||||||||||||||
Beginning balance (in shares) at Dec. 31, 2018 | 970,020 | ||||||||||||||||||||||||||||||||||||
Beginning balance at Dec. 31, 2018 | $ 33,070 | 19,116 | (123) | 14,766 | (2,995) | 2,306 | |||||||||||||||||||||||||||||||
Beginning Balance at Dec. 31, 2018 | 15,508 | 9,518 | 3,724 | (38) | 2,304 | 9,282 | 9,220 | 62 | |||||||||||||||||||||||||||||
Beginning Balance at Dec. 31, 2018 | 30,764 | 10,247 | 1,588 | 7,322 | (1,639) | 2,976 | 3,820 | 2,578 | 1,242 | 0 | 3,354 | 1,714 | 1,640 | 2,740 | 1,636 | 1,104 | 1,509 | 914 | 595 | 1,126 | 979 | 147 | |||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||
Net income | 2,220 | 784 | 544 | 410 | 261 | 412 | 217 | 116 | 87 | ||||||||||||||||||||||||||||
Other comprehensive income (loss), net of income taxes | $ 33 | 32 | 3 | ||||||||||||||||||||||||||||||||||
Ending balance (in shares) at Sep. 30, 2019 | 973,941 | ||||||||||||||||||||||||||||||||||||
Ending balance at Sep. 30, 2019 | $ 34,352 | 19,238 | (123) | 15,871 | (2,963) | 2,329 | |||||||||||||||||||||||||||||||
Ending Balance at Sep. 30, 2019 | 15,593 | 9,525 | 3,778 | (36) | 2,326 | 9,548 | 9,503 | 45 | |||||||||||||||||||||||||||||
Ending Balance at Sep. 30, 2019 | $ 32,023 | 10,597 | 1,588 | 7,509 | (1,639) | 3,139 | 4,136 | 2,752 | 1,384 | 0 | 3,550 | 1,818 | 1,732 | 2,913 | 1,765 | 1,148 | 1,520 | 914 | 606 | 1,268 | 1,134 | 134 | |||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||
Appropriation of retained earnings for future dividends | (157) | 157 | 0 | ||||||||||||||||||||||||||||||||||
Beginning balance (in shares) at Mar. 31, 2019 | 972,786 | ||||||||||||||||||||||||||||||||||||
Beginning balance at Mar. 31, 2019 | $ 33,704 | 19,171 | (123) | 15,321 | (3,012) | 2,347 | |||||||||||||||||||||||||||||||
Beginning Balance at Mar. 31, 2019 | 15,696 | 9,525 | 3,862 | (36) | 2,345 | 9,290 | 9,239 | 51 | |||||||||||||||||||||||||||||
Beginning Balance at Mar. 31, 2019 | 10,340 | 1,588 | 7,385 | (1,639) | 3,006 | 4,043 | 2,723 | 1,320 | 0 | 3,458 | 1,714 | 1,744 | 2,785 | 1,650 | 1,135 | 1,521 | 914 | 607 | 1,129 | 984 | 145 | ||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||
Net income | $ 494 | 484 | 10 | 118 | 108 | 10 | 186 | 186 | 102 | 102 | 0 | 45 | 45 | 106 | 106 | 64 | 64 | 30 | 30 | 14 | 14 | ||||||||||||||||
Stock issued during period, shares, long-term incentive plan activity | 320 | ||||||||||||||||||||||||||||||||||||
Stock issued during period, value, long-term incentive plan activity | $ 14 | 14 | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||
Stock issued during period, shares, employee stock purchase plan | 311 | ||||||||||||||||||||||||||||||||||||
Stock issued during period, value, employee stock purchase plan | $ 24 | 24 | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||
Changes in equity of noncontrolling interests | 3 | 3 | 3 | 3 | |||||||||||||||||||||||||||||||||
Common stock dividends | $ (353) | (353) | (127) | (127) | (90) | (90) | (55) | (55) | (48) | (48) | (29) | (29) | (12) | (12) | |||||||||||||||||||||||
Contributions from parent | 61 | 61 | 264 | 264 | 115 | 115 | 150 | 150 | |||||||||||||||||||||||||||||
Distributions to member | (224) | (224) | (88) | (88) | |||||||||||||||||||||||||||||||||
Other comprehensive income (loss), net of income taxes | 22 | (1) | 21 | (1) | 0 | 0 | (1) | ||||||||||||||||||||||||||||||
Ending balance (in shares) at Jun. 30, 2019 | 973,417 | ||||||||||||||||||||||||||||||||||||
Ending balance at Jun. 30, 2019 | $ 33,907 | 19,209 | (123) | 15,452 | (2,990) | 2,359 | |||||||||||||||||||||||||||||||
Ending Balance at Jun. 30, 2019 | 15,592 | 9,525 | 3,746 | (36) | 2,357 | 9,572 | 9,503 | 69 | |||||||||||||||||||||||||||||
Ending Balance at Jun. 30, 2019 | 10,460 | 1,588 | 7,446 | (1,639) | 3,065 | 4,055 | 2,723 | 1,332 | 0 | 3,448 | 1,714 | 1,734 | 2,916 | 1,765 | 1,151 | 1,522 | 914 | 608 | 1,281 | 1,134 | 147 | ||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||
Appropriation of retained earnings for future dividends | (186) | 186 | 0 | ||||||||||||||||||||||||||||||||||
Net income | $ 760 | 772 | (12) | 244 | 257 | (13) | 200 | 200 | 140 | 140 | 0 | 55 | 55 | 189 | 189 | 98 | 98 | 33 | 33 | 63 | 63 | ||||||||||||||||
Stock issued during period, shares, long-term incentive plan activity | 207 | ||||||||||||||||||||||||||||||||||||
Stock issued during period, value, long-term incentive plan activity | $ 10 | 10 | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||
Stock issued during period, shares, employee stock purchase plan | 317 | ||||||||||||||||||||||||||||||||||||
Stock issued during period, value, employee stock purchase plan | $ 19 | 19 | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||
Changes in equity of noncontrolling interests | (18) | (18) | (18) | (18) | |||||||||||||||||||||||||||||||||
Sale of noncontrolling interests | 0 | ||||||||||||||||||||||||||||||||||||
Common stock dividends | (353) | (353) | (126) | (126) | (88) | (88) | (57) | (57) | (101) | (101) | (35) | (35) | (76) | (76) | |||||||||||||||||||||||
Contributions from parent | 63 | 63 | 29 | 29 | 0 | 0 | 104 | 104 | 0 | ||||||||||||||||||||||||||||
Distributions to member | (225) | (225) | (213) | 213 | |||||||||||||||||||||||||||||||||
Other comprehensive income (loss), net of income taxes | $ 30 | 27 | 0 | $ 27 | 3 | ||||||||||||||||||||||||||||||||
Ending balance (in shares) at Sep. 30, 2019 | 973,941 | ||||||||||||||||||||||||||||||||||||
Ending balance at Sep. 30, 2019 | $ 34,352 | $ 19,238 | $ (123) | $ 15,871 | $ (2,963) | $ 2,329 | |||||||||||||||||||||||||||||||
Ending Balance at Sep. 30, 2019 | $ 15,593 | $ 9,525 | $ 3,778 | $ (36) | $ 2,326 | $ 9,548 | $ 9,503 | $ 45 | |||||||||||||||||||||||||||||
Ending Balance at Sep. 30, 2019 | $ 32,023 | 10,597 | $ 1,588 | $ 7,509 | (1,639) | 3,139 | $ 4,136 | $ 2,752 | $ 1,384 | $ 0 | $ 3,550 | $ 1,818 | $ 1,732 | $ 2,913 | $ 1,765 | $ 1,148 | $ 1,520 | $ 914 | $ 606 | $ 1,268 | $ 1,134 | $ 134 | |||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||
Appropriation of retained earnings for future dividends | $ 3,139 | $ (200) | $ 200 | $ 0 |
Consolidated Statements of Ch_2
Consolidated Statements of Changes in Shareholders Equity (Unaudited) (Parenthetical) - $ / shares | 3 Months Ended | |||||
Sep. 30, 2019 | Jun. 30, 2019 | Mar. 31, 2019 | Sep. 30, 2018 | Jun. 30, 2018 | Mar. 31, 2018 | |
Statement of Stockholders' Equity [Abstract] | ||||||
Common Stock, Dividends, Per Share, Declared | $ 0.36 | $ 0.36 | $ 0.36 | $ 0.35 | $ 0.35 | $ 0.35 |
Significant Accounting Policies
Significant Accounting Policies | 9 Months Ended |
Sep. 30, 2019 | |
Accounting Policies [Abstract] | |
Significant Accounting Policies [Text Block] | Basis of Presentation (All Registrants) Each of the Registrant’s Consolidated Financial Statements includes the accounts of its subsidiaries. All intercompany transactions have been eliminated. 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” within the consolidated financial statements and include intercompany eliminations unless otherwise disclosed. The accompanying consolidated financial statements as of September 30, 2019 and 2018 and for the three and nine months then ended 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, 2018 Consolidated Balance Sheets were derived from audited financial statements. 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, 2019 . 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. New Accounting Standards (All Registrants) New Accounting Standards Adopted in 2019: In 2019, the Registrants have adopted the following new authoritative accounting guidance issued by the FASB. Leases. The Registrants applied the new guidance with the following transition practical expedients: • a "package of three" expedients that must be taken together and allow entities to (1) not reassess whether existing contracts contain leases, (2) carry forward the existing lease classification, and (3) not reassess initial direct costs associated with existing leases, • an implementation expedient which allows the requirements of the standard in the period of adoption with no restatement of prior periods, and • a land easement expedient which allows entities to not evaluate land easements under the new standard at adoption if they were not previously accounted for as leases. The standard materially impacted the Registrants' Consolidated Balance Sheets but did not have a material impact in the Registrants' Consolidated Statements of Operations and Comprehensive Income, Consolidated Statements of Cash Flows and Consolidated Statements of Changes in Shareholders' Equity. The most significant impact was the recognition of the ROU assets and lease liabilities for operating leases. The operating ROU assets and lease liabilities recognized upon adoption are materially consistent with the balances presented in the Combined Notes to the Consolidated Financial Statements. See Note 5 - Leases for additional information. See Note 1 — Significant Accounting Policies of the Exelon 2018 Form 10-K for additional information on new accounting standards issued and adopted as of January 1, 2019. New Accounting Standards Issued and Not Yet Adopted as of September 30, 2019 : The following new authoritative accounting guidance issued by the FASB has not yet been adopted and reflected by the Registrants in their consolidated financial statements as of September 30, 2019 . Unless otherwise indicated, the Registrants are currently assessing the impacts such guidance may have (which could be material) in their financial statements. The Registrants have assessed other FASB issuances of new standards which are not listed below as the Registrants do not expect such standards to have a material impact to their financial statements. Goodwill Impairment (Issued January 2017). Simplifies the accounting for goodwill impairment by removing Step 2 of the current test, which requires calculation of a hypothetical purchase price allocation. Under the revised guidance, goodwill impairment will be measured as the amount by which a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying amount of goodwill (currently Step 1 of the two-step impairment test). Entities will continue to have the option to perform a qualitative assessment to determine if a quantitative impairment test is necessary. Exelon, Generation, ComEd, PHI and DPL do not expect the updated guidance to have a material impact to their financial statements. The standard is effective January 1, 2020, with early adoption permitted, and must be applied on a prospective basis. Impairment of Financial Instruments (Issued June 2016). Provides for a new Current Expected Credit Loss (CECL) impairment model for specified financial instruments including loans, trade receivables, debt securities classified as held-to-maturity investments and net investments in leases recognized by a lessor. Under the new guidance, on initial recognition and at each reporting period, an entity is required to recognize an allowance that reflects its current estimate of credit losses expected to be incurred over the life of the financial instrument based on historical experience, current conditions and reasonable and supportable forecasts. The standard will be effective January 1, 2020 (with early adoption as of January 1, 2019 permitted) and requires a modified retrospective transition approach through a cumulative-effect adjustment to retained earnings as of the beginning of the period of adoption. This standard is primarily applicable to Generation's and the Utility Registrants' trade accounts receivable balances. The Registrants do not expect that this guidance will have a significant impact on their consolidated financial statements. Leases (All Registrants) The Registrants recognize a ROU asset and lease liability for operating leases with a term of greater than one year. The ROU asset is included in Other deferred debits and other assets and the lease liability is included in Other current liabilities and Other deferred credits and other liabilities on the Consolidated Balance Sheets. The ROU asset is measured as the sum of (1) the present value of all remaining fixed and in-substance fixed payments using each Registrant’s incremental borrowing rate, (2) any lease payments made at or before the commencement date (less any lease incentives received) and (3) any initial direct costs incurred. The lease liability is measured the same as the ROU asset, but excludes any payments made before the commencement date and initial direct costs incurred. Lease terms include options to extend or terminate the lease if it is reasonably certain they will be exercised. The Registrants include non-lease components, which are service-related costs that are not integral to the use of the asset, in the measurement of the ROU asset and lease liability. Expense for operating leases and leases with a term of one year or less is recognized on a straight-line basis over the term of the lease, unless another systematic and rational basis is more representative of the derivation of benefit from use of the leased property. Variable lease payments are recognized in the period in which the related obligation is incurred and consist primarily of payments for purchases of electricity under contracted generation and are based on the electricity produced by those generating assets. Operating lease expense and variable lease payments are recorded to Purchased power and fuel expense for contracted generation or Operating and maintenance expense for all other lease agreements on the Registrants’ Statements of Operations and Comprehensive Income. Income from operating leases, including subleases, is recognized on a straight-line basis over the term of the lease, unless another systematic and rational basis is more representative of the pattern in which income is earned over the term of the lease. Variable lease payments are recognized in the period in which the related obligation is performed and consist primarily of payments received from sales of electricity under contracted generation and are based on the electricity produced by those generating assets. Operating lease income and variable lease payments are recorded to Operating revenues on the Registrants’ Statements of Operations and Comprehensive Income. The Registrants’ operating leases consist primarily of contracted generation, real estate including office buildings, and vehicles and equipment. The Registrants generally account for contracted generation in which the generating asset is not renewable as a lease if the customer has dispatch rights and obtains substantially all of the economic benefits. For new agreements entered after January 1, 2019, the Registrants will generally not account for contracted generation in which the generating asset is renewable as a lease if the customer does not design the generating asset. The Registrants account for land right arrangements that provide for exclusive use as leases while shared use land arrangements are generally not leases. The Registrants do not account for secondary use pole attachments as leases. See Note 5 — Leases for additional information. Significant Accounting Policies (All Registrants) |
Business Description [Text Block] | Significant Accounting Policies (All Registrants) Description of Business (All Registrants) Exelon is a utility services holding company engaged in the generation, delivery and marketing of energy through Generation and the energy distribution and transmission businesses through ComEd, PECO, BGE, Pepco, DPL and ACE. Name of Registrant Business Service Territories Exelon Generation Generation, physical delivery and marketing of power across multiple geographical regions through its customer-facing business, Constellation, which sells electricity to both wholesale and retail customers. Generation also sells natural gas, renewable energy and other energy-related products and services. Five reportable segments: Mid-Atlantic, Midwest, New York, ERCOT and Other Power Regions 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 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 |
Variable Interest Entities (Exe
Variable Interest Entities (Exelon, Generation, PHI and ACE) | 9 Months Ended |
Sep. 30, 2019 | |
Variable Interest Entity [Abstract] | |
Variable Interest Entites (Exelon, Generation, PHI and ACE) | Variable Interest Entities (Exelon, Generation, PHI and ACE) At September 30, 2019 and December 31, 2018 , Exelon, Generation, PHI and ACE collectively consolidated several VIEs or VIE groups for which the applicable Registrant was the primary beneficiary (see Consolidated VIEs below) and had significant interests in several other VIEs for which the applicable Registrant does not have the power to direct the entities’ activities and, accordingly, was not the primary beneficiary (see Unconsolidated VIEs below). Consolidated and unconsolidated VIEs are aggregated to the extent that the entities have similar risk profiles. Consolidated VIEs The table below shows the carrying amounts and classification of the consolidated VIEs’ assets and liabilities included in the consolidated financial statements of Exelon, Generation, PHI and ACE as of September 30, 2019 and December 31, 2018 . The assets, except as noted in the footnotes to the table below, can only be used to settle obligations of the VIEs. The liabilities, except as noted in the footnote to the table below, are such that creditors, or beneficiaries, do not have recourse to the general credit of Exelon, Generation, PHI and ACE. September 30, 2019 December 31, 2018 Exelon Generation PHI (a) ACE Exelon Generation PHI (a) ACE Cash and cash equivalents $ 168 $ 168 $ — $ — $ 414 $ 414 $ — $ — Restricted cash and cash equivalents 76 73 3 3 66 62 4 4 Accounts receivable, net Customer 163 163 — — 146 146 — — Other 43 43 — — 23 23 — — Unamortized energy contract asset (b) 23 23 — — 25 25 — — Inventory, net Materials and supplies 222 222 — — 212 212 — — Other current assets 50 48 2 — 52 49 3 — Total current assets 745 740 5 3 938 931 7 4 Property, plant and equipment, net (c) 6,079 6,079 — — 6,188 6,188 — — NDT funds 2,636 2,636 — — 2,351 2,351 — — Unamortized energy contract asset (b) 258 258 — — 274 274 — — Other noncurrent assets 69 52 17 15 258 232 26 19 Total noncurrent assets 9,042 9,025 17 15 9,071 9,045 26 19 Total assets $ 9,787 $ 9,765 $ 22 $ 18 $ 10,009 $ 9,976 $ 33 $ 23 Long-term debt due within one year $ 556 $ 535 $ 21 $ 19 $ 87 $ 66 $ 21 $ 18 Accounts payable 148 148 — — 96 96 — — Accrued expenses 58 57 1 1 73 72 1 1 Unamortized energy contract liabilities 10 10 — — 15 15 — — Other current liabilities 30 30 — — 3 3 — — Total current liabilities 802 780 22 20 274 252 22 19 Long-term debt 532 504 28 26 1,072 1,025 47 40 Asset retirement obligations (d) 2,103 2,103 — — 2,165 2,165 — — Unamortized energy contract liabilities 1 1 — — 1 1 — — Other noncurrent liabilities 84 84 — — 42 42 — — Total noncurrent liabilities 2,720 2,692 28 26 3,280 3,233 47 40 Total liabilities $ 3,522 $ 3,472 $ 50 $ 46 $ 3,554 $ 3,485 $ 69 $ 59 _________ (a) Includes certain purchase accounting adjustments not pushed down to the ACE standalone entity. (b) These are unrestricted assets to Exelon and Generation. (c) Exelon’s and Generation’s balances include unrestricted assets of $41 million and $43 million as of September 30, 2019 and December 31, 2018 , respectively. (d) Exelon’s and Generation’s balances include liabilities with recourse of $5 million as of September 30, 2019 and December 31, 2018 . As of September 30, 2019 and December 31, 2018 , Exelon's and Generation's consolidated VIEs consist of: Consolidated VIE or VIE groups: Reason entity is a VIE: Reason Generation is primary beneficiary: CENG - A joint venture between Generation and EDF. Generation has a 50.01% equity ownership in CENG. See additional discussion below. Disproportionate relationship between equity interest and operational control as a result of the Nuclear Operating Services Agreement (NOSA) described further below. Generation conducts the operational activities. EGRP - A collection of wind and solar project entities. Generation has a 51% equity ownership in EGRP. See additional discussion below. Similar structure to a limited partnership and the limited partners do not have kick out rights with respect to the general partner. Generation conducts the operational activities. Bluestem Wind Energy Holdings, LLC - A Tax Equity structure which is consolidated by EGRP. Generation is a minority interest holder. Similar structure to a limited partnership and the limited partners do not have kick out rights with respect to the general partner. Generation conducts the operational activities. Antelope Valley - A solar generating facility, which is 100% owned by Generation. Antelope Valley sells all of its output to PG&E through a PPA. The PPA contract absorbs variability through a performance guarantee. Generation conducts all activities. Equity investment in distributed energy company - Generation has a 31% equity ownership. This distributed energy company has an interest in an unconsolidated VIE (see Unconsolidated VIEs disclosure below). Generation fully impaired this investment in the third quarter of 2019. See Note 7— Asset Impairments for additional information. Similar structure to a limited partnership and the limited partners do not have kick out rights with respect to the general partner. Generation conducts the operational activities. CENG - On April 1, 2014, Generation, CENG, and subsidiaries of CENG executed the NOSA pursuant to which Generation conducts all activities associated with the operations of the CENG fleet and provides corporate and administrative services to CENG and the CENG fleet for the remaining life of the CENG nuclear plants as if they were a part of the Generation nuclear fleet, subject to the CENG member rights of EDF. Exelon and Generation, where indicated, provide the following support to CENG: • Generation provided a $400 million loan to CENG. The loan balance was fully repaid by CENG in January 2019. • Generation executed an Indemnity Agreement pursuant to which Generation agreed to indemnify EDF against third-party claims that may arise from any future nuclear incident (as defined in the Price-Anderson Act) in connection with the CENG nuclear plants or their operations. Exelon guarantees Generation’s obligations under this Indemnity Agreement. See Note 22 — Commitments and Contingencies of the Exelon 2018 Form 10-K for additional information. • Generation and EDF share in the $688 million of contingent payment obligations for the payment of contingent retrospective premium adjustments for the nuclear liability insurance. • Exelon has executed an agreement to provide up to $245 million to support the operations of CENG as well as a $165 million guarantee of CENG’s cash pooling agreement with its subsidiaries. EGRP - EGRP is a collection of wind and solar project entities and some of these project entities are VIEs that are consolidated by EGRP. Generation owns a number of limited liability companies that build, own, and operate solar and wind power facilities some of which are owned by EGRP. While Generation or EGRP owns 100% of the solar entities and 100% of the majority of the wind entities, it has been determined that certain of the solar and wind entities are VIEs because the entities require additional subordinated financial support in the form of a parental guarantee of debt, loans from the customers in order to obtain the necessary funds for construction of the solar facilities, or the customers absorb price variability from the entities through the fixed price power and/or REC purchase agreements. Generation is the primary beneficiary of these solar and wind entities that qualify as VIEs because Generation controls the design, construction, and operation of the facilities. Generation provides operating and capital funding to the solar and wind entities for ongoing construction, operations and maintenance and there is limited recourse related to Generation related to certain solar and wind entities. In 2017, Generation’s interests in EGRP were contributed to and are pledged for the EGR IV non-recourse debt project financing structure. Refer to Note 11 — Debt and Credit Agreements for additional information. As of September 30, 2019 and December 31, 2018 , Exelon's, PHI's and ACE's consolidated VIE consists of: Consolidated VIEs: Reason entity is a VIE: Reason ACE is the primary beneficiary: ACE Transition Funding - A special purpose entity formed by ACE for the purpose of securitizing authorized portions of ACE’s recoverable stranded costs through the issuance and sale of transition bonds. Proceeds from the sale of each series of transition bonds by ATF were transferred to ACE in exchange for the transfer by ACE to ATF of the right to collect a non-bypassable Transition Bond Charge from ACE customers pursuant to bondable stranded costs rate orders issued by the NJBPU in an amount sufficient to fund the principal and interest payments on transition bonds and related taxes, expenses and fees. ACE’s equity investment is a variable interest as, by design, it absorbs any initial variability of ACETF. The bondholders also have a variable interest for the investment made to purchase the transition bonds. ACE controls the servicing activities. Unconsolidated VIEs Exelon’s and Generation’s variable interests in unconsolidated VIEs generally include equity investments and energy purchase and sale contracts. For the equity investments, the carrying amount of the investments is reflected in Exelon’s and Generation’s Consolidated Balance Sheets in Investments. For the energy purchase and sale contracts (commercial agreements), the carrying amount of assets and liabilities in Exelon’s and Generation’s Consolidated Balance Sheets that relate to their involvement with the VIEs are predominately related to working capital accounts and generally represent the amounts owed by, or owed to, Exelon and Generation for the deliveries associated with the current billing cycles under the commercial agreements. As of September 30, 2019 and December 31, 2018 , Exelon and Generation had significant unconsolidated variable interests in several VIEs for which Exelon or Generation, as applicable, was not the primary beneficiary. These interests include certain equity method investments and certain commercial agreements. The following table presents summary information about Exelon's and Generation’s unconsolidated VIE entities: September 30, 2019 December 31, 2018 Commercial Agreement VIEs Equity Investment VIEs Total Commercial Agreement VIEs Equity Investment VIEs Total Total assets (a) $ 614 $ 453 $ 1,067 $ 597 $ 472 $ 1,069 Total liabilities (a) 36 224 260 37 222 259 Exelon's ownership interest in VIE (a) — 201 201 — 223 223 Other ownership interests in VIE (a) 587 28 615 560 27 587 Registrants’ maximum exposure to loss: Carrying amount of equity method investments — 12 12 — 223 223 _________ (a) These items represent amounts in the unconsolidated VIE balance sheets, not in Exelon’s or Generation’s Consolidated Balance Sheets. These items are included to provide information regarding the relative size of the unconsolidated VIEs. For each of the unconsolidated VIEs, Exelon and Generation have assessed the risk of a loss equal to their maximum exposure to be remote and, accordingly, Exelon and Generation have not recognized a liability associated with any portion of the maximum exposure to loss. As of September 30, 2019 and December 31, 2018 , Exelon's and Generation's unconsolidated VIEs consist of: Unconsolidated VIE groups: Reason entity is a VIE: Reason Generation is not the primary beneficiary: Equity investments in distributed energy companies - 1) Generation has a 90% equity ownership in a distributed energy company. 2) Generation, via a consolidated VIE, has a 90% equity ownership in another distributed energy company (See Consolidated VIEs disclosure above). Generation fully impaired these investments in the third quarter of 2019. See Note 7— Asset Impairments for additional information. Similar structures to a limited partnership and the limited partners do not have kick out rights with respect to the general partner. Generation does not conduct the operational activities. Energy Purchase and Sale agreements - Generation has several energy purchase and sale agreements with generating facilities. PPA contracts that absorb variability through fixed pricing. Generation does not conduct the operational activities. |
Mergers, Acquisitions and Dispo
Mergers, Acquisitions and Dispositions (Exelon and Generation) | 9 Months Ended |
Sep. 30, 2019 | |
Business Combinations [Abstract] | |
Mergers, Acquisitions and Dispositions Disclosures [Text Block] | Mergers, Acquisitions and Dispositions (Exelon and Generation) Acquisition of Handley Generating Station On November 7, 2017, ExGen Texas Power, LLC (EGTP), and all of its wholly owned subsidiaries filed voluntary petitions for relief under Chapter 11 of Title 11 of the United States Code in the United States Bankruptcy Court for the District of Delaware, which resulted in Exelon and Generation deconsolidating EGTP's assets and liabilities from their consolidated financial statements. Concurrently with the Chapter 11 filings, Generation entered into an asset purchase agreement to acquire one of EGTP's generating plants, the Handley Generating Station, which closed on April 4, 2018 for a purchase price of $62 million . Disposition of Oyster Creek On July 31, 2018, Generation entered into an agreement with Holtec International (Holtec) and its indirect wholly owned subsidiary, Oyster Creek Environmental Protection, LLC (OCEP), for the sale and decommissioning of Oyster Creek located in Forked River, New Jersey, which permanently ceased generation operations on September 17, 2018. Completion of the transaction contemplated by the sale agreement was subject to the satisfaction of several closing conditions, including approval of the license transfer from the NRC and other regulatory approvals, and a private letter ruling from the IRS, which were satisfied in the second quarter 2019. The sale was completed on July 1, 2019. Exelon and Generation recognized a loss on the sale in the third quarter, which was immaterial. Under the terms of the transaction, Generation transferred to OCEP substantially all the assets associated with Oyster Creek, including assets held in NDT funds, along with the assumption of liability for all responsibility for the site, including full decommissioning and ongoing management of spent fuel until the spent fuel is moved offsite. The terms of the transaction also include various forms of performance assurance for the obligations of OCEP to timely complete the required decommissioning, including a parental guaranty from Holtec for all performance and payment obligations of OCEP, and a requirement for Holtec to deliver a letter of credit to Generation upon the occurrence of specified events. As a result of the transaction, in the third quarter of 2018, Exelon and Generation reclassified certain Oyster Creek assets and liabilities in Exelon’s and Generation’s Consolidated Balance Sheets as held for sale at their respective fair value s. Exelon and Generation had $897 million and $777 million of Assets and Liabilities held for sale, respectively, at December 31, 2018 . Upon remeasurement of the Oyster Creek ARO, Exelon and Generation recognized an $84 million and a $9 million pre-tax charge to Operating and maintenance expense in the third quarter of 2018 and in the second quarter of 2019, respectively. See Note 13 — Nuclear Decommissioning for additional information. Other Asset Disposition On February 28, 2018, Generation completed the sale of its interest in an electrical contracting business that primarily installs, maintains and repairs underground and high-voltage cable transmission and distribution systems for $87 million , resulting in a pre-tax gain which is included within Gain on sales of assets and businesses in Exelon's and Generation's Consolidated Statements of Operations and Comprehensive Income for the nine months ended September 30, 2018 . |
Revenue from Contracts with Cus
Revenue from Contracts with Customers (All Registrants) | 9 Months Ended |
Sep. 30, 2019 | |
Revenue from Contract with Customer [Abstract] | |
Revenue from Contracts with Customers [Text Block] | 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. Generation’s primary sources of revenue include competitive sales of power, natural gas, and other energy-related products and services. The Utility Registrants’ primary sources of revenue include regulated electric and gas tariff sales, distribution and transmission services. See Note 3 — Revenue from Contracts with Customers of the Exelon 2018 Form 10-K for additional information regarding the primary sources of revenue for the Registrants. Contract Balances (All Registrants) Contract Assets and Liabilities Generation records contract assets for the revenue recognized on the construction and installation of energy efficiency assets and new power generating facilities before Generation has an unconditional right to bill for and receive the consideration from the customer. These contract assets are subsequently reclassified to receivables when the right to payment becomes unconditional. Generation records contract assets and contract receivables within Other current assets and Accounts receivable, net - Customer, respectively, within Exelon’s and Generation’s Consolidated Balance Sheets. Generation records contract liabilities when consideration is received or due prior to the satisfaction of the performance obligations. These contract liabilities primarily relate to upfront consideration received or due for equipment service plans, solar panel leases and the Illinois ZEC program that introduces a cap on the total consideration to be received by Generation. Generation records contract liabilities within Other current liabilities and Other noncurrent liabilities within Exelon's and Generation's Consolidated Balance Sheets. The following table provides a rollforward of the contract assets and liabilities reflected in Exelon's and Generation's Consolidated Balance Sheets from January 1, 2018 to September 30, 2019 : Contract Assets Contract Liabilities Exelon Generation Exelon Generation Balance as of January 1, 2018 $ 283 $ 283 $ 35 $ 35 Consideration received or due (146 ) (146 ) 179 465 Revenues recognized 50 50 (187 ) (458 ) Balance at December 31, 2018 187 187 27 42 Consideration received or due (109 ) (109 ) 65 198 Revenues recognized 92 92 (66 ) (192 ) Balance at September 30, 2019 170 170 26 48 The Utility Registrants do not have any contract assets. The Utility Registrants also record contract liabilities when consideration is received prior to the satisfaction of the performance obligations. As of September 30, 2019 and December 31, 2018 , the Utility Registrants' contract liabilities were immaterial. Transaction Price Allocated to Remaining Performance Obligations (All Registrants) 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 September 30, 2019 . 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 Generation's power and gas sales contracts as they contain variable volumes and/or variable pricing. This disclosure also 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. 2019 2020 2021 2022 2023 and thereafter Total Exelon 156 341 142 74 244 957 Generation 215 442 197 89 244 1,187 Revenue Disaggregation (All Registrants) 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 18 — Segment Information for the presentation of the Registrant's revenue disaggregation. |
Leases (All Registrants)
Leases (All Registrants) | 9 Months Ended |
Sep. 30, 2019 | |
Leases [Abstract] | |
Lessee, Finance and Operating Leases [Text Block] | Leases (All Registrants) Lessee The Registrants have operating leases for which they are the lessees. The following tables outline the significant types of operating leases at each registrant and other terms and conditions of the lease agreements. The Registrants do not have material finance leases. Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Contracted generation ● ● Real estate ● ● ● ● ● ● ● ● ● Vehicles and equipment ● ● ● ● ● ● ● ● ● (in years) Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Remaining lease terms 1-87 1-37 1-6 1-15 1-87 1-13 1-13 1-13 1-8 Options to extend the term 3-30 3-30 5 N/A N/A 3-30 5 3-30 N/A Options to terminate within 2-14 2 4 N/A 3 N/A N/A N/A N/A The components of lease costs for the three months ended September 30, 2019 were as follows: Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Operating lease costs $ 97 $ 73 $ 1 $ — $ 8 $ 12 $ 3 $ 3 $ 2 Variable lease costs 79 74 — — 1 1 — — — Short-term lease costs 5 5 — — — — — — — Total lease costs (a) $ 181 $ 152 $ 1 $ — $ 9 $ 13 $ 3 $ 3 $ 2 __________ (a) Excludes $29 million , $28 million , $1 million and $1 million of sublease income recorded at Exelon, Generation, PHI and DPL, respectively The components of lease costs for the nine months ended September 30, 2019 were as follows: Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Operating lease costs $ 252 $ 180 $ 2 $ 1 $ 25 $ 35 $ 9 $ 10 $ 5 Variable lease costs 229 214 1 — 1 5 2 2 1 Short-term lease costs 16 16 — — — — — — — Total lease costs (a) $ 497 $ 410 $ 3 $ 1 $ 26 $ 40 $ 11 $ 12 $ 6 __________ (a) Excludes $48 million , $42 million , $6 million and $6 million of sublease income recorded at Exelon, Generation, PHI and DPL, respectively. The following table provides additional information regarding the presentation of operating lease ROU assets and lease liabilities within the Registrants’ Consolidated Balance Sheets as of September 30, 2019 : Exelon (a) Generation (a) ComEd PECO BGE PHI Pepco DPL ACE Operating lease ROU assets Other deferred debits and other assets $ 1,374 $ 926 $ 10 $ 2 $ 83 $ 304 $ 66 $ 75 $ 24 Operating lease liabilities Other current liabilities 242 170 3 — 32 35 8 11 5 Other deferred credits and other liabilities 1,355 949 8 1 50 279 60 74 19 Total operating lease liabilities $ 1,597 $ 1,119 $ 11 $ 1 $ 82 $ 314 $ 68 $ 85 $ 24 __________ (a) Exelon's and Generation's operating ROU assets and lease liabilities include $542 million and $703 million , respectively, related to contracted generation. The weighted average remaining lease terms, in years, and discount rates for operating leases as of September 30, 2019 were as follows: Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Remaining lease term 10.1 10.6 4.7 4.3 5.6 9.0 9.6 9.5 5.3 Discount rate 4.5 % 4.8 % 3.1 % 3.3 % 3.6 % 4.0 % 3.7 % 3.7 % 3.3 % Future minimum lease payments for operating leases as of September 30, 2019 were as follows: Year Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE 2019 $ 65 $ 50 $ 1 $ — $ 1 $ 11 $ 3 $ 2 $ 2 2020 289 203 3 1 34 45 10 13 5 2021 246 162 3 — 31 43 9 12 5 2022 179 113 2 — 16 42 9 12 4 2023 148 100 1 — — 41 8 11 4 Remaining years 1,123 837 2 — 19 197 43 53 6 Total 2,050 1,465 12 1 101 379 82 103 26 Interest 453 346 1 — 19 65 14 18 2 Total operating lease liabilities $ 1,597 $ 1,119 $ 11 $ 1 $ 82 $ 314 $ 68 $ 85 $ 24 Future minimum lease payments for operating leases under the prior lease accounting guidance as of December 31, 2018 were as follows: Year Exelon (a)(b) Generation (a)(b) ComEd (a)(c) PECO (a)(c) BGE (a)(c)(d)(e) PHI (a) Pepco (a) DPL (a)(c) ACE (a) 2019 $ 140 $ 33 $ 7 $ 5 $ 35 $ 48 $ 11 $ 14 $ 7 2020 149 46 5 5 35 46 10 13 6 2021 143 46 4 5 33 43 9 12 5 2022 126 47 4 5 18 42 8 12 5 2023 97 46 3 5 3 39 8 10 4 Remaining years 723 545 — — 19 159 40 35 5 Total minimum future lease payments $ 1,378 $ 763 $ 23 $ 25 $ 143 $ 377 $ 86 $ 96 $ 32 __________ (a) Includes amounts related to shared use land arrangements. (b) Excludes Generation’s contingent operating lease payments associated with contracted generation. (c) Amounts related to certain real estate leases and railroad licenses effectively have indefinite payment periods. As a result, ComEd, PECO, BGE and DPL have excluded these payments from the remaining years as such amounts would not be meaningful. ComEd's, PECO’s, BGE’s and DPL's average annual obligation for these arrangements, included in each of the years 2019 - 2023, was $3 million , $5 million , $1 million and $1 million respectively. Also includes amounts related to shared use land arrangements. (d) Includes all future lease payments on a 99-year real estate lease that expires in 2106. (e) The BGE column above includes minimum future lease payments associated with a 6-year lease for the Baltimore City conduit system that became effective during the fourth quarter of 2016. BGE's total commitments under the lease agreement are $26 million , $28 million , $28 million and $14 million related to years 2019 - 2022, respectively. Cash paid for amounts included in the measurement of lease liabilities for the nine months ended September 30, 2019 were as follows: Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Operating cash flows from operating leases $ 225 $ 156 $ 2 $ — $ 32 $ 29 $ 7 $ 6 $ 4 ROU assets obtained in exchange for lease obligations for the nine months ended September 30, 2019 were as follows: Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Operating leases $ 70 $ 11 $ 6 $ — $ 1 $ 20 $ 7 $ 9 $ 4 |
Lessor, Operating Leases [Text Block] | Lessor The Registrants have operating leases for which they are the lessors. The following tables outline the significant types of leases at each registrant and other terms and conditions of their lease agreements. Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Contracted generation ● ● Real estate ● ● ● ● ● ● ● ● ● (in years) Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Remaining lease terms 1-84 1-33 1-18 1-84 24 1-14 2-7 13-14 1-3 Options to extend the term 1-79 1-5 5-79 5-50 N/A 5 N/A N/A N/A The components of lease income for the three months ended September 30, 2019 were as follows: Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Operating lease income $ 30 $ 29 $ — $ — $ — $ 1 $ — $ 1 $ — Variable lease income 80 80 — — — — — — — The components of lease income for the nine months ended September 30, 2019 were as follows: Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Operating lease income $ 48 $ 44 $ — $ — $ — $ 3 $ — $ 3 $ — Variable lease income 209 206 — — — 3 — 3 — Future minimum lease payments to be recovered under operating leases as of September 30, 2019 were as follows: Year Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE 2019 $ 4 $ 3 $ — $ — $ — $ 1 $ — $ 1 $ — 2020 51 46 — — — 4 — 3 — 2021 50 45 — — — 4 1 3 — 2022 50 45 — — — 5 — 4 — 2023 49 45 — — — 4 — 3 — Remaining years 314 271 1 3 1 38 — 38 — Total $ 518 $ 455 $ 1 $ 3 $ 1 $ 56 $ 1 $ 52 $ — Leases (All Registrants) |
Regulatory Matters (All Registr
Regulatory Matters (All Registrants) | 9 Months Ended |
Sep. 30, 2019 | |
Regulated Operations [Abstract] | |
Regulatory Matters (All Registrants) | Regulatory Matters (All Registrants) As discussed in Note 4 — Regulatory Matters of the Exelon 2018 Form 10-K, the Registrants are involved in rate and regulatory proceedings at the FERC and their state commissions. The following discusses developments in 2019 and updates to the 2018 Form 10-K. Utility Regulatory Matters (Exelon and the Utility Registrants) Distribution Base Rate Case Proceedings The following tables show the completed and pending distribution base rate case proceedings in 2019. Completed Distribution Base Rate Case Proceedings Registrant/Jurisdiction Filing Date Requested Revenue Requirement (Decrease) Increase Approved Revenue Requirement (Decrease) Increase Approved ROE Approval Date Rate Effective Date ComEd - Illinois (Electric) April 16, 2018 $ (23 ) $ (24 ) 8.69% December 4, 2018 January 1, 2019 PECO - Pennsylvania (Electric) March 29, 2018 $ 82 $ 25 N/A (a) December 20, 2018 January 1, 2019 BGE - Maryland (Natural Gas) June 8, 2018 (amended October 12, 2018) $ 61 $ 43 9.8% January 4, 2019 January 4, 2019 ACE - New Jersey (Electric) August 21, 2018 (amended November 19, 2018) $ 122 (b) $ 70 (b) 9.6% March 13, 2019 April 1, 2019 Pepco - Maryland (Electric) January 15, 2019 (amended May 16, 2019) $ 27 $ 10 9.6% August 12, 2019 August 13, 2019 __________ (a) The PECO rate case proceeding was resolved through a settlement agreement, which did not specify an approved ROE. (b) Requested and approved increases are before New Jersey sales and use tax. Pending Distribution Base Rate Case Proceedings Registrant/Jurisdiction Filing Date Requested Revenue Requirement (Decrease) Increase Requested ROE Expected Approval Timing ComEd - Illinois (Electric) (a) April 8, 2019 $ (6 ) 8.91 % December 2019 BGE - Maryland (Electric) (b) May 24, 2019 (amended October 4, 2019) $ 74 10.3 % December 2019 BGE - Maryland (Natural Gas) (b) May 24, 2019 (amended October 4, 2019) $ 59 10.3 % December 2019 Pepco - District of Columbia (Electric) (c) May 30, 2019 (amended September 16, 2019) $ 160 10.3 % Fourth quarter of 2020 __________ (a) Reflects an increase of $57 million for the initial revenue requirement for 2019 and a decrease of $63 million related to the annual reconciliation for 2018. The revenue requirement for 2019 and annual reconciliation for 2018 provides for a weighted average debt and equity return on distribution rate base of 6.53% . See Note 4 — Regulatory Matters of the Exelon 2018 Form 10-K for additional information on ComEd's distribution formula rate filings. (b) On October 25, 2019, BGE filed a settlement agreement with the MDPSC. The settlement provides for an increase to BGE’s annual electric and natural gas distribution rates of $18 million and $45 million , respectively. (c) Reflects a three-year cumulative multi-year plan and total requested revenue requirement increases of $84 million , $40 million and $36 million for years 2020, 2021, and 2022, respectively, to recover capital investments made in 2018 and 2019 and planned capital investments from 2020 to 2022. Transmission Formula Rates Transmission Formula Rate (Exelon, ComEd, BGE, PHI, Pepco, DPL and ACE). ComEd’s, BGE’s, Pepco's, DPL's and ACE's 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, with the resulting rates effective on June 1 of the same year. The annual formula rate update is based on prior year actual costs and current year projected capital additions (initial year revenue requirement). The update 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). For 2019, the following total increases/(decreases) were included in ComEd’s, BGE’s, Pepco's, DPL's and ACE's electric transmission formula rate filings: Registrant (a) Initial Revenue Requirement Increase (Decrease) Annual Reconciliation (Decrease) Increase Total Revenue Requirement Increase (Decrease) Allowed Return on Rate Base (c) Allowed ROE (d) ComEd $ 21 $ (16 ) $ 5 8.21 % 11.50 % BGE (10 ) (23 ) (19 ) (b) 7.35 % 10.50 % Pepco 15 11 26 7.75 % 10.50 % DPL 17 (1 ) 16 7.14 % 10.50 % ACE 11 (2 ) 9 7.79 % 10.50 % __________ (a) All rates are effective June 2019 , subject to review by the FERC and other parties, which is due by the fourth quarter of 2019 . (b) The change in BGE's transmission revenue requirement includes a FERC approved dedicated facilities charge of $14 million 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 settlement 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, Pepco, DPL and ACE, 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. Pending Transmission Formula Rate (Exelon and PECO). On May 1, 2017, PECO filed a request with FERC seeking approval to update its transmission rates and change the manner in which PECO’s transmission rate is determined from a fixed rate to a formula rate. The formula rate will be updated annually to ensure that under this rate customers pay the actual costs of providing transmission services. PECO’s initial formula rate filing included a requested increase of $22 million to PECO’s annual transmission revenue requirement, which reflected a ROE of 11% , inclusive of a 50 basis point adder for being a member of a RTO. On June 27, 2017, FERC issued an Order accepting the filing and suspending the proposed rates until December 1, 2017, subject to refund, and set the matter for hearing and settlement judge procedures. Pursuant to the transmission formula rate request discussed above, PECO made its annual formula rate updates in May 2018 and 2019, which included a decrease of $6 million and an increase of $8 million , respectively, to the annual transmission revenue requirement. The updated transmission formula rates were effective on June 1, 2018 and 2019, respectively, subject to refund. On July 22, 2019, PECO and other parties filed with FERC a settlement agreement, which includes a ROE of 10.35% , inclusive of a 50 basis point adder for being a member of a RTO. The settlement did not have a material impact on PECO’s 2017, 2018, or 2019 annual transmission revenue requirements. A final order from FERC is expected before the end of the first quarter of 2020. PECO cannot predict the outcome of this proceeding, or the transmission formula FERC may approve. Other State Regulatory Matters Energy Efficiency Formula Rate. ComEd filed its annual energy efficiency formula rate update with the ICC on May 23, 2019. The filing establishes the revenue requirement used to set the rates that will take effect in January 2020 after the ICC’s review and approval. The revenue requirement requested is based on a reconciliation of the 2018 actual costs plus projected 2019 and 2020 expenditures. Registrant Initial Revenue Requirement Increase (Decrease) Annual Reconciliation Increase (Decrease) Total Revenue Requirement Increase (Decrease) Requested Return on Rate Base Requested ROE ComEd $ 53 $ (2 ) $ 51 (a) 6.53 % 8.91 % __________ (a) The requested revenue requirement increase provides for a weighted average debt and equity return on rate base of 6.53% inclusive of an allowed ROE of 8.91% . The ROE reflects the average rate on 30-year treasury notes plus 580 basis points. The ROE applicable to the 2018 reconciliation year is 10.91% and the return on rate base is 7.49% , which include the Performance Adjustment, which can either increase or decrease the ROE by up to a maximum of 200 basis points. Maryland Regulatory Matters Maryland Alternative Rate Plans Rulemaking (Exelon, BGE, PHI, Pepco and DPL). On August 9, 2019, the MDPSC issued an order in which the MDPSC determined that it is now appropriate to move forward to implement alternative rate plans in Maryland. The MDPSC found that a multi-year rate plan, based on a historic test year and allowing up to three future test years, can produce just and reasonable rates. A working group has been convened to develop and submit a detailed implementation report to the MDPSC by December 20, 2019. The MDPSC will issue another order on next steps by January 30, 2020. BGE, Pepco and DPL cannot predict the outcome or the potential financial impact, if any, on BGE, Pepco or DPL. New Jersey Regulatory Matters ACE Infrastructure Investment Program Filing (Exelon, PHI and ACE). On February 28, 2018, ACE filed with the NJBPU the company’s Infrastructure Investment Program (IIP) proposing to seek recovery of a series of investments through a new rider mechanism, totaling $338 million , between 2019-2022 to provide safe and reliable service for its customers. The IIP allowed for more timely recovery of investments made to modernize and enhance ACE’s electric system. On April 15, 2019, ACE entered into a settlement agreement with other parties, which allows for a recovery totaling $96 million of reliability related capital investments from July 1, 2019 through June 30, 2023. On April 18, 2019, the NJBPU approved the settlement agreement. New Jersey Clean Energy Legislation (Exelon, PHI and ACE). On May 23, 2018, New Jersey enacted legislation that established and modified New Jersey’s clean energy and energy efficiency programs and solar and renewable energy portfolio standards. On the same day, New Jersey enacted legislation that established a ZEC program that provides compensation for nuclear plants that demonstrate to the NJBPU that they meet certain requirements, including that they make a significant contribution to air quality in the state and that their revenues are insufficient to cover their costs and risks. Electric distribution utilities in New Jersey, including ACE, began collecting from retail distribution customers, through a non-bypassable charge, all costs associated with the utility’s procurement of the ZECs effective April 18, 2019. See Generation Regulatory Matters below for additional information. Other Federal Regulatory Matters Transmission-Related Income Tax Regulatory Assets (Exelon, ComEd, BGE, PHI, Pepco, DPL and ACE). On December 13, 2016 (and as amended on March 13, 2017), BGE filed with FERC to begin recovering certain existing and future transmission-related income tax regulatory assets through its transmission formula rate. BGE’s existing regulatory assets included (1) amounts that, if BGE’s transmission formula rate provided for recovery, would have been previously amortized and (2) amounts that would be amortized and recovered prospectively. ComEd, Pepco, DPL and ACE had similar transmission-related income tax regulatory liabilities and assets also requiring FERC approval. On November 16, 2017, FERC issued an order rejecting BGE’s proposed revisions to its transmission formula rate to recover these transmission-related income tax regulatory assets. As a result of the FERC’s order, ComEd, BGE, Pepco, DPL and ACE took a charge to Income tax expense within their Consolidated Statements of Operations and Comprehensive Income in the fourth quarter of 2017 reducing their associated transmission-related income tax regulatory assets for the portion of the total transmission-related income tax regulatory assets that would have been previously amortized and recovered through rates. Similar regulatory assets and liabilities at PECO are not subject to the same FERC transmission rate recovery formula. See above for additional information regarding PECO's transmission formula rate filing. On December 18, 2017, BGE filed for clarification and rehearing of FERC’s November 16, 2017 order and on February 23, 2018 (as amended on July 9, 2018), ComEd, Pepco, DPL, and ACE each filed with FERC to revise their transmission formula rate mechanisms to permit recovery of transmission-related income tax regulatory assets, including those amounts that would have been previously amortized and recovered through rates had the transmission formula rate provided for such recovery. On September 7, 2018, FERC issued orders rejecting BGE’s December 18, 2017 request for rehearing and clarification and ComEd's, Pepco's, DPL's and ACE's February 23, 2018 (as amended on July 9, 2018) filings, citing the lack of timeliness of the requests to recover amounts that would have been previously amortized, but indicating that ongoing recovery of certain transmission-related income tax regulatory assets would provide for a more accurate revenue requirement, consistent with its November 16, 2017 order. On October 1, 2018, ComEd, BGE, Pepco, DPL, and ACE submitted filings to recover ongoing non-TCJA amortization amounts and refund TCJA transmission-related income tax regulatory liabilities for the prospective period starting on October 1, 2018. In addition, on October 9, 2018, ComEd, Pepco, DPL, and ACE sought rehearing of FERC's September 7, 2018 order. On November 2, 2018, BGE filed an appeal of FERC’s September 7, 2018 order to the Court of Appeals for the D.C. Circuit. On April 26, 2019, FERC issued an order accepting ComEd’s, BGE’s, Pepco’s, DPL’s, and ACE’s October 1, 2018 filings, effective October 1, 2018, subject to refund and established hearing and settlement judge procedures. ComEd, BGE, Pepco, DPL, and ACE cannot predict the outcome of these proceedings. If FERC ultimately rules that the future, ongoing non-TCJA amortization amounts are not recoverable, Exelon, ComEd, BGE, PHI, Pepco, DPL and ACE would record additional charges to Income tax expense, which could be up to approximately $80 million , $52 million , $16 million , $12 million , $4 million , $6 million and $2 million , respectively, as of September 30, 2019 . Regulatory Assets and Liabilities The Utility Registrants' regulatory assets and liabilities have not changed materially since December 31, 2018, unless noted below. See Note 4 — Regulatory Matters of the Exelon 2018 Form 10-K for additional information on the specific regulatory assets and liabilities. ComEd . Regulatory assets increased $122 million primarily due to an increase of $186 million in Energy Efficiency Costs and $32 million Renewable Energy partially offset by a decrease of $97 million in Electric Distribution Formula Rate Annual Reconciliations. PECO. Regulatory assets increased $62 million primarily due to an increase of $95 million in Deferred Income Taxes offset by a $34 million decrease in Electric Energy and Natural Gas Costs. BGE . Regulatory liabilities decreased $90 million primarily due to a decrease of $40 million in Deferred Income Taxes and $43 million in Removal Costs. Pepco. Regulatory assets decreased $84 million primarily due to a decrease of $39 million in Electric Energy and Natural Gas Costs, $26 million in DC PLUG charge and $14 million in AMI Programs - Deployment Costs and Legacy Meters. Regulatory liabilities decreased by $71 million primarily due to a decrease of $73 million in Deferred Income Taxes. DPL. Regulatory liabilities decreased $42 million primarily due to a decrease of $29 million in Deferred Income Taxes and $10 million in Electric Energy and Natural Gas Costs. ACE. Regulatory liabilities decreased $30 million primarily due to a decrease of $32 million in Deferred Income Taxes. Capitalized Ratemaking Amounts Not Recognized (Exelon and the Utility Registrants) 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 Exelon's and the Utility Registrant's 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 our customers. Exelon ComEd (a) PECO BGE (b) PHI Pepco (c) DPL (c) ACE September 30, 2019 $ 59 $ 4 $ — $ 47 $ 8 $ 5 $ 3 $ — December 31, 2018 $ 65 $ 8 $ — $ 49 $ 8 $ 5 $ 3 $ — _________ (a) Reflects ComEd's unrecognized equity returns earned for ratemaking purposes on its electric distribution formula rate regulatory assets. (b) BGE's authorized amounts capitalized for ratemaking purposes primarily relate to earnings on shareholders' investment on its AMI programs. (c) Pepco's and DPL's authorized amounts capitalized for ratemaking purposes relate to earnings on shareholders' investment on their respective AMI Programs and Energy Efficiency and Demand Response Programs. The earnings on energy efficiency are on Pepco DC and DPL DE programs only. Generation Regulatory Matters (Exelon and Generation) Illinois Regulatory Matters Zero Emission Standard. Pursuant to FEJA, on January 25, 2018, the ICC announced that Generation’s Clinton Unit 1, Quad Cities Unit 1 and Quad Cities Unit 2 nuclear plants were selected as the winning bidders through the IPA's ZEC procurement event. Generation executed the ZEC procurement contracts with Illinois utilities, including ComEd, effective January 26, 2018 and began recognizing revenue with compensation for the sale of ZECs retroactive to the June 1, 2017 effective date of FEJA. During the first quarter of 2018, Generation recognized $150 million of revenue related to ZECs generated from June 1, 2017 through December 31, 2017. On February 14, 2017, two lawsuits were filed in the Northern District of Illinois against the IPA alleging that the state’s ZEC program violates certain provisions of the U.S. Constitution. Both lawsuits argued that the Illinois ZEC program would distort PJM's FERC-approved energy and capacity market auction system of setting wholesale prices and sought a permanent injunction preventing the implementation of the program. The lawsuits were dismissed by the district court on July 14, 2017. On September 13, 2018, the U.S. Circuit Court of Appeals for the Seventh Circuit affirmed the lower court's dismissal of both lawsuits. On January 7, 2019, plaintiffs filed a petition seeking U.S. Supreme Court review of the case, which was denied on April 15, 2019. New Jersey Regulatory Matters New Jersey Clean Energy Legislation. On May 23, 2018, New Jersey enacted legislation that established a ZEC program that will provide compensation for nuclear plants that demonstrate to the NJBPU that they meet certain requirements, including that they make a significant contribution to air quality in the state and that their revenues are insufficient to cover their costs and risks. Under the legislation, the NJBPU will issue ZECs to qualifying nuclear power plants and the electric distribution utilities in New Jersey, including ACE, will be required to purchase those ZECs. On November 19, 2018, NJBPU issued an order providing for the method and application process for determining the eligibility of nuclear power plants, a draft method and process for ranking and selecting eligible nuclear power plants, and the establishment of a mechanism for each regulated utility to purchase ZECs from selected nuclear power plants. On December 19, 2018, PSEG filed complete applications seeking NJBPU approval for Salem 1 and Salem 2, of which Generation owns a 42.59% ownership interest, to participate in the ZEC program. On April 18, 2019, the NJBPU approved the award of ZECs to Salem 1 and Salem 2. Upon approval, Generation began recognizing revenue for the sale of New Jersey ZECs in the month they are generated and has recognized $21 million and $31 million for the three and nine months ended September 30, 2019 . On May 15, 2019, New Jersey Rate Counsel appealed the NJBPU's decision to the New Jersey Superior Court. The appeal does not prevent implementation of the ZEC program. Exelon and Generation cannot predict the outcome of the appeal. See Note 8 — Early Plant Retirements for additional information related to Salem. New York Regulatory Matters New York Clean Energy Standard. On August 1, 2016, the NYPSC issued an order establishing the New York CES, a component of which is a Tier 3 ZEC program targeted at preserving the environmental attributes of zero-emissions nuclear-powered generating facilities that meet the criteria demonstrating public necessity as determined by the NYPSC. On October 19, 2016, a coalition of fossil-generation companies filed a complaint in federal district court against the NYPSC alleging that the ZEC program violates certain provisions of the U.S. Constitution; specifically, that the ZEC program interferes with FERC’s jurisdiction over wholesale rates and that it discriminates against out of state competitors, which was dismissed by the district court on July 25, 2017. On September 27, 2018, the U.S. Court of Appeals for the Second Circuit affirmed the lower court's dismissal of the complaint against the ZEC program. On January 7, 2019, the fossil-generation companies filed a petition seeking U.S. Supreme Court review of the case which was denied on April 15, 2019. In addition, on November 30, 2016 (as amended on January 13, 2017), a group of parties filed a Petition in New York State court seeking to invalidate the ZEC program, which argued that the NYPSC did not have authority to establish the program, that it violated state environmental law and that it violated certain technical provisions of the State Administrative Procedures Act when adopting the ZEC program. Subsequently, Generation, CENG and the NYPSC filed motions to dismiss the state court action, which were later opposed by the plaintiffs. On January 22, 2018, the court dismissed the environmental claims and the majority of the plaintiffs from the case but denied the motions to dismiss with respect to the remaining five plaintiffs and claims, without commenting on the merits of the case. On October 8, 2019, the court dismissed all remaining claims. The petitioners have until November 11, 2019 to file a notice of appeal. See Note 8 — Early Plant Retirements for additional information related to Ginna and Nine Mile Point. Federal Regulatory Matters Operating License Renewals Conowingo Hydroelectric Project. On August 29, 2012, Generation submitted a hydroelectric license application to FERC for a new license for the Conowingo Hydroelectric Project (Conowingo). In connection with Generation’s efforts to obtain a water quality certification pursuant to Section 401 of the Clean Water Act (401 Certification) from MDE for Conowingo, Generation has been working with MDE and other stakeholders to resolve water quality licensing issues, including: (1) water quality, (2) fish habitat, and (3) sediment. On April 21, 2016, Generation and the U.S. Fish and Wildlife Service of the U.S. Department of the Interior executed a settlement agreement (DOI Settlement) resolving all fish passage issues between the parties. On April 27, 2018, MDE issued its 401 Certification for Conowingo. As issued, the 401 Certification contains numerous conditions, including those relating to reduction of nutrients from upstream sources, removal of all visible trash and debris from upstream sources, and implementation of measures relating to fish passage, which could have a material, unfavorable impact on Exelon’s and Generation’s financial statements through an increase in capital expenditures and operating costs if implemented. On May 25, 2018, Generation filed complaints in federal and state court, along with a petition for reconsideration with MDE, alleging that the conditions are unfair and onerous and in violation of MDE regulations and state, federal, and constitutional law. Generation also requested that FERC defer the issuance of the federal license while these significant state and federal law issues are pending. On February 28, 2019, Generation filed a Petition for Declaratory Order with FERC requesting that FERC issue an order declaring that MDE waived its right to issue a 401 Certification for Conowingo because it failed to timely act on Conowingo's 401 Certification application and requesting that FERC decline to include the conditions required by MDE in April 2018. On October 29, 2019, Generation and MDE entered into a settlement agreement (MDE Settlement) that would resolve all outstanding issues relating to the 401 Certification. Under the MDE Settlement, the parties will propose license articles to FERC for approval as an offer of settlement to be incorporated by FERC into the new license in accordance with FERC’s discretionary authority under the Federal Power Act. The MDE Settlement provides that if FERC approves the offer of settlement, MDE would waive its rights to issue a 401 Certification and Generation would agree to implement environmental protection, mitigation and enhancement measures over the anticipated 50-year term of the new license. These measures address ecological and water quality matters, including modifications to river flows to improve aquatic habitat, along with other additional fish and eel passage improvements and initiatives to support rare, threatened and endangered wildlife, among other commitments. Exelon’s commitments under the DOI and MDE Settlements are not effective until incorporated by FERC into the new license. The financial impact of the DOI and MDE Settlements and other anticipated license commitments are estimated to be $11 million to $14 million per year, on average, recognized over the new license term, including capital and operating costs. The actual timing and amount of the majority of these costs are not currently fixed and will vary from year to year throughout the life of the new license. Generation cannot currently predict when FERC will issue the new license. As of September 30, 2019 , $41 million of direct costs associated with Conowingo licensing efforts have been capitalized. Generation’s current depreciation provision for Conowingo assumes renewal of the FERC license. |
Asset Impairments (Exelon and G
Asset Impairments (Exelon and Generation) | 9 Months Ended |
Sep. 30, 2019 | |
Property, Plant and Equipment [Abstract] | |
Asset Impairment Charges [Text Block] | Asset Impairments (Exelon and Generation) The Registrants evaluate the carrying value of long-lived assets or asset groups for recoverability whenever events or changes in circumstances indicate that the carrying value of those assets may not be recoverable. Indicators of impairment may include a deteriorating business climate, including, but not limited to, declines in energy prices, condition of the asset, specific regulatory disallowance, or plans to dispose of a long-lived asset significantly before the end of its useful life. The Registrants determine if long-lived assets or asset groups are impaired by comparing the undiscounted expected future cash flows to the carrying value. When the undiscounted cash flow analysis indicates a long-lived asset or asset group is not recoverable, the amount of the impairment loss is determined by measuring the excess of the carrying amount of the long-lived asset or asset group over its fair value. The fair value analysis is primarily based on the income approach using significant unobservable inputs (Level 3) including revenue and generation forecasts, projected capital and maintenance expenditures and discount rates. A variation in the assumptions used could lead to a different conclusion regarding the recoverability of an asset or asset group and, thus, could potentially result in material future impairments of the Registrant's long-lived assets. Equity Method Investments in Certain Distributed Energy Companies In the third quarter of 2019, Generation’s equity method investments in certain distributed energy companies were fully impaired due to an other-than-temporary decline in market conditions and underperforming projects. Exelon and Generation recorded a pre-tax impairment charge of $164 million in Equity in losses of unconsolidated affiliates and an offsetting pre-tax $96 million in Net income attributable to noncontrolling interests in their Consolidated Statements of Operations and Comprehensive Income. As a result, Generation accelerated the amortization of investment tax credits associated with these companies and Exelon and Generation recorded a benefit of $46 million in Income taxes. The impairment charge and the accelerated amortization of investment tax credits resulted in a net $15 million decrease to Exelon’s and Generation’s earnings. See Note 2 — Variable Interest Entities for additional information. Antelope Valley Solar Facility Generation’s Antelope Valley, a 242 MW solar facility in Lancaster, CA, sells all of its output to PG&E through a PPA. As of September 30, 2019 , Generation had approximately $730 million of net long-lived assets related to Antelope Valley. As a result of the PG&E bankruptcy filing in the first quarter of 2019, Generation completed a comprehensive review of Antelope Valley's estimated undiscounted future cash flows and no impairment charge was recorded. Significant changes in assumptions such as the likelihood of the PPA being rejected as part of the bankruptcy proceedings could potentially result in future impairments of Antelope Valley’s net long-lived assets, which could be material. Antelope Valley is a wholly owned indirect subsidiary of EGR IV, which had approximately $1,930 million of additional net long-lived assets as of September 30, 2019 . EGR IV is a wholly owned indirect subsidiary of Exelon and Generation and includes Generation's interest in EGRP and other projects with non-controlling interests. To date, there have been no indicators to suggest that the carrying amount of other net long-lived assets of EGR IV may not be recoverable. Generation will continue to monitor the bankruptcy proceedings for any changes in circumstances that may indicate the carrying amount of the net long-lived assets of Antelope Valley or other long-lived assets of EGR IV may not be recoverable. See Note 11 - Debt and Credit Agreements for additional information on the PG&E bankruptcy. |
Early Plant Retirements (Exelon
Early Plant Retirements (Exelon and Generation) | 9 Months Ended |
Sep. 30, 2019 | |
Property, Plant and Equipment [Abstract] | |
Early Plant Retirements (Exelon and Generation) | Early Plant Retirements (Exelon and Generation) Exelon and Generation continuously evaluate factors that affect the current and expected economic value of Generation’s plants, including, but not limited to: market power prices, results of capacity auctions, potential legislative and regulatory solutions to ensure plants are fairly compensated for benefits they provide through their carbon-free emissions, reliability, or fuel security, and the impact of potential rules from the EPA requiring reduction of carbon and other emissions and the efforts of states to implement those final rules. The precise timing of an early retirement date for any plant, and the resulting financial statement impacts, may be affected by many factors, including the status of potential regulatory or legislative solutions, results of any transmission system reliability study assessments, the nature of any co-owner requirements and stipulations, and NDT fund requirements for nuclear plants, among other factors. However, the earliest retirement date for any plant would usually be the first year in which the unit does not have capacity or other obligations, and where applicable, just prior to its next scheduled nuclear refueling outage. Nuclear Generation In 2015 and 2016, Generation identified the Clinton and Quad Cities nuclear plants in Illinois, Ginna and Nine Mile Point nuclear plants in New York and Three Mile Island nuclear plant in Pennsylvania as having the greatest risk of early retirement based on economic valuation and other factors. In 2017, PSEG made public similar financial challenges facing its New Jersey nuclear plants, including Salem, of which Generation owns a 42.59% ownership interest. PSEG is the operator of Salem and also has the decision-making authority to retire Salem. Assuming the continued effectiveness of the Illinois ZES, New Jersey ZEC program and the New York CES, Generation and CENG, through its ownership of Ginna and Nine Mile Point, no longer consider Clinton, Quad Cities, Salem, Ginna or Nine Mile Point to be at heightened risk for early retirement. However, to the extent the Illinois ZES, New Jersey ZEC program or the New York CES do not operate as expected over their full terms, each of these plants could again be at heightened risk for early retirement, which could have a material impact on Exelon’s and Generation’s future financial statements. See Note 6 — Regulatory Matters for additional information on the Illinois ZES, New Jersey ZEC program and New York CES. In Pennsylvania, the TMI nuclear plant did not clear in the May 2017 PJM capacity auction for the 2020-2021 planning year, the third consecutive year that TMI failed to clear the PJM base residual capacity auction and on May 30, 2017, based on these capacity auction results, prolonged periods of low wholesale power prices, and the absence of federal or state policies that place a value on nuclear energy for its ability to produce electricity without air pollution, Generation announced that it would permanently cease generation operations at TMI. On September 20, 2019, Generation permanently ceased generation operations at TMI. On February 2, 2018, Generation announced that it would permanently cease generation operations at the Oyster Creek nuclear plant at the end of its current operating cycle and permanently ceased generation operations on September 17, 2018. As a result of these early nuclear plant retirement decisions, Exelon and Generation recognized incremental non-cash charges to earnings stemming from shortening the expected economic useful lives primarily related to accelerated depreciation of plant assets (including any ARC) and accelerated amortization of nuclear fuel, as well as operating and maintenance expenses. See Note 13 — Nuclear Decommissioning for additional information on changes to the nuclear decommissioning ARO balance. The total impact for the three and nine months ended September 30, 2019 and 2018 are summarized in the table below. Three Months Ended September 30, Nine Months Ended September 30, Income statement expense (pre-tax) 2019 2018 2019 2018 Depreciation and amortization (a) Accelerated depreciation $ 71 $ 152 $ 216 $ 441 Accelerated nuclear fuel amortization 3 18 13 52 Operating and maintenance (b) 39 4 (44 ) 32 Total $ 113 $ 174 $ 185 $ 525 _________ (a) Reflects incremental accelerated depreciation and amortization for TMI for the three and nine months ended September 30, 2019 . Reflects incremental accelerated depreciation for TMI and Oyster Creek for the three and nine months ended September 30, 2018 . The Oyster Creek amounts are from February 2, 2018 through September 17, 2018. The TMI amounts are through September 20, 2019. (b) In 2019, primarily reflects the net impacts associated with the remeasurements of the TMI ARO in the first and third quarters. See Note 13 — Nuclear Decommissioning for additional information on the first quarter 2019 TMI ARO update. In 2018, primarily reflects materials and supplies inventory reserve adjustments, employee related costs and CWIP impairments associated with the early retirement decisions for TMI and Oyster Creek. Excludes the charges in the third quarter of 2018 and second quarter of 2019 to Operating and maintenance expense for the ARO remeasurement due to the sale of Oyster Creek. See Note 3 — Mergers, Acquisitions and Dispositions for additional information. Generation’s Dresden, Byron and Braidwood nuclear plants in Illinois are also showing increased signs of economic distress, which could lead to an early retirement, in a market that does not currently compensate them for their unique contribution to grid resiliency and their ability to produce large amounts of energy without carbon and air pollution. The May 2018 PJM capacity auction for the 2021-2022 planning year resulted in the largest volume of nuclear capacity ever not selected in the auction, including all of Dresden, and portions of Byron and Braidwood. Exelon continues to work with stakeholders on state policy solutions, while also advocating for broader market reforms at the regional and federal level. Other Generation On March 29, 2018, Generation notified grid operator ISO-NE of its plans to early retire its Mystic Generating Station assets absent regulatory reforms on June 1, 2022, at the end of the then-current capacity commitment for Mystic Units 7 and 8. Mystic Unit 9 was then committed through May 2021. On May 16, 2018, Generation made a filing with FERC to establish cost-of-service compensation and terms and conditions of service for Mystic Units 8 and 9 for the period between June 1, 2022 - May 31, 2024. On December 20, 2018, FERC issued an order accepting the cost of service agreement reflecting a number of adjustments to the annual fixed revenue requirement and allowing for recovery of a substantial portion of the costs associated with the Everett Marine Terminal. Those adjustments were reflected in a compliance filing filed March 1, 2019. In the December 20, 2018 order, FERC also directed a paper hearing on ROE using a new methodology. Initial briefs in the ROE proceeding were filed on April 19, 2019 and reply briefs were filed on July 18, 2019. On January 4, 2019, Generation notified ISO-NE that it will participate in the Forward Capacity Market auction for the 2022 - 2023 capacity commitment period. In addition, on January 22, 2019, Exelon and several other parties filed requests for rehearing of certain findings of the December 20, 2018 order, which does not alter Generation's commitment to participate in the Forward Capacity Auction for the 2022-2023 capacity commitment period. On June 10, 2019, ISO-NE announced that it has determined that Mystic 8 and 9 are needed for fuel security for the 2023-2024 capacity commitment period. On March 25, 2019, ISO-NE filed the Inventoried Energy Program, which is intended to provide an interim fuel security program pending conclusion of the stakeholder process to develop a long-term, market-based solution to address fuel security. Exelon filed comments on the Inventoried Energy Program proposal on April 15, 2019. On May 8, 2019, FERC issued a deficiency letter to ISO-NE seeking additional information on the Inventoried Energy Program proposal, and ISO-NE filed a response on June 6, 2019. On August 5, 2019, FERC allowed the Inventoried Energy Program to take effect by operation of law. Several parties have filed requests for rehearing. FERC ordered ISO-NE to file long-term, market-based fuel security rules by October 15, 2019. On August 30, 2019, FERC granted an extension of time to file the long-term, market-based fuel security rules to April 15, 2020. The following table provides the balance sheet amounts as of September 30, 2019 for Exelon's and Generation’s significant assets and liabilities associated with the Mystic Units 8 and 9 and Everett Marine Terminal assets that would potentially be impacted by the failure to adopt long-term solutions for reliability and fuel security. September 30, 2019 Asset Balances Materials and supplies inventory $ 31 Fuel inventory 5 Completed plant, net 889 Construction work in progress 7 Liability Balances Asset retirement obligation (2 ) |
Fair Value of Financial Assets
Fair Value of Financial Assets and Liabilities (All Registrants) | 9 Months Ended |
Sep. 30, 2019 | |
Fair Value Disclosures [Abstract] | |
Fair Value of Financial Assets and Liabilities (All Registrants) | Fair Value of Financial Assets and Liabilities (All Registrants) E xelon 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. 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 11 — Fair Value of Financial Assets and Liabilities of the Exelon 2018 Form 10-K, unless otherwise noted below. 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, SNF obligation and trust preferred securities (long-term debt to financing trusts or junior subordinated debentures) as of September 30, 2019 and December 31, 2018 . The Registrants have no financial liabilities classified as Level 1. The carrying amounts of the Registrants’ short-term liabilities as presented on their Consolidated Balance Sheets are representative of their fair value (Level 2) because of the short-term nature of these instruments. September 30, 2019 December 31, 2018 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 $ 36,304 $ 38,056 $ 2,541 $ 40,597 $ 35,424 $ 33,711 $ 2,158 $ 35,869 Generation 8,613 7,962 1,398 9,360 8,793 7,467 1,443 8,910 ComEd 8,196 9,622 — 9,622 8,101 8,390 — 8,390 PECO 3,404 3,891 50 3,941 3,084 3,157 50 3,207 BGE 3,270 3,678 — 3,678 2,876 2,950 — 2,950 PHI 6,494 5,993 1,093 7,086 6,259 5,436 665 6,101 Pepco 2,860 3,249 395 3,644 2,719 2,901 196 3,097 DPL 1,495 1,437 232 1,669 1,494 1,303 193 1,496 ACE 1,324 1,034 466 1,500 1,188 987 275 1,262 Long-Term Debt to Financing Trusts (a) Exelon $ 390 $ — $ 426 $ 426 $ 390 $ — $ 400 $ 400 ComEd 205 — 223 223 205 — 209 209 PECO 184 — 203 203 184 — 191 191 SNF Obligation Exelon $ 1,193 $ 1,017 $ — $ 1,017 $ 1,171 $ 949 $ — $ 949 Generation 1,193 1,017 — 1,017 1,171 949 — 949 ____ (a) Includes unamortized debt issuance costs which are not fair valued. 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 September 30, 2019 and December 31, 2018 : Exelon and Generation Exelon Generation As of September 30, 2019 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Assets Cash equivalents (a) $ 1,719 $ — $ — $ — $ 1,719 $ 896 $ — $ — $ — $ 896 NDT fund investments Cash equivalents (b) 315 78 — — 393 315 78 — — 393 Equities 3,121 1,727 — 1,314 6,162 3,121 1,727 — 1,314 6,162 Fixed income Corporate debt — 1,473 259 — 1,732 — 1,473 259 — 1,732 U.S. Treasury and agencies 1,777 152 — — 1,929 1,777 152 — — 1,929 Foreign governments — 56 — — 56 — 56 — — 56 State and municipal debt — 85 — — 85 — 85 — — 85 Other (c) — 23 — 979 1,002 — 23 — 979 1,002 Exelon Generation As of September 30, 2019 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Fixed income subtotal 1,777 1,789 259 979 4,804 1,777 1,789 259 979 4,804 Middle market lending — — 255 445 700 — — 255 445 700 Private equity — — — 398 398 — — — 398 398 Real estate — — — 581 581 — — — 581 581 NDT fund investments subtotal (d) 5,213 3,594 514 3,717 13,038 5,213 3,594 514 3,717 13,038 Rabbi trust investments Cash equivalents 49 — — — 49 4 — — — 4 Mutual funds 77 — — — 77 24 — — — 24 Fixed income — 13 — — 13 — — — — — Life insurance contracts — 76 40 — 116 — 24 — — 24 Rabbi trust investments subtotal 126 89 40 — 255 28 24 — — 52 Commodity derivative assets Economic hedges 533 1,488 1,817 — 3,838 533 1,488 1,817 — 3,838 Proprietary trading — 54 156 — 210 — 54 156 — 210 Effect of netting and allocation of collateral (e)(f) (677 ) (1,261 ) (1,025 ) — (2,963 ) (677 ) (1,261 ) (1,025 ) — (2,963 ) Commodity derivative assets subtotal (144 ) 281 948 — 1,085 (144 ) 281 948 — 1,085 Total assets 6,914 3,964 1,502 3,717 16,097 5,993 3,899 1,462 3,717 15,071 Liabilities Commodity derivative liabilities Economic hedges (773 ) (1,695 ) (1,686 ) — (4,154 ) (773 ) (1,695 ) (1,406 ) — (3,874 ) Proprietary trading — (59 ) (89 ) — (148 ) — (59 ) (89 ) — (148 ) Effect of netting and allocation of collateral (e)(f) 770 1,585 1,329 — 3,684 770 1,585 1,329 — 3,684 Commodity derivative liabilities subtotal (3 ) (169 ) (446 ) — (618 ) (3 ) (169 ) (166 ) — (338 ) Deferred compensation obligation — (140 ) — — (140 ) — (37 ) — — (37 ) Total liabilities (3 ) (309 ) (446 ) — (758 ) (3 ) (206 ) (166 ) — (375 ) Total net assets $ 6,911 $ 3,655 $ 1,056 $ 3,717 $ 15,339 $ 5,990 $ 3,693 $ 1,296 $ 3,717 $ 14,696 Exelon Generation As of December 31, 2018 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Assets Cash equivalents (a) $ 1,243 $ — $ — $ — $ 1,243 $ 581 $ — $ — $ — $ 581 NDT fund investments Cash equivalents (b) 252 86 — — 338 252 86 — — 338 Equities 2,918 1,591 — 1,381 5,890 2,918 1,591 — 1,381 5,890 Fixed income Corporate debt — 1,593 230 — 1,823 — 1,593 230 — 1,823 U.S. Treasury and agencies 2,081 99 — — 2,180 2,081 99 — — 2,180 Foreign governments — 50 — — 50 — 50 — — 50 State and municipal debt — 149 — — 149 — 149 — — 149 Other (c) — 30 — 846 876 — 30 — 846 876 Fixed income subtotal 2,081 1,921 230 846 5,078 2,081 1,921 230 846 5,078 Middle market lending — — 313 367 680 — — 313 367 680 Private equity — — — 329 329 — — — 329 329 Real estate — — — 510 510 — — — 510 510 NDT fund investments subtotal (d) 5,251 3,598 543 3,433 12,825 5,251 3,598 543 3,433 12,825 Rabbi trust investments Cash equivalents 48 — — — 48 5 — — — 5 Mutual funds 72 — — — 72 24 — — — 24 Fixed income — 15 — — 15 — — — — — Life insurance contracts — 70 38 — 108 — 22 — — 22 Rabbi trust investments subtotal 120 85 38 — 243 29 22 — — 51 Commodity derivative assets Economic hedges 541 2,760 1,470 — 4,771 541 2,760 1,470 — 4,771 Proprietary trading — 69 77 — 146 — 69 77 — 146 Effect of netting and allocation of collateral (e)(f) (582 ) (2,357 ) (732 ) — (3,671 ) (582 ) (2,357 ) (732 ) — (3,671 ) Commodity derivative assets subtotal (41 ) 472 815 — 1,246 (41 ) 472 815 — 1,246 Total assets 6,573 4,155 1,396 3,433 15,557 5,820 4,092 1,358 3,433 14,703 Exelon Generation As of December 31, 2018 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Liabilities Commodity derivative liabilities Economic hedges (642 ) (2,963 ) (1,276 ) — (4,881 ) (642 ) (2,963 ) (1,027 ) — (4,632 ) Proprietary trading — (73 ) (21 ) — (94 ) — (73 ) (21 ) — (94 ) Effect of netting and allocation of collateral (e)(f) 639 2,581 808 — 4,028 639 2,581 808 — 4,028 Commodity derivative liabilities subtotal (3 ) (455 ) (489 ) — (947 ) (3 ) (455 ) (240 ) — (698 ) Deferred compensation obligation — (137 ) — — (137 ) — (35 ) — — (35 ) Total liabilities (3 ) (592 ) (489 ) — (1,084 ) (3 ) (490 ) (240 ) — (733 ) Total net assets $ 6,570 $ 3,563 $ 907 $ 3,433 $ 14,473 $ 5,817 $ 3,602 $ 1,118 $ 3,433 $ 13,970 _________ (a) Exelon excludes cash of $347 million and $458 million at September 30, 2019 and December 31, 2018 , respectively, and restricted cash of $112 million and $80 million at September 30, 2019 and December 31, 2018 , respectively, and includes long-term restricted cash of $186 million and $185 million at September 30, 2019 and December 31, 2018 , respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets. Generation excludes cash of $183 million and $283 million at September 30, 2019 and December 31, 2018 , respectively, and restricted cash of $66 million and $39 million at September 30, 2019 and December 31, 2018 , respectively. (b) Includes $85 million and $50 million of cash received from outstanding repurchase agreements at September 30, 2019 and December 31, 2018 , respectively, and is offset by an obligation to repay upon settlement of the agreement as discussed in (d) below. (c) Includes a derivative liability of $2 million and a derivative asset of $44 million , which have total notional amounts of $864 million and $1,432 million at September 30, 2019 and December 31, 2018 , respectively. The notional principal amounts for these instruments provide one measure of the transaction volume outstanding as of the fiscal years ended and do not represent the amount of Exelon and Generation's exposure to credit or market loss. (d) Excludes net liabilities of $176 million and $130 million at September 30, 2019 and December 31, 2018 , respectively. These items consist of receivables related to pending securities sales, interest and dividend receivables, repurchase agreement obligations, and payables related to pending securities purchases. The repurchase agreements are generally short-term in nature with durations generally of 30 days or less. (e) Collateral posted/(received) from counterparties totaled $93 million , $324 million and $304 million allocated to Level 1, Level 2 and Level 3 mark-to-market derivatives, respectively, as of September 30, 2019 . Collateral posted/(received) from counterparties, net of collateral paid to counterparties, totaled $57 million , $224 million and $76 million allocated to Level 1, Level 2 and Level 3 mark-to-market derivatives, respectively, as of December 31, 2018 . (f) Of the collateral posted/(received), $306 million and $(94) million represents variation margin on the exchanges as of September 30, 2019 and December 31, 2018 , respectively. As of September 30, 2019 , Exelon and Generation have outstanding commitments to invest in fixed income, middle market lending, private equity and real estate investments of approximately $93 million , $241 million , $383 million , and $388 million , respectively. These commitments will be funded by Generation’s existing NDT funds. Exelon and Generation hold investments without readily determinable fair values with carrying amounts of $75 million as of September 30, 2019 . Changes were immaterial in fair value, cumulative adjustments and impairments for the three and nine months ended September 30, 2019 . Valuation Techniques Used to Determine Net Asset Value Certain NDT Fund Investments are not classified within the fair value hierarchy and are included under the heading “Not subject to leveling” in the table above. These investments are measured at fair value using NAV per share as a practical expedient and include commingled funds, mutual funds which are not publicly quoted, managed middle market funds, private equity and real estate funds. For commingled funds and mutual funds, which are not publicly quoted, the fair value is primarily derived from the quoted prices in active markets on the underlying securities and can typically be redeemed monthly with 30 or less days of notice and without further restrictions. For managed middle market funds, the fair value is determined using a combination of valuation models including cost models, market models, and income models and typically cannot be redeemed until maturity of the term loan. Private equity and real estate investments include those in limited partnerships that invest in operating companies and real estate holding companies that are not publicly traded on a stock exchange, such as, leveraged buyouts, growth capital, venture capital, distressed investments, investments in natural resources, and direct investments in pools of real estate properties. These investments typically cannot be redeemed and are generally liquidated over a period of 8 to 10 years from the initial investment date, which is based on Exelon’s understanding of the investment funds. Private equity and real estate valuations are reported by the fund manager and are based on the valuation of the underlying investments, which include inputs such as cost, operating results, discounted future cash flows, market based comparable data, and independent appraisals from sources with professional qualifications. These valuation inputs are unobservable. ComEd, PECO and BGE ComEd PECO BGE As of September 30, 2019 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) $ 264 $ — $ — $ 264 $ 207 $ — $ — $ 207 $ 122 $ — $ — $ 122 Rabbi trust investments Mutual funds — — — — 8 — — 8 7 — — 7 Life insurance contracts — — — — — 11 — 11 — — — — Rabbi trust investments subtotal — — — — 8 11 — 19 7 — — 7 Total assets 264 — — 264 215 11 — 226 129 — — 129 Liabilities Deferred compensation obligation — (7 ) — (7 ) — (8 ) — (8 ) — (5 ) — (5 ) Mark-to-market derivative liabilities (b) — — (280 ) (280 ) — — — — — — — — Total liabilities — (7 ) (280 ) (287 ) — (8 ) — (8 ) — (5 ) — (5 ) Total net assets (liabilities) $ 264 $ (7 ) $ (280 ) $ (23 ) $ 215 $ 3 $ — $ 218 $ 129 $ (5 ) $ — $ 124 ComEd PECO BGE As of December 31, 2018 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) $ 209 $ — $ — $ 209 $ 111 $ — $ — $ 111 $ 4 $ — $ — $ 4 Rabbi trust investments Mutual funds — — — — 7 — — 7 6 — — 6 Life insurance contracts — — — — — 10 — 10 — — — — Rabbi trust investments subtotal — — — — 7 10 — 17 6 — — 6 Total assets 209 — — 209 118 10 — 128 10 — — 10 Liabilities Deferred compensation obligation — (6 ) — (6 ) — (10 ) — (10 ) — (5 ) — (5 ) Mark-to-market derivative liabilities (b) — — (249 ) (249 ) — — — — — — — — Total liabilities — (6 ) (249 ) (255 ) — (10 ) — (10 ) — (5 ) — (5 ) Total net assets (liabilities) $ 209 $ (6 ) $ (249 ) $ (46 ) $ 118 $ — $ — $ 118 $ 10 $ (5 ) $ — $ 5 _________ (a) ComEd excludes cash of $76 million and $93 million at September 30, 2019 and December 31, 2018 , respectively, and restricted cash of $31 million and $28 million at September 30, 2019 and December 31, 2018 , respectively, and includes long-term restricted cash of $171 million and $166 million at September 30, 2019 and December 31, 2018 , respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets. PECO excludes cash of $23 million and $24 million at September 30, 2019 and December 31, 2018 , respectively. BGE excludes cash of $8 million and $7 million at September 30, 2019 and December 31, 2018 , respectively, and restricted cash of $1 million and $2 million at September 30, 2019 and December 31, 2018 , respectively. (b) The Level 3 balance consists of the current and noncurrent liability of $27 million and $253 million , respectively, at September 30, 2019 , and $26 million and $223 million , respectively, at December 31, 2018 , related to floating-to-fixed energy swap contracts with unaffiliated suppliers. PHI, Pepco, DPL and ACE As of September 30, 2019 As of December 31, 2018 PHI Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Cash equivalents (a) $ 107 $ — $ — $ 107 $ 147 $ — $ — $ 147 Rabbi trust investments Cash equivalents 43 — — 43 42 — — 42 Mutual funds 13 — — 13 13 — — 13 Fixed income — 13 — 13 — 15 — 15 Life insurance contracts — 24 40 64 — 22 38 60 Rabbi trust investments subtotal 56 37 40 133 55 37 38 130 Total assets 163 37 40 240 202 37 38 277 Liabilities Deferred compensation obligation — (19 ) — (19 ) — (21 ) — (21 ) Total liabilities — (19 ) — (19 ) — (21 ) — (21 ) Total net assets $ 163 $ 18 $ 40 $ 221 $ 202 $ 16 $ 38 $ 256 Pepco DPL ACE As of September 30, 2019 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) $ 34 $ — $ — $ 34 $ — $ — $ — $ — $ 18 $ — $ — $ 18 Rabbi trust investments Cash equivalents 43 — — 43 — — — — — — — — Fixed income — 3 — 3 — — — — — — — — Life insurance contracts — 24 40 64 — — — — — — — — Rabbi trust investments subtotal 43 27 40 110 — — — — — — — — Total assets 77 27 40 144 — — — — 18 — — 18 Liabilities Deferred compensation obligation — (2 ) — (2 ) — — — — — — — — Total liabilities — (2 ) — (2 ) — — — — — — — — Total net assets $ 77 $ 25 $ 40 $ 142 $ — $ — $ — $ — $ 18 $ — $ — $ 18 Pepco DPL ACE As of December 31, 2018 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) $ 38 $ — $ — $ 38 $ 16 $ — $ — $ 16 $ 23 $ — $ — $ 23 Rabbi trust investments Cash equivalents 41 — — 41 — — — — — — — — Fixed income — 5 — 5 — — — — — — — — Life insurance contracts — 22 37 59 — — — — — — — — Rabbi trust investments subtotal 41 27 37 105 — — — — — — — — Total assets 79 27 37 143 16 — — 16 23 — — 23 Liabilities Deferred compensation obligation — (3 ) — (3 ) — (1 ) — (1 ) — — — — Total liabilities — (3 ) — (3 ) — (1 ) — (1 ) — — — — Total net assets (liabilities) $ 79 $ 24 $ 37 $ 140 $ 16 $ (1 ) $ — $ 15 $ 23 $ — $ — $ 23 _________ (a) PHI excludes cash of $45 million and $39 million at September 30, 2019 and December 31, 2018 , respectively, and includes long-term restricted cash of $15 million and $19 million at September 30, 2019 and December 31, 2018 , respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets. Pepco excludes cash of $18 million and $15 million at September 30, 2019 and December 31, 2018 , respectively. DPL excludes cash of $11 million and $8 million at September 30, 2019 and December 31, 2018 , respectively. ACE excludes cash of $13 million and $7 million at September 30, 2019 and December 31, 2018 , respectively, and includes long-term restricted cash of $15 million and $19 million at September 30, 2019 and December 31, 2018 , respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets. 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 and nine months ended September 30, 2019 and 2018 : Exelon Generation ComEd PHI and Pepco Three Months Ended September 30, 2019 Total NDT Fund Investments Mark-to-Market Derivatives Total Generation Mark-to-Market Derivatives Life Insurance Contracts Eliminated in Consolidation Balance as of June 30, 2019 $ 1,179 $ 539 $ 873 $ 1,412 $ (273 ) $ 40 $ — Total realized / unrealized gains (losses) Included in net income (171 ) 2 (173 ) (a) (171 ) — — — Included in noncurrent payables to affiliates — 11 — 11 — — (11 ) Included in regulatory assets/liabilities 4 — — — (7 ) (b) — 11 Change in collateral 41 — 41 41 — — — Purchases, sales, issuances and settlements Purchases 53 1 52 53 — — — Sales (22 ) (21 ) (1 ) (22 ) — — — Settlements (18 ) (18 ) — (18 ) — — — Transfers into Level 3 1 — 1 (c) 1 — — — Transfers out of Level 3 (11 ) — (11 ) (c) (11 ) — — — Balance at September 30, 2019 $ 1,056 $ 514 $ 782 $ 1,296 $ (280 ) $ 40 $ — The amount of total (losses) gains included in income attributed to the change in unrealized gains (losses) related to assets and liabilities as of September 30, 2019 $ (18 ) $ 2 $ (20 ) $ (18 ) $ — $ — $ — Exelon Generation ComEd PHI and Pepco Nine Months Ended September 30, 2019 Total NDT Fund Investments Mark-to-Market Derivatives Total Generation Mark-to-Market Derivatives Life Insurance Contracts Eliminated in Consolidation Balance as of December 31, 2018 $ 907 $ 543 $ 575 $ 1,118 $ (249 ) $ 38 $ — Total realized / unrealized gains (losses) Included in net income (125 ) 5 (132 ) (a) (127 ) — 2 — Included in noncurrent payables to affiliates — 32 — 32 — — (32 ) Included in regulatory assets 1 — — — (31 ) (b) — 32 Change in collateral 227 — 227 227 — — — Purchases, sales, issuances and settlements Purchases 163 43 120 163 — — — Sales (23 ) (21 ) (2 ) (23 ) — — — Settlements (88 ) (88 ) — (88 ) — — — Transfers into Level 3 5 — 5 (c) 5 — — — Transfers out of Level 3 (11 ) — (11 ) (c) (11 ) — — — Balance as of September 30, 2019 $ 1,056 $ 514 $ 782 $ 1,296 $ (280 ) $ 40 $ — The amount of total gains (losses) included in income attributed to the change in unrealized gains (losses) related to assets and liabilities as of September 30, 2019 $ 173 $ 5 $ 166 $ 171 $ — $ 2 $ — __________ (a) Includes a reduction for the reclassification of $153 million and $298 million of realized gains due to the settlement of derivative contracts for the three and nine months ended September 30, 2019 , respectively. (b) Includes $7 million of decreases in fair value and an increase for realized losses due to settlements of $4 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the three months ended September 30, 2019 . Includes $31 million of decreases in fair value and an increase for realized losses due to settlements of $17 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the nine months ended September 30, 2019 . (c) Transfers into and out of Level 3 generally occur when the contract tenor becomes less and more observable respectively, primarily due to changes in market liquidity or assumptions for certain commodity contracts. Exelon Generation ComEd PHI and Pepco Three Months Ended September 30, 2018 Total NDT Fund Investments Mark-to-Market Derivatives Total Generation Mark-to-Market Derivatives Life Insurance Contracts Eliminated in Consolidation Balance as of June 30, 2018 $ 1,106 $ 585 $ 737 $ 1,322 $ (252 ) $ 36 $ — Total realized / unrealized gains (losses) Included in net income (259 ) (1 ) (259 ) (a) (260 ) — 1 — Included in noncurrent payables to affiliates — (4 ) — (4 ) — — 4 Included in regulatory assets (11 ) — — — (7 ) (b) — (4 ) Change in collateral (44 ) — (44 ) (44 ) — — — Purchases, sales, issuances and settlements Purchases 96 15 81 96 — — — Settlements (29 ) (29 ) — (29 ) — — — Transfers into Level 3 3 — 3 (c) 3 — — — Transfers out of Level 3 (6 ) — (6 ) (c) (6 ) — — — Balance as of September 30, 2018 $ 856 $ 566 $ 512 $ 1,078 $ (259 ) $ 37 $ — The amount of total gains (losses) included in income attributed to the change in unrealized gains (losses) related to assets and liabilities as of September 30, 2018 $ (105 ) $ (1 ) $ (104 ) $ (105 ) $ — $ — $ — Exelon Generation ComEd PHI and Pepco Nine Months Ended September 30, 2018 Total NDT Fund Investments Mark-to-Market Derivatives Total Generation Mark-to-Market Derivatives Life Insurance Contracts Eliminated in Consolidation Balance as of December 31, 2017 $ 966 $ 648 $ 552 $ 1,200 $ (256 ) $ 22 $ — Total realized / unrealized gains (losses) Included in net income (186 ) (1 ) (188 ) (a) (189 ) — 3 — Included in regulatory assets (3 ) — — — (3 ) (b) — — Change in collateral 14 — 14 14 — — — Purchases, sales, issuances and settlements Purchases 215 34 181 215 — — — Sales (3 ) — (3 ) (3 ) — — — Settlements (103 ) (115 ) — (115 ) — 12 — Transfers into Level 3 (21 ) — (21 ) (c) (21 ) — — — Transfers out of Level 3 (23 ) — (23 ) (c) (23 ) — — — Balance as of September 30, 2018 $ 856 $ 566 $ 512 $ 1,078 $ (259 ) $ 37 $ — The amount of total gains (losses) included in income attributed to the change in unrealized gains (losses) related to assets and liabilities as of September 30, 2018 $ 154 $ (5 ) $ 159 $ 154 $ — $ — $ — __________ (a) Includes a reduction for the reclassification of $155 million and $347 million of realized losses due to the settlement of derivative contracts for the three and nine months ended September 30, 2018 , respectively. (b) Includes $4 million of increases in fair value and an increase for realized losses due to settlements of $3 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the three months ended September 30, 2018 . Includes $9 million of decreases in fair value and an increase for realized losses due to settlements of $12 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the nine months ended September 30, 2018 . (c) Transfers into and out of Level 3 generally occur when the contract tenor becomes less and more observable respectively, primarily due to changes in market liquidity or assumptions for certain commodity contracts. The following tables present the income statement classification of the total realized and unrealized gains (losses) included in income for Level 3 assets and liabilities measured at fair value on a recurring basis during the three and nine months ended September 30, 2019 and 2018 : Exelon Generation PHI and Pepco Operating Purchased Operating and Maintenance Other, net Operating Purchased Other, net Operating and Maintenance Total realized (losses) gains for the three months ended September 30, 2019 $ (25 ) $ (148 ) $ — $ 2 $ (25 ) $ (148 ) $ 2 $ — Total realized gains (losses) for the nine months ended September 30, 2019 122 (254 ) — 5 122 (254 ) 5 — Total unrealized gains (losses) for the three months ended September 30, 2019 99 (119 ) — 2 99 (119 ) 2 — Total unrealized gains (losses) for the nine months ended September 30, 2019 368 (202 ) 2 5 368 (202 ) 5 2 Exelon Generation PHI and Pepco Operating Purchased Operating and Maintenance Other, net Operating Revenues Purchased Power and Fuel Other, net Operating and Maintenance Total realized (losses) gains for the three months ended September 30, 2018 $ (176 ) $ (83 ) $ 1 $ (1 ) $ (176 ) $ (83 ) $ (1 ) $ 1 Total realized (losses) gains for the nine months ended September 30, 2018 (32 ) (156 ) 3 (1 ) (32 ) (156 ) (1 ) 3 Total unrealized (losses) for the three months ended September 30, 2018 (64 ) (40 ) — (1 ) (64 ) (40 ) (1 ) — Total unrealized gains (losses) for the nine months ended September 30, 2018 174 (15 ) — (5 ) 174 (15 ) (5 ) — The table below discloses the significant inputs to the forward curve used to value these positions. Type of trade Fair Value at September 30, 2019 Fair Value at December 31, 2018 Valuation Technique Unobservable Input 2019 Range 2018 Range Mark-to-market derivatives — Economic Hedges (Exelon and Generation) (a)(b) $ 411 $ 443 Discounted Forward power $11 - $167 $12 - $174 Forward gas $1.36 - $10.82 $0.78 - $12.38 Option Volatility 9% - 200% 10% - 277% Mark-to-market derivatives — Proprietary trading (Exelon and Generation) (a)(b) $ 67 $ 56 Discounted Forward power $17 - $167 $14 - $174 Mark-to-market derivatives (Exelon and ComEd) $ (280 ) $ (249 ) Discounted Forward heat (c) 9x - 10x 10x - 11x Marketability 4% - 7% 4% - 8% Renewable 87% - 119% 86% - 120% _________ (a) The valuation techniques, unobservable inputs and ranges are the same for the asset and liability positions. (b) The fair values do not include cash collateral posted on level three positions of $304 million and $76 million as of September 30, 2019 and December 31, 2018 , respectively. (c) Quoted forward natural gas rates are utilized to project the forward power curve for the delivery of energy at specified future dates. The natural gas curve is extrapolated beyond its observable period to the end of the contract’s delivery. The inputs listed above, which are as of the balance sheet date, would have a direct impact on the fair values of the above instruments if they were adjusted. The significant unobservable inputs used in the fair value measurement of Generation’s commodity derivatives are forward commodity prices and for options is price volatility. Increases (decreases) in the forward commodity price in isolation would result in significantly higher (lower) fair values for long positions (contracts that give Generation the obligation or option to purchase a commodity), with offsetting impacts to short positions (contracts that give Generation the obligation or right to sell a commodity). Increases (decreases) in volatility would increase (decrease) the value for the holder of the option (writer of the option). Generally, a change in the estimate of forward commodity prices is unrelated to a change in the estimate of volatility of prices. An increase to the reserves listed above would decrease the fair value of the positions. An increase to the heat rate or renewable factors would increase the fair value accordingly. Generally, interrelationships exist between market prices of natural gas and power. As such, an increase in natural gas pricing would potentially have a similar impact on forward power markets. |
Derivative Financial Instrument
Derivative Financial Instruments (All Registrants) | 9 Months Ended |
Sep. 30, 2019 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Derivative Instruments (All Registrants) | Derivative Financial Instruments (All Registrants) The Registrants use derivative instruments to manage commodity price risk, interest rate risk and foreign exchange 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. All derivative economic hedges related to commodities, referred to as economic hedges, are recorded at fair value through earnings at Generation and offset by a corresponding regulatory asset or liability at ComEd. For all NPNS derivative instruments, accounts receivable or accounts payable are recorded when derivative settles and revenue or expense is recognized in earnings as the underlying physical commodity is sold or consumed. Authoritative guidance about offsetting assets and liabilities requires the fair value of derivative instruments to be shown in the Combined Notes to Consolidated Financial Statements on a gross basis, even when the derivative instruments are subject to legally enforceable master netting agreements and qualify for net presentation in the Consolidated Balance Sheets. A master netting agreement is an agreement between two counterparties that may have derivative and non-derivative contracts with each other providing for the net settlement of all referencing contracts via one payment stream, which takes place as the contracts deliver, when collateral is requested or in the event of default. In the tables below that present fair value balances, Generation’s energy-related economic hedges and proprietary trading derivatives are shown gross. The impact of the netting of fair value balances with the same counterparty that are subject to legally enforceable master netting agreements, as well as netting of cash collateral, including margin on exchange positions, is aggregated in the collateral and netting columns. Generation’s and ComEd’s use of cash collateral is generally unrestricted unless Generation or ComEd are 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 (All Registrants) Each of 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, including swaps, futures, forwards, options and short-term and long-term commitments to purchase and sell energy and commodity products. The Registrants believe these instruments, which are either determined to be non-derivative or classified as economic hedges, mitigate exposure to fluctuations in commodity prices. Generation. To the extent the amount of energy Generation produces differs from the amount of energy it has contracted to sell, Exelon and Generation are exposed to market fluctuations in the prices of electricity, fossil fuels and other commodities. Within Exelon, Generation has the most exposure to commodity price risk. As such, Generation uses a variety of derivative and non-derivative instruments to manage the commodity price risk of its electric generation facilities, including power and gas sales, fuel and power purchases, natural gas transportation and pipeline capacity agreements and other energy-related products marketed and purchased. To manage these risks, Generation may enter into fixed-price derivative or non-derivative contracts to hedge the variability in future cash flows from expected sales of power and gas and purchases of power and fuel. The objectives for executing such hedges include fixing the price for a portion of anticipated future electricity sales at a level that provides an acceptable return. Generation is also exposed to differences between the locational settlement prices of certain economic hedges and the hedged generating units. This price difference is actively managed through other instruments which include derivative congestion products, whose changes in fair value are recognized in earnings each period, and auction revenue rights, which are accounted for on an accrual basis. Additionally, Generation is exposed to certain market risks through its proprietary trading activities. The proprietary trading activities are a complement to Generation’s energy marketing portfolio but represent a small portion of Generation’s overall energy marketing activities and are subject to limits established by Exelon’s RMC. Utility Registrants . 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 (b) Gas NPNS Fixed price contracts to cover about 20% 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 price contracts through full requirements contracts. Changes in fair value of economic hedge recorded to an offsetting regulatory asset or liability (c) Exchange traded future contracts for 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 4 - Regulatory Matters for additional information. (b) As part of its hedging program, PECO enters into electric supply procurement contracts that do not meet the definition of a derivative instrument. (c) The fair value of the DPL economic hedge is not material as of September 30, 2019 and December 31, 2018 and is not presented in the fair value tables below. The following table provides a summary of the derivative fair value balances recorded by Exelon, Generation and ComEd as of September 30, 2019 and December 31, 2018 : September 30, 2019 Exelon Generation ComEd Derivatives Total Economic Hedges Proprietary Trading Collateral (a)(b) Netting (a) Subtotal Economic Hedges Mark-to-market derivative assets (current assets) $ 602 $ 2,452 $ 143 $ 212 $ (2,205 ) $ 602 $ — Mark-to-market derivative assets (noncurrent assets) 483 1,386 67 104 (1,074 ) 483 — Total mark-to-market derivative assets 1,085 3,838 210 316 (3,279 ) 1,085 — Mark-to-market derivative liabilities (current liabilities) (224 ) (2,550 ) (101 ) 249 2,205 (197 ) (27 ) Mark-to-market derivative liabilities (noncurrent liabilities) (394 ) (1,324 ) (47 ) 156 1,074 (141 ) (253 ) Total mark-to-market derivative liabilities (618 ) (3,874 ) (148 ) 405 3,279 (338 ) (280 ) Total mark-to-market derivative net assets (liabilities) $ 467 $ (36 ) $ 62 $ 721 $ — $ 747 $ (280 ) December 31, 2018 Exelon Generation ComEd Description Total Economic Proprietary Collateral Netting (a) Subtotal Economic Mark-to-market derivative assets $ 801 $ 3,505 $ 105 $ 121 $ (2,930 ) $ 801 $ — Mark-to-market derivative assets 445 1,266 41 51 (913 ) 445 — Total mark-to-market derivative assets 1,246 4,771 146 172 (3,843 ) 1,246 — Mark-to-market derivative liabilities (473 ) (3,429 ) (74 ) 125 2,931 (447 ) (26 ) Mark-to-market derivative liabilities (474 ) (1,203 ) (20 ) 60 912 (251 ) (223 ) Total mark-to-market derivative liabilities (947 ) (4,632 ) (94 ) 185 3,843 (698 ) (249 ) Total mark-to-market derivative net assets (liabilities) $ 299 $ 139 $ 52 $ 357 $ — $ 548 $ (249 ) _________ (a) Exelon and Generation net all available amounts allowed under the derivative authoritative guidance in the balance sheet. These amounts include unrealized derivative transactions with the same counterparty under legally enforceable master netting agreements and cash collateral. In some cases Exelon and Generation may have other offsetting exposures, subject to a master netting or similar agreement, such as trade receivables and payables, transactions that do not qualify as derivatives, letters of credit and other forms of non-cash collateral. These amounts are immaterial and not reflected in the table above. (b) Of the collateral posted/(received), $306 million and $(94) million represents variation margin on the exchanges at September 30, 2019 and December 31, 2018 respectively. Economic Hedges (Commodity Price Risk) Generation. For the three and nine months ended September 30, 2019 and 2018 , Exelon and Generation recognized the following net pre-tax commodity mark-to-market gains (losses) which are also located in the Net fair value changes related to derivatives line in the Consolidated Statements of Cash Flows. Three Months Ended Nine Months Ended 2019 2018 2019 2018 Income Statement Location Gain (Loss) Gain (Loss) Operating revenues $ 76 $ 8 $ 65 $ (99 ) Purchased power and fuel (45 ) 66 (127 ) (4 ) Total Exelon and Generation $ 31 $ 74 $ (62 ) $ (103 ) In general, increases and decreases in forward market prices have a positive and negative impact, respectively, on Generation’s owned and contracted generation positions that have not been hedged. Generation hedges commodity price risk on a ratable basis over three-year periods. As of September 30, 2019 , the percentage of expected generation hedged for the Mid-Atlantic, Midwest, New York and ERCOT reportable segments is 96% - 99% , 84% - 87% and 54% - 57% for 2019 , 2020 and 2021 , respectively. Proprietary Trading (Commodity Price Risk) Generation also executes commodity derivatives for proprietary trading purposes. Proprietary trading includes all contracts executed with the intent of benefiting from shifts or changes in market prices as opposed to those executed with the intent of hedging or managing risk. Gains and losses associated with proprietary trading are reported as Operating revenues in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income and are included in the Net fair value changes related to derivatives line in the Consolidated Statements of Cash Flows. For the three and nine months ended September 30, 2019 and 2018 , net pre-tax commodity mark-to-market gains (losses) for Exelon and Generation were not material. The Utility Registrants do not execute derivatives for proprietary trading purposes. Interest Rate and Foreign Exchange Risk (Exelon and Generation) Exelon and Generation utilize interest rate swaps, which are treated as economic hedges, to manage their interest rate exposure. On July 1, 2018, Exelon de-designated its fair value hedges related to interest rate risk and Generation de-designated its cash flow hedges related to interest rate risk. The notional amounts were $1,371 million and $1,420 million at September 30, 2019 and December 31, 2018 , respectively, for Exelon and $571 million and $620 million at September 30, 2019 and December 31, 2018 , respectively, for Generation. Generation utilizes foreign currency derivatives to manage foreign exchange rate exposure associated with international commodity purchases in currencies other than U.S. dollars, which are treated as economic hedges. The notional amounts were $257 million and $268 million at September 30, 2019 and December 31, 2018 , respectively. The mark-to-market derivative assets and liabilities as of September 30, 2019 and December 31, 2018 and the mark-to-market gains and losses for the three and nine months ended September 30, 2019 and 2018 were not material for Exelon and Generation. Credit Risk (All Registrants) 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. Generation. For commodity derivatives, Generation enters into enabling agreements that allow for payment netting with its counterparties, which reduces Generation’s exposure to counterparty risk by providing for the offset of amounts payable to the counterparty against amounts receivable from the counterparty. Typically, each enabling agreement is for a specific commodity and so, with respect to each individual counterparty, netting is limited to transactions involving that specific commodity product, except where master netting agreements exist with a counterparty that allow for cross product netting. In addition to payment netting language in the enabling agreement, Generation’s credit department establishes credit limits, margining thresholds and collateral requirements for each counterparty, which are defined in the derivative contracts. Counterparty credit limits are based on an internal credit review process that considers a variety of factors, including the results of a scoring model, leverage, liquidity, profitability, credit ratings by credit rating agencies, and risk management capabilities. To the extent that a counterparty’s margining thresholds are exceeded, the counterparty is required to post collateral with Generation as specified in each enabling agreement. Generation’s credit department monitors current and forward credit exposure to counterparties and their affiliates, both on an individual and an aggregate basis. The following tables provide information on Generation’s credit exposure for all derivative instruments, NPNS and applicable payables and receivables, net of collateral and instruments that are subject to master netting agreements, as of September 30, 2019 . The tables further delineate that exposure by credit rating of the counterparties and provide guidance on the concentration of credit risk to individual counterparties. The figures in the tables below exclude credit risk exposure from individual retail counterparties, nuclear fuel procurement contracts and exposure through RTOs, ISOs, NYMEX, ICE, NASDAQ, NGX and Nodal commodity exchanges. Additionally, the figures in the tables below exclude exposures with affiliates, including net receivables with ComEd, PECO, BGE, Pepco, DPL and ACE of $68 million , $30 million , $32 million , $39 million , $15 million and $8 million as of September 30, 2019 , respectively. Rating as of September 30, 2019 Total Exposure Before Credit Collateral Credit Collateral (a) Net Exposure Number of Counterparties Greater than 10% of Net Exposure Net Exposure of Counterparties Greater than 10% of Net Exposure Investment grade $ 693 $ 10 $ 683 — $ — Non-investment grade 74 38 36 No external ratings Internally rated — investment grade 297 1 296 Internally rated — non-investment grade 175 24 151 Total $ 1,239 $ 73 $ 1,166 — $ — Net Credit Exposure by Type of Counterparty As of Financial institutions $ 1 Investor-owned utilities, marketers, power producers 875 Energy cooperatives and municipalities 255 Other 35 Total $ 1,166 _________ (a) As of September 30, 2019 , credit collateral held from counterparties where Generation had credit exposure included $18 million of cash and $55 million of letters of credit. The credit collateral does not include non-liquid collateral. Utility Registrants. 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 September 30, 2019 , the Utility Registrants’ counterparty credit risk with suppliers was immaterial. Credit-Risk-Related Contingent Features (All Registrants) Generation. As part of the normal course of business, Generation routinely enters into physically or financially settled contracts for the purchase and sale of electric capacity, electricity, fuels, emissions allowances and other energy-related products. Certain of Generation’s derivative instruments contain provisions that require Generation to post collateral. Generation also enters into commodity transactions on exchanges where the exchanges act as the counterparty to each trade. Transactions on the exchanges must adhere to comprehensive collateral and margining requirements. This collateral may be posted in the form of cash or credit support with thresholds contingent upon Generation’s credit rating from each of the major credit rating agencies. The collateral and credit support requirements vary by contract and by counterparty. These credit-risk-related contingent features stipulate that if Generation were to be downgraded or lose its investment grade credit rating (based on its senior unsecured debt rating), it would be required to provide additional collateral. This incremental collateral requirement allows for the offsetting of derivative instruments that are assets with the same counterparty, where the contractual right of offset exists under applicable master netting agreements. In the absence of expressly agreed-to provisions that specify the collateral that must be provided, collateral requested will be a function of the facts and circumstances of the situation at the time of the demand. In this case, Generation believes an amount of several months of future payments (i.e., capacity payments) rather than a calculation of fair value is the best estimate for the contingent collateral obligation, which has been factored into the disclosure below. The aggregate fair value of all derivative instruments with credit-risk related contingent features in a liability position that are not fully collateralized (excluding transactions on the exchanges that are fully collateralized) is detailed in the table below: Credit-Risk Related Contingent Features September 30, 2019 December 31, 2018 Gross fair value of derivative contracts containing this feature (a) $ (1,249 ) $ (1,723 ) Offsetting fair value of in-the-money contracts under master netting arrangements (b) 947 1,105 Net fair value of derivative contracts containing this feature (c) $ (302 ) $ (618 ) _________ (a) Amount represents the gross fair value of out-of-the-money derivative contracts containing credit-risk related contingent features ignoring the effects of master netting agreements. (b) Amount represents the offsetting fair value of in-the-money derivative contracts under legally enforceable master netting agreements with the same counterparty, which reduces the amount of any liability for which a Registrant could potentially be required to post collateral. (c) Amount represents the net fair value of out-of-the-money derivative contracts containing credit-risk related contingent features after considering the mitigating effects of offsetting positions under master netting arrangements and reflects the actual net liability upon which any potential contingent collateral obligations would be based. As of September 30, 2019 and December 31, 2018 , Exelon and Generation posted or held the following amounts of cash collateral and letters of credit on derivative contracts with external counterparties, after giving consideration to offsetting derivative and non-derivative positions under master netting agreements. September 30, 2019 December 31, 2018 Cash collateral posted $ 787 $ 418 Letters of credit posted 273 367 Cash collateral held 96 47 Letters of credit held 58 44 Additional collateral required in the event of a credit downgrade below investment grade 1,481 2,104 Generation entered into supply forward contracts with certain utilities, including PECO and BGE, with one-sided collateral postings only from Generation. If market prices fall below the benchmark price levels in these contracts, the utilities are not required to post collateral. However, when market prices rise above the benchmark price levels, counterparty suppliers, including Generation, are required to post collateral once certain unsecured credit limits are exceeded. Utility Registrants 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, and DPL’s credit rating. As of September 30, 2019 , 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 ratings as of September 30, 2019 , they could have been required to post incremental collateral to its counterparties of $28 million , $26 million and $11 million |
Debt and Credit Agreements (All
Debt and Credit Agreements (All Registrants) | 9 Months Ended |
Sep. 30, 2019 | |
Debt Disclosure [Abstract] | |
Debt and Credit Agreements (All Registrants) | Debt and Credit Agreements (All Registrants) Short-Term Borrowings Exelon Corporate, ComEd, BGE, Pepco, DPL and ACE meet their short-term liquidity requirements primarily through the issuance of commercial paper. Generation and PECO meet their short-term liquidity requirements primarily through the issuance of commercial paper and borrowings from the Exelon intercompany money pool. PHI Corporate meets its short-term liquidity requirements primarily through the issuance of short-term notes and 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 September 30, 2019 and December 31, 2018 . Generation and PECO had no commercial paper borrowings as of both September 30, 2019 and December 31, 2018 . Outstanding Commercial Average Interest Rate on Commercial Paper Issuer September 30, 2019 December 31, 2018 September 30, 2019 December 31, 2018 Exelon $ 519 $ 89 2.50 % 2.15 % ComEd 387 — 2.51 % 2.14 % BGE — 35 2.49 % 2.18 % PHI 132 54 2.52 % 2.15 % PEPCO 12 40 2.61 % 2.24 % DPL 57 — 2.42 % 2.07 % ACE 63 14 2.57 % 2.21 % See Note 13 — Debt and Credit Agreements of the Exelon 2018 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 , which was renewed on March 22, 2018 with an expiration of March 21, 2019. The loan agreement was renewed on March 20, 2019 and will expire on March 19, 2020. Pursuant to the loan agreement, loans made thereunder bear interest at a variable rate equal to LIBOR plus 0.95% and all indebtedness thereunder is unsecured. The loan agreement is reflected in Exelon's Consolidated Balance Sheet within Short-Term borrowings. Credit Agreements On February 21, 2019, Generation entered into a credit agreement establishing a $100 million bilateral credit facility. The facility will mature in March 2021. This facility will solely be used by Generation to issue letters of credit. Long-Term Debt Issuance of Long-Term Debt During the nine months ended September 30, 2019 , the following long-term debt was issued: Company Type Interest Rate Maturity Amount Use of Proceeds Generation Energy Efficiency Project Financing 3.95 % August 31, 2020 $ 4 Funding to install energy conservation measures for the Fort Meade project. Generation Energy Efficiency Project Financing 3.46 % May 1, 2020 $ 39 Funding to install energy conservation measures for the Marine Corps. Logistics Project. ComEd First Mortgage Bonds, Series 126 4.00 % March 1, 2049 $ 400 Repay a portion of ComEd’s outstanding commercial paper obligations and fund other general corporate purposes. PECO First and Refunding Mortgage Bonds 3.00 % September 15, 2049 $ 325 Repay short-term borrowings and for general corporate purposes BGE Senior Notes 3.20 % September 15, 2049 $ 400 Repay commercial paper obligations and for general corporate purposes Pepco First Mortgage Bonds 3.45 % June 13, 2029 $ 150 Repay existing indebtedness and for general corporate purposes Pepco Unsecured Tax-Exempt Bonds 1.70 % September 1, 2022 $ 110 Refinance existing indebtedness ACE First Mortgage Bonds 3.50 % May 21, 2029 $ 100 Repay existing indebtedness and for general corporate purposes ACE First Mortgage Bonds 4.14 % May 21, 2049 $ 50 Repay existing indebtedness and for general corporate purposes Debt Covenants As of September 30, 2019 , the Registrants are in compliance with debt covenants, except for Antelope Valley's nonrecourse debt event of default as discussed below. Nonrecourse Debt Exelon and Generation have issued nonrecourse debt financing. Borrowings under these agreements are secured by the assets and equity of each respective project. The lenders do not have recourse against Exelon or Generation in the event of a default. Antelope Valley Solar Ranch One. In December 2011, the DOE Loan Programs Office issued a guarantee for up to $646 million for a nonrecourse loan from the Federal Financing Bank to support the financing of the construction of the Antelope Valley facility. The project became fully operational in 2014. The loan will mature on January 5, 2037. As of September 30, 2019 , approximately $495 million was outstanding. In 2017, Generation’s interests in Antelope Valley were also contributed to and are pledged as collateral for the EGR IV financing structure referenced below. Antelope Valley sells all of its output to PG&E through a PPA. On January 29, 2019, PG&E filed for protection under Chapter 11 of the U.S. Bankruptcy Code, which created an event of default for Antelope Valley’s nonrecourse debt that provides the lender with a right to accelerate amounts outstanding under the loan such that they would become immediately due and payable. As a result of the ongoing event of default and the absence of a waiver from the lender foregoing their acceleration rights, the debt was reclassified as current in Exelon’s and Generation’s Consolidated Balance Sheets in the first quarter of 2019 and continues to be classified as current as of September 30, 2019 . Further, distributions from Antelope Valley to EGR IV are currently suspended. ExGen Renewables IV. In November 2017, EGR IV, an indirect subsidiary of Exelon and Generation, entered into an $850 million nonrecourse senior secured term loan credit facility agreement. Generation’s interests in EGRP, Antelope Valley, SolGen, and Albany Green Energy were all contributed to and are pledged as collateral for this financing. The loan is scheduled to mature on November 28, 2024. As of September 30, 2019 , $796 million was outstanding. Although Antelope Valley’s debt is in default, it is nonrecourse to EGR IV. However, if in the future Antelope Valley were to file for bankruptcy protection as a result of events culminating from PG&E’s bankruptcy proceedings this would represent an event of default for EGR IV’s debt that would provide the lender with an opportunity to accelerate EGR IV’s debt. See Note 13 — Debt and Credit Agreements of the Exelon 2018 Form 10-K for additional information on nonrecourse debt. |
Income Taxes (All Registrants)
Income Taxes (All Registrants) | 9 Months Ended |
Sep. 30, 2019 | |
Income Tax Disclosure [Abstract] | |
Income Taxes (All Registrants) | 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 September 30, 2019 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE U.S. Federal statutory rate 21.0% 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 6.4 5.2 8.1 (0.3) 6.3 4.8 1.9 6.6 6.9 Qualified NDT fund income 3.2 7.1 — — — — — — — Amortization of investment tax credit, including deferred taxes on basis difference (4.1) (8.9) (0.2) — (0.1) (0.2) (0.1) (0.2) (0.3) Plant basis differences (1.7) — (1.0) (7.5) (1.1) (1.8) (2.6) (0.6) (1.9) Production tax credits and other credits (1.2) (2.7) — — — — — — — Noncontrolling interests (2.2) (4.8) — — — — — — — Excess deferred tax amortization (6.5) — (9.9) (3.6) (8.0) (17.7) (16.3) (13.5) (23.3) Other 0.7 0.5 0.4 (0.5) (0.2) 0.8 1.0 (0.1) 0.7 Effective income tax rate 15.6% 17.4% 18.4% 9.1% 17.9% 6.9% 4.9% 13.2% 3.1% Three Months Ended September 30, 2018 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE U.S. Federal statutory rate 21.0% 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 (1.2) (9.0) 8.3 (3.6) 7.3 0.2 1.0 6.6 7.3 Qualified NDT fund income 2.4 5.8 — — — — — — — Amortization of investment tax credit, including deferred taxes on basis difference (0.6) (1.1) (0.2) (0.1) — (0.2) (0.1) (0.3) (0.3) Plant basis differences (2.5) — (0.3) (15.2) (0.8) (2.0) (3.4) (0.7) (1.3) Production tax credits and other credits (1.2) (2.9) (0.1) — — — — — — Noncontrolling interests (1.1) (2.8) — — — — — — — Excess deferred tax amortization (6.8) — (7.8) (4.6) (7.9) (17.7) (21.2) (14.0) (15.4) Tax Cuts and Jobs Act of 2017 1.3 3.5 — — — 0.2 0.1 — — Other 3.2 5.6 0.3 0.9 2.6 0.6 0.3 0.6 0.3 Effective income tax rate 14.5% 20.1% 21.2% (1.6)% 22.2% 2.1% (2.3)% 13.2% 11.6% Nine Months Ended September 30, 2019 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE U.S. Federal statutory rate 21.0% 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 5.1 4.2 8.2 — 6.4 4.8 2.0 6.7 6.9 Qualified NDT fund income 5.3 11.9 — — — — — — — Amortization of investment tax credit, including deferred taxes on basis difference (1.9) (4.0) (0.2) — (0.1) (0.2) (0.1) (0.2) (0.3) Plant basis differences (1.6) — (0.7) (6.8) (1.1) (1.8) (2.3) (0.6) (2.0) Production tax credits and other credits (1.0) (2.1) — — — — — — — Noncontrolling interests (1.0) (2.3) — — — — — — — Excess deferred tax amortization (6.0) — (9.2) (2.9) (7.9) (18.6) (17.3) (15.0) (23.4) Other 0.8 (0.1) 0.2 (0.2) 0.1 0.5 0.7 0.2 — Effective income tax rate 20.7% 28.6% 19.3% 11.1% 18.4% 5.7% 4.0% 12.1% 2.2% Nine Months Ended September 30, 2018 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE U.S. Federal statutory rate 21.0% 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 1.7 (2.6) 8.2 (3.6) 6.6 2.7 2.4 6.5 7.3 Qualified NDT fund income 0.9 2.6 — — — — — — — Amortization of investment tax credit, including deferred taxes on basis difference (0.9) (2.2) (0.2) (0.1) (0.1) (0.2) (0.1) (0.3) (0.3) Plant basis differences (2.7) — (0.1) (15.4) (0.7) (1.9) (2.9) (0.7) (1.3) Production tax credits and other credits (1.8) (5.1) (0.1) — — — — — — Noncontrolling interests (1.1) (3.2) — — — — — — — Excess deferred tax amortization (6.1) — (7.6) (3.4) (8.1) (14.5) (16.5) (11.0) (14.0) Tax Cuts and Jobs Act of 2017 0.2 1.3 (0.2) — — 0.3 — — — Other 0.4 2.0 0.1 — 0.9 0.3 — 0.4 0.9 Effective income tax rate 11.6% 13.8% 21.1% (1.5)% 19.6% 7.7% 3.9% 15.9% 13.6% Accounting for Uncertainty in Income Taxes Exelon, Generation, ComEd, PHI and ACE have the following unrecognized tax benefits as of September 30, 2019 and December 31, 2018 . PECO, BGE, Pepco and DPL do not have unrecognized tax benefits for the periods presented. Exelon Generation ComEd PHI ACE September 30, 2019 $ 448 $ 411 $ — $ 45 $ 14 December 31, 2018 $ 477 $ 408 $ 2 $ 45 $ 14 In 2016, the Tax Court held that Exelon was not entitled to defer a gain on its 1999 like-kind exchange transaction. In addition to the tax and interest related to the gain deferral, the Tax Court also ruled that Exelon was liable for penalties and interest on the penalties. Exelon had fully paid the amounts assessed resulting from the Tax Court decision in 2017. In September 2017, Exelon appealed the Tax Court decision to the U.S. Court of Appeals for the Seventh Circuit. In October 2018, the U.S. Court of Appeals for the Seventh Circuit affirmed the Tax Court’s decision. Exelon filed a petition seeking rehearing of the Seventh Circuit’s decision, but the Seventh Circuit denied that petition in December 2018. In the first quarter of 2019, Exelon elected not to seek a further review by the U.S. Supreme Court. As a result, Exelon's and ComEd's unrecognized tax benefits decreased by approximately $33 million and $2 million , respectively, in the first quarter of 2019. Reasonably possible the total amount of unrecognized tax benefits could significantly increase or decrease within 12 months after the reporting date Settlement of Income Tax Audits, Refund Claims, and Litigation Exelon, Generation, PHI and ACE have the following unrecognized federal and state tax benefits that could significantly decrease within the 12 months after the reporting date as a result of completing audits, potential settlements, refund claims, and the outcomes of pending court cases as of September 30, 2019 : Exelon (a) Generation (a) PHI (b) ACE (b) $ 425 $ 411 $ 14 $ 14 __________ (a) Exelon and Generation have $411 million that, if recognized, would decrease the effective tax rate. (b) The unrecognized tax benefit related to PHI and ACE, if recognized, may be included in future base rates and that portion would have no impact to the effective tax rate. Other Income Tax Matters Marginal State Income Tax Rate (Exelon, Generation) In the third quarter of 2019, Exelon reviewed and updated its marginal state income tax rates based on 2018 state apportionment rates. As a result of the rate changes, the following accounting adjustments were recorded as of September 30, 2019: Exelon Generation Increase to deferred income tax liability $ 23 $ 9 Increase to income tax expense, net of federal taxes 23 9 State Income Tax Law Changes On June 5, 2019, the Governor of Illinois signed a tax bill which would increase the Illinois corporate income tax rate from 9.50% to 10.49% effective for tax years beginning on or after January 1, 2021. The tax rate is contingent upon ratification of state constitutional amendments in November 2020. The effect of the rate change will be recognized in the period in which the new legislation is enacted. Exelon, Generation and ComEd do not expect a material impact to their financial statements as a result of the rate change. |
Nuclear Decommissioning (Exelon
Nuclear Decommissioning (Exelon and Generation) | 9 Months Ended |
Sep. 30, 2019 | |
Environmental Remediation Obligations [Abstract] | |
Nuclear Decommissioning (Exelon and Generation) | Nuclear Decommissioning (Exelon and Generation) Nuclear Decommissioning Asset Retirement Obligations (Exelon and Generation) Generation has a legal obligation to decommission its nuclear power plants following the expiration of their operating licenses. To estimate its decommissioning obligation related to its nuclear generating stations for financial accounting and reporting purposes, Generation uses a probability-weighted, discounted cash flow model which, on a unit-by-unit basis, considers multiple outcome scenarios that include significant estimates and assumptions, and are based on decommissioning cost studies, cost escalation rates, probabilistic cash flow models and discount rates. Generation updates its ARO annually, unless circumstances warrant more frequent updates, based on its review of updated cost studies and its annual evaluation of cost escalation factors and probabilities assigned to various scenarios. The financial statement impact for changes in the ARO, on an individual unit basis, due to the changes in and timing of estimated cash flows generally result in a corresponding change in the unit’s ARC within Property, plant and equipment on Exelon’s and Generation’s Consolidated Balance Sheets. If the ARO decreases for a Non-Regulatory Agreement unit without any remaining ARC, the corresponding change is recorded as decrease in Operating and maintenance expense within Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income. The following table provides a rollforward of the nuclear decommissioning ARO reflected in Exelon’s and Generation’s Consolidated Balance Sheets from December 31, 2018 to September 30, 2019 : Nuclear decommissioning ARO at December 31, 2018 (a)(b) $ 10,005 Sale of Oyster Creek (755 ) Accretion expense 361 Net increase due to changes in, and timing of, estimated future cash flows 211 Costs incurred related to decommissioning plants (52 ) Nuclear decommissioning ARO at September 30, 2019 (a) $ 9,770 _________ (a) Includes $127 million and $22 million as the current portion of the ARO at September 30, 2019 and December 31, 2018 , respectively, which is included in Other current liabilities in Exelon’s and Generation’s Consolidated Balance Sheets. (b) Includes $772 million of ARO related to Oyster Creek which was classified as Liabilities held for sale in Exelon's and Generation's Consolidated Balance Sheets at December 31, 2018 . See Note 3 — Mergers, Acquisitions and Dispositions for additional information. During the nine months ended September 30, 2019 , Exelon's and Generation’s total nuclear ARO decreased by approximately $235 million , primarily reflecting the sale of Oyster Creek, partially offset by the accretion of the ARO liability due to the passage of time and the net impacts of ARO updates completed during the first and third quarters of 2019. The first quarter 2019 ARO update included an increase of approximately $330 million for a change in the assumed retirement timing probabilities for certain economically challenged nuclear plants and a $110 million decrease for the impacts of revised decommissioning cost estimates for TMI which incorporate site specific decommissioning planning activities associated with the early retirement of TMI on September 20, 2019. The TMI ARO adjustment resulted in an $85 million decrease in Operating and maintenance expense within Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income. See Note 8 — Early Plant Retirements for additional information. The third quarter 2019 ARO update included a decrease of approximately $300 million due to lower estimated costs to decommission Nine Mile Point, Ginna, Braidwood, Byron and LaSalle nuclear units resulting from the completion of updated cost studies, partially offset by an increase of approximately $280 million for other impacts that included updated cost escalation rates, primarily for labor, equipment and materials, and current discount rates. The third quarter ARO adjustment resulted in a $65 million decrease in Operating and maintenance expense within Exelon and Generation's Consolidated Statements of Operations and Comprehensive Income. NDT Funds (Exelon and Generation) Exelon and Generation had NDT funds totaling $12,862 million and $12,695 million at September 30, 2019 and December 31, 2018 , respectively. The NDT funds included $890 million at December 31, 2018 , related to Oyster Creek NDT funds which were classified as Assets held for sale in Exelon's and Generation's Consolidated Balance Sheets. See Note 3 — Mergers, Acquisitions and Dispositions for additional information regarding the sale of Oyster Creek. The NDT funds also include $156 million and $144 million for the current portion of the NDT funds at September 30, 2019 and December 31, 2018 , respectively, which are included in Other current assets in Exelon's and Generation's Consolidated Balance Sheets. See Note 17 — Supplemental Financial Information for additional information on activities of the NDT funds. NRC Minimum Funding Requirements (Exelon and Generation) NRC regulations require that licensees of nuclear generating facilities demonstrate reasonable assurance that funds will be available in specified minimum amounts to decommission the facility at the end of its life. Generation filed its biennial decommissioning funding status report with the NRC on April 1, 2019 for all units except for Zion Station which is included in a separate report to the NRC submitted by ZionSolutions, LLC. The status report demonstrated adequate decommissioning funding assurance as of December 31, 2018 for all units except for Clinton and Peach Bottom Unit 1. As of February 28, 2019, Clinton demonstrated adequate minimum funding assurance due to market recovery and no further action is required. This demonstration was also included in the April 1, 2019 submittal. As a former PECO plant, financial assurance for decommissioning Peach Bottom Unit 1 is provided by the NDT fund, collections from PECO ratepayers, and the ability to adjust those collections in accordance with the approved PAPUC tariff. No additional actions are required aside from the PAPUC filing in accordance with the tariff. See Note 15 — Asset Retirement Obligations of the Exelon 2018 Form 10-K for information regarding the amount collected from PECO ratepayers for decommissioning cost. |
Retirement Benefits (All Regist
Retirement Benefits (All Registrants) | 9 Months Ended |
Sep. 30, 2019 | |
Retirement Benefits [Abstract] | |
Retirement Benefits (All Registrants) | Retirement Benefits (All Registrants) Effective January 1, 2019, Exelon merged the Exelon Corporation Cash Balance Pension Plan (CBPP) into the Exelon Corporation Retirement Program (ECRP). The merging of the plans is not changing the benefits offered to the plan participants and, thus, has no impact on Exelon's pension obligation. However, beginning in 2019, actuarial losses and gains related to the CBPP and ECRP are being amortized over participants’ average remaining service period of the merged ECRP rather than each individual plan. Defined Benefit Pension and OPEB During the first quarter of 2019, Exelon received an updated valuation of its pension and OPEB to reflect actual census data as of January 1, 2019. This valuation resulted in an increase to the pension and OPEB obligations of $75 million and $36 million , respectively. Additionally, accumulated other comprehensive loss increased by $39 million (after-tax) and regulatory assets and liabilities increased by $53 million and decreased by $5 million , respectively. The majority of the 2019 pension benefit cost for Exelon-sponsored plans is calculated using an expected long-term rate of return on plan assets of 7.00% and a discount rate of 4.31% . The majority of the 2019 OPEB cost is calculated using an expected long-term rate of return on plan assets of 6.67% for funded plans and a discount rate of 4.30% . 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 and nine months ended September 30, 2019 and 2018 . Pension Benefits OPEB 2019 2018 2019 2018 Components of net periodic benefit cost: Service cost $ 89 $ 100 $ 23 $ 28 Interest cost 221 201 47 43 Expected return on assets (306 ) (312 ) (38 ) (43 ) Amortization of: Prior service benefit — — (45 ) (47 ) Actuarial loss 104 158 11 18 Settlement charges 7 — — — Contractual termination benefits 1 — — — Net periodic benefit cost $ 116 $ 147 $ (2 ) $ (1 ) Pension Benefits OPEB 2019 2018 2019 2018 Components of net periodic benefit cost: Service cost $ 267 $ 303 $ 70 $ 84 Interest cost 663 602 141 131 Expected return on assets (918 ) (939 ) (115 ) (130 ) Amortization of: Prior service cost (benefit) — 1 (134 ) (140 ) Actuarial loss 310 472 34 50 Settlement charges 7 1 — — Contractual termination benefits 1 — — — Net periodic benefit cost $ 330 $ 440 $ (4 ) $ (5 ) The amounts below represent the Registrants' allocated pension and OPEB plan 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 Generation and 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 September 30, Nine Months Ended September 30, Pension and OPEB Costs 2019 2018 2019 2018 Exelon $ 114 $ 145 $ 326 $ 435 Generation 37 50 100 151 ComEd 23 45 70 133 PECO 4 5 9 14 BGE 16 15 47 44 PHI 23 17 71 51 Pepco 6 3 19 10 DPL 4 2 11 5 ACE 4 3 12 10 Defined Contribution Savings Plans The Registrants participate in various 401(k) defined contribution savings plans that are sponsored by Exelon. The plans are 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 during the three and nine months ended September 30, 2019 and 2018 , respectively. Three Months Ended September 30, Nine Months Ended September 30, Savings Plan Matching Contributions 2019 2018 2019 2018 Exelon $ 36 $ 44 $ 101 $ 126 Generation 14 23 41 65 ComEd 9 8 26 23 PECO 2 2 7 7 BGE 4 2 9 5 PHI 4 4 8 10 Pepco 1 1 2 2 DPL 1 1 2 2 ACE 1 1 1 2 |
Changes in Accumulated Other Co
Changes in Accumulated Other Comprehensive Income (Exelon) | 9 Months Ended |
Sep. 30, 2019 | |
Changes in Accumulated Other Comprehensive Income [Abstract] | |
Changes in Accumulated Other Comprehensive Income Note [Text Block] | Changes in Accumulated Other Comprehensive Income (Exelon) The following tables present changes in Exelon's AOCI, net of tax, by component: Three Months Ended September 30, 2019 Losses on Cash Flow Hedges Pension and Non-Pension Postretirement Benefit Plan Items (a) Foreign Currency Items AOCI of Investments in Unconsolidated Affiliates (b) Total Beginning balance $ (2 ) $ (2,957 ) $ (29 ) $ (2 ) $ (2,990 ) OCI before reclassifications — 6 (2 ) — 4 Amounts reclassified from AOCI — 21 — 2 23 Net current-period OCI — 27 (2 ) 2 27 Ending balance $ (2 ) $ (2,930 ) $ (31 ) $ — $ (2,963 ) Three Months Ended September 30, 2018 Losses on Cash Flow Hedges Pension and Non-Pension Postretirement Benefit Plan Items (a) Foreign Currency Items AOCI of Investments in Unconsolidated Affiliates (b) Total Beginning balance $ (2 ) $ (2,890 ) $ (29 ) $ — $ (2,921 ) OCI before reclassifications — 5 2 — 7 Amounts reclassified from AOCI — 45 — — 45 Net current-period OCI — 50 2 — 52 Ending balance $ (2 ) $ (2,840 ) $ (27 ) $ — $ (2,869 ) Nine Months Ended September 30, 2019 Losses on Cash Flow Hedges Pension and Non-Pension Postretirement Benefit Plan Items (a) Foreign Currency Items AOCI of Investments in Unconsolidated Affiliates (b) Total Beginning balance $ (2 ) $ (2,960 ) $ (33 ) $ — $ (2,995 ) OCI before reclassifications — (32 ) 2 (2 ) (32 ) Amounts reclassified from AOCI — 62 — 2 64 Net current-period OCI — 30 2 — 32 Ending balance $ (2 ) $ (2,930 ) $ (31 ) $ — $ (2,963 ) Nine Months Ended September 30, 2018 Gains (Losses) on Cash Flow Hedges Unrealized gains (losses) on Marketable Securities Pension and Non-Pension Postretirement Benefit Plan Items (a) Foreign Currency Items AOCI of Investments in Unconsolidated Affiliates (b) Total Beginning balance $ (14 ) $ 10 $ (2,998 ) $ (23 ) $ (1 ) $ (3,026 ) OCI before reclassifications 11 — 22 (4 ) 1 30 Amounts reclassified from AOCI 1 — 136 — — 137 Net current-period OCI 12 — 158 (4 ) 1 167 Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard (c) — (10 ) — — — (10 ) Ending balance $ (2 ) $ — $ (2,840 ) $ (27 ) $ — $ (2,869 ) _________ (a) AOCI amounts are included in the computation of net periodic pension and OPEB cost. See Note 14 — Retirement Benefits for additional information. See Exelon's Statements of Operations and Comprehensive Income for individual components of AOCI. (b) All amounts are net of noncontrolling interests. (c) Exelon prospectively adopted the new standard Recognition and Measurement of Financial Assets and Liabilities. The standard was adopted as of January 1, 2018, which resulted in an increase to Retained earnings and Accumulated other comprehensive loss of $10 million for Exelon. The amounts reclassified related to Rabbi Trusts. The following table presents income tax benefit (expense) allocated to each component of Exelon's other comprehensive income (loss): Three Months Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 Pension and non-pension postretirement benefit plans: Prior service benefit reclassified to periodic benefit cost $ 6 $ 6 $ 18 $ 18 Actuarial loss reclassified to periodic benefit cost (13 ) (21 ) (39 ) (65 ) Pension and non-pension postretirement benefit plans valuation adjustment — (2 ) 14 (8 ) |
Commitments and Contingencies (
Commitments and Contingencies (All Registrants) | 9 Months Ended |
Sep. 30, 2019 | |
Commitments and Contingencies Disclosure [Abstract] | |
Commitments and Contingencies (All Registrants) | Commitments and Contingencies (All Registrants) The following is an update to the current status of commitments and contingencies set forth in Note 22 of the Exelon 2018 Form 10-K. See Note 5 — Mergers, Acquisitions and Dispositions of the Exelon 2018 Form 10-K for additional information on the PHI Merger commitments. 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 September 30, 2019 : Description Exelon PHI Pepco DPL ACE Total commitments $ 513 $ 320 $ 120 $ 89 $ 111 Remaining commitments (a) 112 82 67 9 6 _________ (a) Remaining commitments extend through 2026 and include rate credits, energy efficiency programs. and delivery system modernization. In addition, Exelon is committed to develop or to assist in the commercial development of approximately 37 MWs of new solar generation in Maryland, District of Columbia, and Delaware at an estimated cost of approximately $127 million , which will generate future earnings at Exelon and Generation. Investment costs, which are expected to be primarily capital in nature, are recognized as incurred and recorded in Exelon's and Generation's financial statements. As of September 30, 2019 , 27 MWs of new generation were developed and Exelon and Generation have incurred costs of $107 million . Exelon has also 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 DPSC in March 2019. The third and final 40 MW wind REC tranche will be conducted in 2022. Commercial Commitments (All Registrants). The Registrants’ commercial commitments as of September 30, 2019 , representing commitments potentially triggered by future events were as follow s: Expiration within Total 2019 2020 2021 2022 2023 2024 and beyond Exelon Letters of credit $ 1,718 $ 1,192 $ 515 $ 11 $ — $ — $ — Surety bonds (a) 991 315 638 38 — — — Financing trust guarantees 378 — — — — — 378 Guaranteed lease residual values (b) 26 — 2 3 4 3 15 Total commercial commitments $ 3,113 $ 1,507 $ 1,155 $ 52 $ 4 $ 3 $ 393 Generation Letters of credit $ 1,686 $ 1,179 $ 496 $ 11 $ — $ — $ — Surety bonds (a) 790 298 492 — — — — Total commercial commitments $ 2,476 $ 1,477 $ 988 $ 11 $ — $ — $ — ComEd Letters of credit $ 7 $ 4 $ 3 $ — $ — $ — $ — Surety bonds (a) 50 5 43 2 — — — Financing trust guarantees 200 — — — — — 200 Total commercial commitments $ 257 $ 9 $ 46 $ 2 $ — $ — $ 200 PECO Surety bonds (a) $ 9 $ 1 $ 8 $ — $ — $ — $ — Financing trust guarantees 178 — — — — — 178 Total commercial commitments $ 187 $ 1 $ 8 $ — $ — $ — $ 178 BGE Letters of credit $ 8 $ 2 $ 6 $ — $ — $ — $ — Surety bonds (a) 17 2 15 — — — — Total commercial commitments $ 25 $ 4 $ 21 $ — $ — $ — $ — PHI Letters of credit $ 11 $ 1 $ 10 $ — $ — $ — $ — Surety bonds (a) 24 5 19 — — — — Guaranteed lease residual values (b) 26 — 2 3 4 3 15 Total commercial commitments $ 61 $ 6 $ 31 $ 3 $ 4 $ 3 $ 15 Pepco Letters of credit $ 10 $ — $ 10 $ — $ — $ — $ — Surety bonds (a) 17 2 15 — — — — Guaranteed lease residual values (b) 9 — — 1 1 1 6 Total commercial commitments $ 36 $ 2 $ 25 $ 1 $ 1 $ 1 $ 6 DPL Letters of credit $ 1 $ 1 $ — $ — $ — $ — $ — Surety bonds (a) 4 2 2 — — — — Guaranteed lease residual values (b) 11 — 1 1 2 1 6 Total commercial commitments $ 16 $ 3 $ 3 $ 1 $ 2 $ 1 $ 6 ACE Surety bonds (a) $ 3 $ 1 $ 2 $ — $ — $ — $ — Guaranteed lease residual values (b) 7 — 1 1 1 1 3 Total commercial commitments $ 10 $ 1 $ 3 $ 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 $68 million guaranteed by Exelon and PHI, of which $22 million , $29 million and $17 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 in the Registrants' financial statements. MGP Sites (Exelon, ComEd, PECO, BGE, PHI and DPL). 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 identified 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 2025. • PECO has 8 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 2022. • 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 2021. • 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 settlements of natural gas distribution rate cases with the PAPUC, 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 September 30, 2019 and December 31, 2018 , the Registrants had accrued the following undiscounted amounts for environmental liabilities in Other current liabilities and Other deferred credits and other liabilities within their respective Consolidated Balance Sheets: September 30, 2019 December 31, 2018 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 $ 507 $ 346 $ 496 $ 356 Generation 107 — 108 — ComEd 328 327 329 327 PECO 20 18 27 25 BGE 3 1 5 4 PHI 49 — 27 — Pepco 47 — 25 — DPL 1 — 1 — ACE 1 — 1 — Cotter Corporation (Exelon and Generation). The EPA has advised Cotter Corporation (Cotter), a former ComEd subsidiary, that it is potentially liable in connection with radiological contamination at a site known as the West Lake Landfill in Missouri. In 2000, ComEd sold Cotter to an unaffiliated third-party. As part of the sale, ComEd agreed to indemnify Cotter for any liability arising in connection with the West Lake Landfill. In connection with Exelon’s 2001 corporate restructuring, this responsibility to indemnify Cotter was transferred to Generation. Including Cotter, there are three PRPs participating in the West Lake Landfill remediation proceeding. Investigation by Generation has identified a number of other parties who also may be PRPs and could be liable to contribute to the final remedy. Further investigation is ongoing. In September 2018 the EPA issued its Record of Decision (ROD) Amendment for the selection of the final remedy. The ROD modified the EPA’s previously proposed plan for partial excavation of the radiological materials by reducing the depths of the excavation. The ROD also allows for variation in depths of excavation depending on radiological concentrations. The EPA and the PRPs have entered into a Consent Agreement to perform the Remedial Design, which is expected to be completed in the 2020 - 2021 time frame. In March 2019 the PRPs received Special Notice Letters from the EPA to perform the Remedial Action work. The EPA has established a deadline of October 2019 for the PRPs to provide a good faith offer to conduct, or finance, the Remedial Action work . This schedule can be extended by the EPA pending completion of the Remedial Design. The estimated cost of the remedy, taking into account the current EPA technical requirements and the total costs expected to be incurred by the PRPs in fully executing the remedy, is approximately $280 million , including cost escalation on an undiscounted basis, which would be allocated among the final group of PRPs. Generation has determined that a loss associated with the EPA’s partial excavation and enhanced landfill cover remedy is probable and has recorded a liability included in the table above, that reflects management’s best estimate of Cotter’s allocable share of the ultimate cost. Given the joint and several nature of this liability, the magnitude of Generation’s ultimate liability will depend on the actual costs incurred to implement the required remediation remedy as well as on the nature and terms of any cost-sharing arrangements with the final group of PRPs. Therefore, it is reasonably possible that the ultimate cost and Generation’s associated allocable share could differ significantly once these uncertainties are resolved, which could have a material impact on Exelon's and Generation's future financial statements. One of the other PRPs has indicated it will be making a contribution claim against Cotter for costs that it has incurred to prevent the subsurface fire from spreading to those areas of the West Lake Landfill where radiological materials are believed to have been disposed. At this time, Exelon and Generation do not possess sufficient information to assess this claim and therefore are unable to estimate a range of loss, if any. As such, no liability has been recorded for the potential contribution claim. It is reasonably possible, however, that resolution of this matter could have a material, unfavorable impact on Exelon’s and Generation's financial statements. In January 2018, the PRPs were advised by the EPA that it will begin an additional investigation and evaluation of groundwater conditions at the West Lake Landfill. In September 2018, the PRPs agreed to an Administrative Settlement Agreement and Order on Consent for the performance by the PRPs of the groundwater RI/FS. The purpose of this RI/FS is to define the nature and extent of any groundwater contamination from the West Lake Landfill site and evaluate remedial alternatives. Generation estimates the undiscounted cost for the groundwater RI/FS to be approximately $20 million . Generation determined a loss associated with the RI/FS is probable and has recorded a liability included in the table above that reflects management’s best estimate of Cotter’s allocable share of the cost among the PRPs. At this time Generation cannot predict the likelihood or the extent to which, if any, remediation activities may be required and therefore cannot estimate a reasonably possible range of loss for response costs beyond those associated with the RI/FS component. It is reasonably possible, however, that resolution of this matter could have a material, unfavorable impact on Exelon’s and Generation’s future financial statements. In August 2011, Cotter was notified by the DOJ that Cotter is considered a PRP with respect to the government’s clean-up costs for contamination attributable to low level radioactive residues at a former storage and reprocessing facility named Latty Avenue near St. Louis, Missouri. The Latty Avenue site is included in ComEd’s indemnification responsibilities discussed above as part of the sale of Cotter. The radioactive residues had been generated initially in connection with the processing of uranium ores as part of the U.S. Government’s Manhattan Project. Cotter purchased the residues in 1969 for initial processing at the Latty Avenue facility for the subsequent extraction of uranium and metals. In 1976, the NRC found that the Latty Avenue site had radiation levels exceeding NRC criteria for decontamination of land areas. Latty Avenue was investigated and remediated by the United States Army Corps of Engineers pursuant to funding under FUSRAP. The DOJ has not yet formally advised the PRPs of the amount that it is seeking, but it is believed to be approximately $90 million from all PRPs. Pursuant to a series of annual agreements since 2011, the DOJ and the PRPs have tolled the statute of limitations until February 2020 so that settlement discussions could proceed. Generation has determined that a loss associated with this matter is probable under its indemnification agreement with Cotter and has recorded an estimated liability, which is included in the table above. Benning Road Site (Exelon, Generation, 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 was formerly the location of a Pepco Energy Services electric generating facility, which 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 with the DOEE, which requires Pepco and Pepco Energy Services to conduct a Remediation Investigation (RI)/ Feasibility Study (FS) for the Benning Road site and an approximately 10 to 15-acre portion of the adjacent Anacostia River. Since 2013, Pepco and Pepco Energy Services (now Generation, pursuant to Exelon's 2016 acquisition of PHI) have been performing RI work and have submitted multiple draft RI reports to the DOEE. Once the RI work is completed, Pepco and Generation will issue a draft “final” RI report for review and comment by DOEE and the public. Pepco and Generation will then proceed to develop a FS to evaluate possible remedial alternatives for submission to DOEE. The Court has established a schedule for completion of the RI and FS, and approval by the DOEE, by September 16, 2021. DOEE will then prepare a Proposed Plan and issue a Record of Decision identifying any further response actions determined to be necessary, after considering public comment on the Proposed Plan. PHI, Pepco and Generation 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 Pepco and Generation, DOEE and the National Park Service 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 Pepco and Pepco Energy Services 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. DOEE asked Pepco, along with parties responsible for other sites along the river, to participate in a "Consultative Working Group" to provide input into the process for future remedial actions and to ensure proper coordination with the other river cleanup efforts currently underway, including cleanup of the river segment adjacent to the Benning Road site resulting from the Benning Road site RI/FS. In addition, the District of Columbia Council directed DOEE to form an official advisory committee made up of members of federal, state and local environmental regulators, community and environmental groups and various academic and technical experts to provide guidance and support to DOEE as the project progressed. This group, called the Anacostia Leadership Council, has met regularly since it was formed. Pepco has participated in the Consultative Working Group. 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. The District of Columbia Council has set a deadline of December 31, 2019 for completion of the Record of Decision. An appropriate liability for Pepco’s share of investigation costs has been accrued and is included in the table above. Pepco has 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 based on DOEE’s stated position following a series of meetings attended by representatives from the Anacostia Leadership Council and the Consultative Working Group. A draft FS, which Pepco believes will include the process to identify potential short-term remedies and actions based on the technical findings in the RI report and their estimated costs to the extent possible, is being prepared by DOEE and is expected later in the fourth quarter of 2019. DOEE and likely the National Park Service will continue to oversee ongoing remediation efforts and potential longer-term remedies for the Anacostia River. Pepco has concluded that incremental exposure remains reasonably possible, however management cannot reasonably estimate a range of loss beyond the amounts recorded, which are included in the table above. In addition to the activities associated with the remedial process outlined above, there is a complementary statutory program that requires an assessment to determine if any natural resources have been damaged as a result of the contamination that is being remediated, and, if so, that a plan be developed by the federal, state and local Natural Resource Damage Trustees, who are defined by CERCLA as the responsible parties for the restoration or compensation for any loss of those resources from the environmental contaminants at the site. If natural resources cannot be restored, then compensation for the injury can be sought from the responsible parties. The assessment of Natural Resource Damages (NRD) typically takes place following cleanup because cleanups sometimes also effectively restore habitat. During the second quarter of 2018, Pepco became aware that the Trustees are in the beginning stages of this process that often takes many years beyond the remedial decision to complete. 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 it cannot reasonably estimate the range of loss. Litigation and Regulatory Matters Asbestos Personal Injury Claims (Exelon and Generation). Generation maintains a reserve for claims associated with asbestos-related personal injury actions in certain facilities that are currently owned by Generation or were previously owned by ComEd and PECO. The estimated liabilities are recorded on an undiscounted basis and exclude the estimated legal costs associated with handling these matters, which could be material. At September 30, 2019 and December 31, 2018 , Exelon and Generation had recorded estimated liabilities of approximately $83 million and $79 million , respectively, in total for asbestos-related bodily injury claims. As of September 30, 2019 , approximately $25 million of this amount related to 257 open claims presented to Generation, while the remaining $58 million is for estimated future asbestos-related bodily injury claims anticipated to arise through 2055, based on actuarial assumptions and analyses, which are updated on an annual basis. On a quarterly basis, Generation monitors actual experience against the number of forecasted claims to be received and expected claim payments and evaluates whether adjustments to the estimated liabilities are necessary. It is reasonably possible that additional exposure to estimated future asbestos-related bodily injury claims in excess of the amount accrued could have a material, unfavorable impact on Exelon’s and Generation’s financial statements. City of Everett Tax Increment Financing Agreement (Exelon and Generation). On April 10, 2017, the City of Everett petitioned the Massachusetts Economic Assistance Coordinating Council (EACC) to revoke the 1999 tax increment financing agreement (TIF Agreement) relating to Mystic Units 8 and 9 on the grounds that the total investment in Mystic Units 8 and 9 materially deviates from the investment set forth in the TIF Agreement. On October 31, 2017, a three-member panel of the EACC conducted an administrative hearing on the City’s petition. On November 30, 2017, the hearing panel issued a tentative decision denying the City’s petition, finding that there was no material misrepresentation that would justify revocation of the TIF Agreement. On December 13, 2017, the tentative decision was adopted by the full EACC. On January 12, 2018, the City filed a complaint in Massachusetts Superior Court requesting, among other things, that the court set aside the EACC’s decision, grant the City’s request to decertify the Project and the TIF Agreement, and award the City damages for alleged underpaid taxes over the period of the TIF Agreement. Generation vigorously contested the City’s claims before the EACC and will continue to do so in the Massachusetts Superior Court proceeding. Generation continues to believe that the City’s claim lacks merit. Accordingly, Generation has not recorded a liability for payment resulting from such a revocation, nor can Generation estimate a reasonably possible range of loss, if any, associated with any such revocation. Further, it is reasonably possible that property taxes assessed in future periods, including those following the expiration of the current TIF Agreement in 2020, could be material to Generation’s financial statements. Subpoenas (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 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 U.S. Attorney's Office for the Northern District of Illinois requiring production of records of any communications with certain individuals and entities. On October 22, 2019, the SEC notified Exelon and ComEd that it has also opened an investigation into their lobbying activities. Exelon and ComEd have cooperated fully and intend to continue to cooperate fully and expeditiously with the U.S. Attorney’s Office and the SEC. Exelon and ComEd cannot predict the outcome of the subpoenas or the SEC investigation. 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. |
Supplemental Financial Informat
Supplemental Financial Information (All Registrants) | 9 Months Ended |
Sep. 30, 2019 | |
Supplemental Financial Information [Abstract] | |
Supplemental Financial Information (All Registrants) | 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 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Three Months Ended September 30, 2019 Utility taxes (a) $ 241 $ 29 $ 66 $ 38 $ 21 $ 86 $ 81 $ 5 $ — Property 148 66 7 5 39 31 21 9 — Payroll 57 28 7 3 4 6 2 1 1 Three Months Ended September 30, 2018 Utility taxes (a) $ 253 $ 32 $ 67 $ 39 $ 23 $ 92 $ 87 $ 5 $ — Property 145 70 7 4 37 26 16 9 — Payroll 58 31 6 3 4 5 1 1 1 Nine Months Ended September 30, 2019 Utility taxes (a) $ 672 $ 87 $ 183 $ 102 $ 68 $ 231 $ 217 $ 14 $ — Property 444 205 22 12 114 91 64 25 2 Payroll 185 92 21 11 13 20 5 3 2 Nine Months Ended September 30, 2018 Utility taxes (a) $ 705 $ 92 $ 188 $ 102 $ 70 $ 253 $ 238 $ 15 $ — Property 416 204 22 12 106 71 45 24 2 Payroll 191 99 20 11 12 19 5 3 2 _________ (a) Generation’s utility tax represents gross receipts tax related to its retail operations, and the Utility Registrants' utility taxes represents 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 Generation ComEd PECO BGE PHI Pepco DPL ACE Three Months Ended September 30, 2019 Decommissioning-related activities: Net realized income on NDT funds (a) Regulatory agreement units $ 67 $ 67 $ — $ — $ — $ — $ — $ — $ — Non-regulatory agreement units 33 33 — — — — — — — Net unrealized gains on NDT funds Regulatory agreement units 89 89 — — — — — — — Non-regulatory agreement units 55 55 — — — — — — — Regulatory offset to NDT fund-related activities (b) (125 ) (125 ) — — — — — — — Decommissioning-related activities 119 119 — — — — — — — AFUDC — Equity 22 — 4 3 6 9 7 1 1 Non-service net periodic benefit cost (2 ) — — — — — — — — Three Months Ended September 30, 2018 Decommissioning-related activities: Net realized income on NDT funds (a) Regulatory agreement units $ 214 $ 214 $ — $ — $ — $ — $ — $ — $ — Non-regulatory agreement units 58 58 — — — — — — — Net unrealized (losses) gains on NDT funds Regulatory agreement units (66 ) (66 ) — — — — — — — Non-regulatory agreement units 72 72 — — — — — — — Regulatory offset to NDT fund-related activities (b) (110 ) (110 ) — — — — — — — Decommissioning-related activities 168 168 — — — — — — — AFUDC — Equity 16 — 4 1 5 6 6 — — Non-service net periodic benefit cost (12 ) — — — — — — — — Other, Net Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Nine Months Ended September 30, 2019 Decommissioning-related activities: Net realized income on NDT funds (a) Regulatory agreement units $ 197 $ 197 $ — $ — $ — $ — $ — $ — $ — Non-regulatory agreement units 316 316 — — — — — — — Net unrealized gains on NDT funds Regulatory agreement units 565 565 — — — — — — — Non-regulatory agreement units 236 236 — — — — — — — Regulatory offset to NDT fund-related activities (b) (611 ) (611 ) — — — — — — — Decommissioning-related activities 703 703 — — — — — — — AFUDC — Equity 64 — 13 9 16 26 18 3 4 Non-service net periodic benefit cost 8 — — — — — — — — Nine Months Ended September 30, 2018 Decommissioning-related activities: Net realized income on NDT funds (a) Regulatory agreement units $ 476 $ 476 $ — $ — $ — $ — $ — $ — $ — Non-regulatory agreement units 257 257 — — — — — — — Net unrealized losses on NDT funds Regulatory agreement units (335 ) (335 ) — — — — — — — Non-regulatory agreement units (143 ) (143 ) — — — — — — — Regulatory offset to NDT fund-related activities (b) (110 ) (110 ) — — — — — — — Decommissioning-related activities 145 145 — — — — — — — AFUDC — Equity 47 — 12 3 13 19 17 2 — Non-service net periodic benefit cost (33 ) — — — — — — — — _________ (a) Realized income includes interest, dividends and realized gains and losses on sales of NDT fund investments. (b) Includes the elimination of decommissioning-related activities for the Regulatory Agreement Units, including the elimination of income taxes related to all NDT fund activity for those units. See Note 15 — Asset Retirement Obligations of the Exelon 2018 Form 10-K for additional information regarding the accounting for nuclear decommissioning. Supplemental Cash Flow Information The following tables provide additional information about material items recorded in the Registrants' Consolidated Statements of Cash Flows. Depreciation, amortization and accretion Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Nine Months Ended September 30, 2019 Property, plant and equipment (a) $ 2,803 $ 1,184 $ 661 $ 225 $ 263 $ 405 $ 178 $ 109 $ 89 Amortization of regulatory assets (a) 390 — 106 22 105 157 103 29 25 Amortization of intangible assets, net (a) 44 37 — — — — — — — Amortization of energy contract assets and liabilities (b) 14 14 — — — — — — — Nuclear fuel (c) 771 771 — — — — — — — ARO accretion (d) 371 371 — — — — — — — Total depreciation, amortization and accretion $ 4,393 $ 2,377 $ 767 $ 247 $ 368 $ 562 $ 281 $ 138 $ 114 Nine Months Ended September 30, 2018 Property, plant and equipment (a) $ 2,829 $ 1,347 $ 613 $ 204 $ 249 $ 355 $ 161 $ 97 $ 70 Amortization of regulatory assets (a) 412 — 83 20 109 200 125 38 37 Amortization of intangible assets, net (a) 43 36 — — — — — — — Amortization of energy contract assets and liabilities (b) 8 8 — — — — — — — Nuclear fuel (c) 852 852 — — — — — — — ARO accretion (d) 367 365 — — — — — — — Total depreciation, amortization and accretion $ 4,511 $ 2,608 $ 696 $ 224 $ 358 $ 555 $ 286 $ 135 $ 107 _________ (a) Included in Depreciation and amortization in the Registrants' Consolidated Statements of Operations and Comprehensive Income. (b) Included in Operating revenues or Purchased power and fuel expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. (c) Included in Purchased power and fuel expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. (d) Included in Operating and maintenance expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. Other non-cash operating activities Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Nine Months Ended September 30, 2019 Pension and non-pension postretirement benefit costs $ 324 $ 98 $ 70 $ 9 $ 45 $ 71 $ 19 $ 11 $ 12 Provision for uncollectible accounts 89 20 26 22 5 16 7 2 6 Other decommissioning-related activity (a) (400 ) (400 ) — — — — — — — Energy-related options (b) 21 21 — — — — — — — Amortization of rate stabilization deferral (8 ) — — — — (8 ) (9 ) 1 — Discrete impacts from EIMA and FEJA (c) 80 — 80 — — — — — — Long-term incentive plan 33 — — — — — — — — Amortization of operating ROU asset 193 138 2 — 23 26 6 7 4 Change in environmental liabilities 23 — — — — 23 23 — — Nine Months Ended September 30, 2018 Pension and non-pension postretirement benefit costs $ 435 $ 151 $ 133 $ 14 $ 43 $ 51 $ 10 $ 5 $ 10 Provision for uncollectible accounts 133 38 30 25 6 32 12 6 14 Other decommissioning-related activity (a) (39 ) (39 ) — — — — — — — Energy-related options (b) 4 4 — — — — — — — Amortization of rate stabilization deferral — — — — — — — — — Discrete impacts from EIMA and FEJA (c) 27 — 27 — — — — — — Long-term incentive plan 84 — — — — — — — — Asset retirement costs 20 — — — — 20 22 (1 ) (1 ) _______ (a) Includes the elimination of decommissioning-related activity for the Regulatory Agreement Units, including the elimination of operating revenues, ARO accretion, ARC amortization, investment income and income taxes related to all NDT fund activity for these units. See Note 15 — Asset Retirement Obligations of the Exelon 2018 Form 10-K for additional information regarding the accounting for nuclear decommissioning. (b) Includes option premiums reclassified to realized at the settlement of the underlying contracts and recorded in Operating revenues and expenses. (c) Reflects the change in ComEd's distribution and energy efficiency formula rates. See Note 6 — Regulatory Matters 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 Generation ComEd PECO BGE PHI Pepco DPL ACE September 30, 2019 Cash and cash equivalents $ 1,683 $ 1,019 $ 76 $ 224 $ 130 $ 99 $ 18 $ 11 $ 13 Restricted cash 309 126 124 6 1 38 34 — 3 Restricted cash included in other long-term assets 186 — 171 — — 15 — — 15 Total cash, cash equivalents and restricted cash $ 2,178 $ 1,145 $ 371 $ 230 $ 131 $ 152 $ 52 $ 11 $ 31 December 31, 2018 Cash and cash equivalents $ 1,349 $ 750 $ 135 $ 130 $ 7 $ 124 $ 16 $ 23 $ 7 Restricted cash 247 153 29 5 6 43 37 1 4 Restricted cash included in other long-term assets 185 — 166 — — 19 — — 19 Total cash, cash equivalents and restricted cash $ 1,781 $ 903 $ 330 $ 135 $ 13 $ 186 $ 53 $ 24 $ 30 September 30, 2018 Cash and cash equivalents $ 1,918 $ 1,187 $ 124 $ 102 $ 113 $ 153 $ 12 $ 110 $ 11 Restricted cash 240 152 12 5 3 42 35 — 7 Restricted cash included in other long-term assets 163 — 144 — — 19 — — 19 Total cash, cash equivalents and restricted cash $ 2,321 $ 1,339 $ 280 $ 107 $ 116 $ 214 $ 47 $ 110 $ 37 December 31, 2017 Cash and cash equivalents $ 898 $ 416 $ 76 $ 271 $ 17 $ 30 $ 5 $ 2 $ 2 Restricted cash 207 138 5 4 1 42 35 — 6 Restricted cash included in other long-term assets 85 — 63 — — 23 — — 23 Total cash, cash equivalents and restricted cash $ 1,190 $ 554 $ 144 $ 275 $ 18 $ 95 $ 40 $ 2 $ 31 For additional information on restricted cash see Note 1 — Significant Accounting Policies of the Exelon 2018 Form 10-K. Supplemental Balance Sheet Information The following tables provide additional information about material items recorded in the Registrants' Consolidated Balance Sheets. Unbilled customer revenues Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE September 30, 2019 $ 1,256 $ 676 $ 212 $ 102 $ 103 $ 163 $ 91 $ 38 $ 34 December 31, 2018 1,656 965 223 114 168 186 97 59 30 Accrued expenses Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE September 30, 2019 Compensation-related accruals (a) $ 880 $ 336 $ 133 $ 48 $ 63 $ 86 $ 26 $ 17 $ 13 Taxes accrued 431 247 56 13 64 80 61 17 3 Interest accrued 421 106 62 33 36 78 37 20 19 December 31, 2018 Compensation-related accruals (a) $ 1,191 $ 479 $ 187 $ 49 $ 68 $ 99 $ 29 $ 19 $ 12 Taxes accrued 412 226 71 28 46 74 58 4 5 Interest accrued 334 77 105 33 39 50 25 8 12 _________ (a) Primarily includes accrued payroll, bonuses and other incentives, vacation and benefits. |
Segment Information (All Regist
Segment Information (All Registrants) | 9 Months Ended |
Sep. 30, 2019 | |
Segment Reporting [Abstract] | |
Segment Information (All Registrants) | Segment Information (All Registrants) Operating segments for each of the Registrants are determined based on information used by the CODM in deciding how to evaluate performance and allocate resources at each of the Registrants. Exelon has eleven reportable segments, which include Generation's five reportable segments consisting of the Mid-Atlantic, Midwest, New York, ERCOT and all other power regions referred to collectively as “Other Power Regions” and 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. The basis for Generation's reportable segments is the integrated management of its electricity business that is located in different geographic regions, and largely representative of the footprints of ISO/RTO and/or NERC regions, which utilize multiple supply sources to provide electricity through various distribution channels (wholesale and retail). Generation's hedging strategies and risk metrics are also aligned to these same geographic regions. Descriptions of each of Generation’s five reportable segments are as follows: • Mid-Atlantic represents operations in the eastern half of PJM, which includes New Jersey, Maryland, Virginia, West Virginia, Delaware, the District of Columbia and parts of Pennsylvania and North Carolina. • Midwest represents operations in the western half of PJM and the United States footprint of MISO, excluding MISO’s Southern Region. • New York represents operations within ISO-NY. • ERCOT represents operations within Electric Reliability Council of Texas. • Other Power Regions: • New England represents the operations within ISO-NE. • South represents operations in the FRCC, MISO’s Southern Region, and the remaining portions of the SERC not included within MISO or PJM. • West represents operations in the WECC, which includes California ISO. • Canada represents operations across the entire country of Canada and includes AESO, OIESO and the Canadian portion of MISO. The CODMs for Exelon and Generation evaluate the performance of Generation’s electric business activities and allocate resources based on RNF. Generation believes that RNF is a useful measurement of operational performance. RNF is not a presentation defined under GAAP and may not be comparable to other companies’ presentations or deemed more useful than the GAAP information provided elsewhere in this report. Generation’s operating revenues include all sales to third parties and affiliated sales to the Utility Registrants. Purchased power costs include all costs associated with the procurement and supply of electricity including capacity, energy and ancillary services. Fuel expense includes the fuel costs for Generation’s owned generation and fuel costs associated with tolling agreements. The results of Generation's other business activities are not regularly reviewed by the CODM and are therefore not classified as operating segments or included in the regional reportable segment amounts. These activities include natural gas, as well as other miscellaneous business activities that are not significant to Generation's overall operating revenues or results of operations. Further, Generation’s unrealized mark-to-market gains and losses on economic hedging activities and its amortization of certain intangible assets and liabilities relating to commodity contracts recorded at fair value from mergers and acquisitions are also excluded from the regional reportable segment amounts. Exelon and Generation do not use a measure of total assets in making decisions regarding allocating resources to or assessing the performance of these reportable segments. During the first quarter of 2019, due to a change in economics in our New England region, Generation changed the way that information is reviewed by the CODM. The New England region is no longer regularly reviewed as a separate region by the CODM nor is it presented separately in any external information presented to third parties. Information for the New England region is reviewed by the CODM as part of Other Power Regions. Exelon and Generation retrospectively applied this change. An analysis and reconciliation of the Registrants’ reportable segment information to the respective information in the consolidated financial statements for the three and nine months ended September 30, 2019 and 2018 is as follows: Three Months Ended September 30, 2019 and 2018 Generation (a) ComEd PECO BGE PHI Other (b) Intersegment Exelon Operating revenues (c) : 2019 Competitive businesses electric revenues $ 4,314 $ — $ — $ — $ — $ — $ (275 ) $ 4,039 Competitive businesses natural gas revenues 265 — — — — — 1 266 Competitive businesses other revenues 195 — — — — — (1 ) 194 Rate-regulated electric revenues — 1,583 716 619 1,357 — (7 ) 4,268 Rate-regulated natural gas revenues — — 62 84 20 — (3 ) 163 Shared service and other revenues — — — — 3 474 (478 ) (1 ) Total operating revenues $ 4,774 $ 1,583 $ 778 $ 703 $ 1,380 $ 474 $ (763 ) $ 8,929 Generation (a) ComEd PECO BGE PHI Other (b) Intersegment Exelon 2018 Competitive businesses electric revenues $ 4,741 $ — $ — $ — $ — $ — $ (306 ) $ 4,435 Competitive businesses natural gas revenues 397 — — — — — — 397 Competitive businesses other revenues 140 — — — — — (1 ) 139 Rate-regulated electric revenues — 1,598 700 645 1,334 — (7 ) 4,270 Rate-regulated natural gas revenues — — 57 86 24 — (5 ) 162 Shared service and other revenues — — — — 3 458 (461 ) — Total operating revenues $ 5,278 $ 1,598 $ 757 $ 731 $ 1,361 $ 458 $ (780 ) $ 9,403 Intersegment revenues (d) : 2019 $ 275 $ 4 $ 1 $ 6 $ 4 $ 474 $ (764 ) $ — 2018 308 4 2 6 3 456 (779 ) — Depreciation and amortization: 2019 $ 407 $ 259 $ 83 $ 116 $ 193 $ 25 $ — $ 1,083 2018 468 237 75 110 192 23 — 1,105 Operating expenses: 2019 $ 4,274 $ 1,256 $ 595 $ 612 $ 1,124 $ 457 $ (759 ) $ 7,559 2018 4,961 1,275 603 628 1,116 459 (790 ) 8,252 Interest expense, net: 2019 $ 109 $ 91 $ 33 $ 31 $ 66 $ 79 $ — $ 409 2018 101 85 32 27 65 83 — 393 Income (loss) before income taxes: 2019 $ 501 $ 245 $ 154 $ 67 $ 203 $ (68 ) $ — $ 1,102 2018 389 245 124 81 191 (83 ) — 947 Income Taxes: 2019 $ 87 $ 45 $ 14 $ 12 $ 14 $ — $ — $ 172 2018 78 52 (2 ) 18 4 (13 ) — 137 Net income (loss): 2019 $ 244 $ 200 $ 140 $ 55 $ 189 $ (68 ) $ — $ 760 2018 300 193 126 63 187 (69 ) — 800 Capital Expenditures 2019 $ 392 $ 452 $ 228 $ 300 $ 308 $ 7 $ — $ 1,687 2018 362 514 204 233 359 18 — 1,690 __________ (a) Intersegment revenues for Generation in 2019 include revenue from sales to PECO of $43 million , sales to BGE of $65 million , sales to Pepco of $65 million , sales to DPL of $14 million and sales to ACE of $3 million in the Mid-Atlantic region, and sales to ComEd of $83 million in the Midwest region, which eliminate upon consolidation. Intersegment revenues for Generation in 2018 include revenue from sales to PECO of $35 million , sales to BGE of $69 million , sales to Pepco of $46 million , sales to DPL of $26 million and sales to ACE of $10 million in the Mid-Atlantic region, and sales to ComEd of $122 million in the Midwest region, which eliminate upon consolidation. (b) Other primarily includes Exelon’s corporate operations, shared service entities and other financing and investment activities. (c) 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 17 — Supplemental Financial Information for additional information on total utility taxes. (d) Intersegment revenues exclude sales to unconsolidated affiliates. The intersegment profit associated with Generation’s sale of certain products and services by and between Exelon’s segments is not eliminated in consolidation due to the recognition of intersegment profit in accordance with regulatory accounting guidance. For Exelon, these amounts are included in Operating revenues in the Consolidated Statements of Operations and Comprehensive Income. PHI: Pepco DPL ACE Other (b) Intersegment PHI Operating revenues (a) : 2019 Rate-regulated electric revenues $ 642 $ 299 $ 419 $ — $ (3 ) $ 1,357 Rate-regulated natural gas revenues — 20 — — — 20 Shared service and other revenues — — — 92 (89 ) 3 Total operating revenues $ 642 $ 319 $ 419 $ 92 $ (92 ) $ 1,380 2018 Rate-regulated electric revenues $ 628 $ 304 $ 406 $ — $ (4 ) $ 1,334 Rate-regulated natural gas revenues — 24 — — — 24 Shared service and other revenues — — — 103 (100 ) 3 Total operating revenues $ 628 $ 328 $ 406 $ 103 $ (104 ) $ 1,361 Intersegment revenues: 2019 $ 2 $ 1 $ 1 $ 93 $ (93 ) $ 4 2018 2 2 1 103 (105 ) 3 Depreciation and amortization: 2019 $ 95 $ 46 $ 43 $ 9 $ — $ 193 2018 99 47 38 8 — 192 Operating expenses: 2019 $ 515 $ 268 $ 340 $ 95 $ (94 ) $ 1,124 2018 516 277 322 105 (104 ) 1,116 Interest expense, net: 2019 $ 33 $ 15 $ 15 $ 3 $ — $ 66 2018 32 15 16 2 — 65 Income (loss) before income taxes: 2019 $ 103 $ 38 $ 65 $ 192 $ (195 ) $ 203 2018 87 38 69 179 (182 ) 191 Income Taxes: 2019 $ 5 $ 5 $ 2 $ 3 $ (1 ) $ 14 2018 (2 ) 5 8 (8 ) 1 4 Net income (loss): 2019 $ 98 $ 33 $ 63 $ (9 ) $ 4 $ 189 2018 89 33 61 1 3 187 Capital Expenditures 2019 $ 157 $ 85 $ 73 $ (7 ) $ — $ 308 2018 188 88 77 6 — 359 __________ (a) 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 17 — Supplemental Financial Information for additional information on total utility taxes. (b) Other primarily includes PHI’s corporate operations, shared service entities and other financing and investment activities. The following tables disaggregate the Registrants' 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. For Generation, the disaggregation of revenues reflects Generation’s two primary products of power sales and natural gas sales, with further disaggregation of power sales provided by geographic region. For the Utility Registrants, the disaggregation of revenues reflects the two primary utility services of rate-regulated electric sales and rate-regulated natural gas sales (where applicable), with further disaggregation of these tariff sales provided by major customer groups. Exelon’s disaggregated revenues are consistent with Generation and the Utility Registrants, but exclude any intercompany revenues. Competitive Business Revenues (Generation): Three Months Ended September 30, 2019 Revenues from external customers (a) Intersegment Total Contracts with customers Other (b) Total Mid-Atlantic $ 1,351 $ 10 $ 1,361 $ 3 $ 1,364 Midwest 1,052 47 1,099 (17 ) 1,082 New York 414 15 429 — 429 ERCOT 288 72 360 5 365 Other Power Regions 873 192 1,065 (25 ) 1,040 Total Competitive Businesses Electric Revenues 3,978 336 4,314 (34 ) 4,280 Competitive Businesses Natural Gas Revenues 160 105 265 34 299 Competitive Businesses Other Revenues (c) 112 83 195 — 195 Total Generation Consolidated Operating Revenues $ 4,250 $ 524 $ 4,774 $ — $ 4,774 Three Months Ended September 30, 2018 Revenues from external customers (a) Intersegment Total Contracts with customers Other (b) Total Mid-Atlantic $ 1,397 $ 52 $ 1,449 $ 7 $ 1,456 Midwest 1,095 26 1,121 (4 ) 1,117 New York 475 (6 ) 469 — 469 ERCOT 156 289 445 (1 ) 444 Other Power Regions 959 298 1,257 (45 ) 1,212 Total Competitive Businesses Electric Revenues 4,082 659 4,741 (43 ) 4,698 Competitive Businesses Natural Gas Revenues 200 197 397 43 440 Competitive Businesses Other Revenues (c) 130 10 140 — 140 Total Generation Consolidated Operating Revenues $ 4,412 $ 866 $ 5,278 $ — $ 5,278 __________ (a) Includes all wholesale and retail electric sales to third parties and affiliated sales to the Utility Registrants. (b) Includes revenues from derivatives and leases. (c) Other represents activities not allocated to a region. See text above for a description of included activities. Includes unrealized mark-to-market gains of $77 million and $6 million in 2019 and 2018 , respectively, and elimination of intersegment revenues. Revenues net of purchased power and fuel expense (Generation): Three Months Ended September 30, 2019 Three Months Ended September 30, 2018 RNF (a) Intersegment RNF Total RNF RNF (a) Intersegment RNF Total RNF Mid-Atlantic $ 684 $ 5 $ 689 $ 746 $ 17 $ 763 Midwest 763 (16 ) 747 763 5 768 New York 288 3 291 290 2 292 ERCOT 76 (4 ) 72 161 (63 ) 98 Other Power Regions 212 (28 ) 184 226 (46 ) 180 Total Revenues net of purchased power and fuel for Reportable Segments 2,023 (40 ) 1,983 2,186 (85 ) 2,101 Other (b) 100 40 140 112 85 197 Total Generation Revenues net of purchased power and fuel expense $ 2,123 $ — $ 2,123 $ 2,298 $ — $ 2,298 __________ (a) Includes purchases and sales from/to third parties and affiliated sales to the Utility Registrants. (b) Other represents activities not allocated to a region. See text above for a description of included activities. Includes unrealized mark-to-market gains of $17 million and $71 million in 2019 and 2018 , respectively, accelerated nuclear fuel amortization associated with announced early plant retirements as discussed in Note 8 — Early Plant Retirements of $3 million and $18 million decrease to RNF in 2019 and 2018 , respectively, and the elimination of intersegment RNF. Electric and Gas Revenue by Customer Class (Utility Registrants): Three Months Ended September 30, 2019 Revenues from contracts with customers ComEd PECO BGE PHI Pepco DPL ACE Rate-regulated electric revenues Residential $ 865 $ 479 $ 352 $ 741 $ 311 $ 178 $ 252 Small commercial & industrial 393 109 64 147 41 48 58 Large commercial & industrial 141 63 116 297 222 26 49 Public authorities & electric railroads 12 9 7 17 11 3 3 Other (a) 222 63 82 164 58 50 56 Total rate-regulated electric revenues (b) $ 1,633 $ 723 $ 621 $ 1,366 $ 643 $ 305 $ 418 Rate-regulated natural gas revenues Residential $ — $ 38 $ 49 $ 9 $ — $ 9 $ — Small commercial & industrial — 17 9 4 — 4 — Large commercial & industrial — — 20 1 — 1 — Transportation — 5 — 4 — 4 — Other (c) — 2 5 2 — 2 — Total rate-regulated natural gas revenues (d) $ — $ 62 $ 83 $ 20 $ — $ 20 $ — Total rate-regulated revenues from contracts with customers $ 1,633 $ 785 $ 704 $ 1,386 $ 643 $ 325 $ 418 Other revenues Revenues from alternative revenue programs $ (56 ) $ (11 ) $ (5 ) $ (9 ) $ (3 ) $ (6 ) $ 1 Other rate-regulated electric revenues (e) 6 4 3 3 2 — — Other rate-regulated natural gas revenues (e) — — 1 — — — — Total other revenues $ (50 ) $ (7 ) $ (1 ) $ (6 ) $ (1 ) $ (6 ) $ 1 Total rate-regulated revenues for reportable segments $ 1,583 $ 778 $ 703 $ 1,380 $ 642 $ 319 $ 419 Three Months Ended September 30, 2018 Revenues from contracts with customers ComEd PECO BGE PHI Pepco DPL ACE Rate-regulated electric revenues Residential $ 861 $ 458 $ 366 $ 726 $ 306 $ 180 $ 240 Small commercial & industrial 391 108 68 140 39 48 53 Large commercial & industrial 131 64 117 303 230 25 48 Public authorities & electric railroads 11 7 7 14 8 3 3 Other (a) 212 59 91 156 47 47 63 Total rate-regulated electric revenues (b) $ 1,606 $ 696 $ 649 $ 1,339 $ 630 $ 303 $ 407 Rate-regulated natural gas revenues Residential $ — $ 36 $ 46 $ 8 $ — $ 8 $ — Small commercial & industrial — 15 8 5 — 5 — Large commercial & industrial — — 17 2 — 2 — Transportation — 5 — 3 — 3 — Other (c) — 1 12 6 — 6 — Total rate-regulated natural gas revenues (d) $ — $ 57 $ 83 $ 24 $ — $ 24 $ — Total rate-regulated revenues from contracts with customers $ 1,606 $ 753 $ 732 $ 1,363 $ 630 $ 327 $ 407 Other revenues Revenues from alternative revenue programs $ (15 ) $ 1 $ (6 ) $ (5 ) $ (4 ) $ — $ (1 ) Other rate-regulated electric revenues (e) 7 3 4 3 2 1 — Other rate-regulated natural gas revenues (e) — — 1 — — — — Total other revenues $ (8 ) $ 4 $ (1 ) $ (2 ) $ (2 ) $ 1 $ (1 ) Total rate-regulated revenues for reportable segments $ 1,598 $ 757 $ 731 $ 1,361 $ 628 $ 328 $ 406 __________ (a) Includes revenues from transmission revenue from PJM, wholesale electric revenue and mutual assistance revenue. (b) Includes operating revenues from affiliates of $4 million , $1 million , $2 million , $4 million , $2 million , $1 million and $1 million at ComEd, PECO, BGE, PHI, Pepco, DPL and ACE, respectively, in 2019 and $4 million , $2 million , $1 million , $3 million $2 million , $2 million and $1 million at ComEd, PECO, BGE, PHI, Pepco, DPL and ACE, respectively, in 2018 . (c) Includes revenues from off-system natural gas sales. (d) Includes operating revenues from affiliates of less than $1 million and $4 million at PECO and BGE, respectively, in 2019 and less than $1 million and $5 million at PECO and BGE, respectively, in 2018 . (e) Includes late payment charge revenues. Nine Months Ended September 30, 2019 and 2018 Generation (a) ComEd PECO BGE PHI Other (b) Intersegment Exelon Operating revenues (c) : 2019 Competitive businesses electric revenues $ 12,365 $ — $ — $ — $ — $ — $ (840 ) $ 11,525 Competitive businesses natural gas revenues 1,479 — — — — — — 1,479 Competitive businesses other revenues 436 — — — — — (4 ) 432 Rate-regulated electric revenues — 4,342 1,901 1,817 3,574 — (25 ) 11,609 Rate-regulated natural gas revenues — — 432 510 116 — (12 ) 1,046 Shared service and other revenues — — — — 10 1,410 (1,415 ) 5 Total operating revenues $ 14,280 $ 4,342 $ 2,333 $ 2,327 $ 3,700 $ 1,410 $ (2,296 ) $ 26,096 2018 Competitive businesses electric revenues $ 13,190 $ — $ — $ — $ — $ — $ (969 ) $ 12,221 Competitive businesses natural gas revenues 1,839 — — — — — (8 ) 1,831 Competitive businesses other revenues 339 — — — — — (4 ) 335 Rate-regulated electric revenues — 4,508 1,893 1,850 3,549 — (34 ) 11,766 Rate-regulated natural gas revenues — — 382 519 129 — (13 ) 1,017 Shared service and other revenues — — — — 10 1,398 (1,408 ) — Total operating revenues $ 15,368 $ 4,508 $ 2,275 $ 2,369 $ 3,688 $ 1,398 $ (2,436 ) $ 27,170 Shared service and other revenues Intersegment revenues (d) : 2019 $ 844 $ 13 $ 4 $ 18 $ 11 $ 1,410 $ (2,300 ) $ — 2018 981 23 5 18 11 1,392 (2,430 ) — Depreciation and amortization: 2019 $ 1,221 $ 767 $ 247 $ 368 $ 562 $ 72 $ — $ 3,237 2018 1,383 696 224 358 555 68 — 3,284 Operating expenses: 2019 $ 13,333 $ 3,431 $ 1,783 $ 1,936 $ 3,106 $ 1,405 $ (2,291 ) $ 22,703 2018 14,475 3,610 1,853 2,005 3,165 1,395 (2,467 ) 24,036 Interest expense, net: 2019 $ 336 $ 268 $ 100 $ 89 $ 197 $ 231 $ — $ 1,221 2018 305 261 96 78 193 205 — 1,138 Generation (a) ComEd PECO BGE PHI Other (b) Intersegment Exelon Income (loss) before income taxes: 2019 $ 1,355 $ 674 $ 461 $ 320 $ 436 $ (218 ) $ — $ 3,028 2018 800 663 331 301 363 (195 ) — 2,263 Income Taxes: 2019 $ 388 $ 130 $ 51 $ 59 $ 25 $ (27 ) $ — $ 626 2018 110 140 (5 ) 59 28 (70 ) — 262 Net income (loss): 2019 $ 784 $ 544 $ 410 $ 261 $ 412 $ (191 ) $ — $ 2,220 2018 667 523 336 242 336 (125 ) — 1,979 Capital Expenditures 2019 $ 1,282 $ 1,413 $ 675 $ 842 $ 1,006 $ 41 $ — $ 5,259 2018 1,660 1,540 615 667 988 27 — 5,497 Total assets: September 30, 2019 $ 47,984 $ 32,326 $ 11,379 $ 10,304 $ 22,576 $ 8,254 $ (10,085 ) $ 122,738 December 31, 2018 47,556 31,213 10,642 9,716 21,984 8,355 (9,800 ) 119,666 __________ (a) Intersegment revenues for Generation in 2019 include revenue from sales to PECO of $123 million , sales to BGE of $199 million , sales to Pepco of $188 million , sales to DPL of $50 million and sales to ACE of $16 million in the Mid-Atlantic region, and sales to ComEd of $266 million in the Midwest region, which eliminate upon consolidation. Intersegment revenues for Generation in 2018 include revenue from sales to PECO of $97 million , sales to BGE of $198 million , sales to Pepco of $143 million , sales to DPL of $103 million and sales to ACE of $21 million in the Mid-Atlantic region, and sales to ComEd of $419 million in the Midwest region, which eliminate upon consolidation. (b) Other primarily includes Exelon’s corporate operations, shared service entities and other financing and investment activities. (c) 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 17 — Supplemental Financial Information for additional information on total utility taxes. (d) Intersegment revenues exclude sales to unconsolidated affiliates. The intersegment profit associated with Generation’s sale of certain products and services by and between Exelon’s segments is not eliminated in consolidation due to the recognition of intersegment profit in accordance with regulatory accounting guidance. For Exelon, these amounts are included in Operating revenues in the Consolidated Statements of Operations and Comprehensive Income. PHI: Pepco DPL ACE Other (b) Intersegment PHI Operating revenues (a) : 2019 Rate-regulated electric revenues $ 1,748 $ 871 $ 966 $ (1 ) $ (10 ) $ 3,574 Rate-regulated natural gas revenues — 116 — — — 116 Shared service and other revenues — — — 298 (288 ) 10 Total operating revenues $ 1,748 $ 987 $ 966 $ 297 $ (298 ) $ 3,700 2018 Rate-regulated electric revenues $ 1,708 $ 872 $ 981 $ — $ (12 ) $ 3,549 Rate-regulated natural gas revenues — 129 — — — 129 Shared service and other revenues — — — 326 (316 ) 10 Total operating revenues $ 1,708 $ 1,001 $ 981 $ 326 $ (328 ) $ 3,688 Intersegment revenues: 2019 $ 5 $ 5 $ 2 $ 297 $ (298 ) $ 11 2018 5 6 2 325 (327 ) 11 Depreciation and amortization: 2019 $ 281 $ 138 $ 114 $ 29 $ — $ 562 2018 286 135 107 27 — 555 Operating expenses: 2019 $ 1,444 $ 820 $ 838 $ 302 $ (298 ) $ 3,106 2018 1,454 859 847 329 (324 ) 3,165 Interest expense, net: 2019 $ 100 $ 45 $ 44 $ 8 $ — $ 197 2018 96 42 48 7 — 193 Income (loss) before income taxes: 2019 $ 226 $ 132 $ 89 $ 411 $ (422 ) $ 436 2018 181 107 88 326 (339 ) 363 Income Taxes: 2019 $ 9 $ 16 $ 2 $ (1 ) $ (1 ) $ 25 2018 7 17 12 (8 ) — 28 Net income (loss): 2019 $ 217 $ 116 $ 87 $ (19 ) $ 11 $ 412 2018 174 90 76 (15 ) 11 336 Capital Expenditures 2019 $ 455 $ 245 $ 300 $ 6 $ — $ 1,006 2018 475 254 247 12 — 988 Total assets: September 30, 2019 $ 8,603 $ 4,724 $ 3,916 $ 11,071 $ (5,738 ) $ 22,576 December 31, 2018 8,299 4,588 3,699 10,819 (5,421 ) 21,984 __________ (a) 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 17 — Supplemental Financial Information for additional information on total utility taxes. (b) Other primarily includes PHI’s corporate operations, shared service entities and other financing and investment activities. The following tables disaggregate the Registrants' 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. For Generation, the disaggregation of revenues reflects Generation’s two primary products of power sales and natural gas sales, with further disaggregation of power sales provided by geographic region. For the Utility Registrants, the disaggregation of revenues reflects the two primary utility services of rate-regulated electric sales and rate-regulated natural gas sales (where applicable), with further disaggregation of these tariff sales provided by major customer groups. Exelon’s disaggregated revenues are consistent with Generation and the Utility Registrants, but exclude any intercompany revenues. Competitive Business Revenues (Generation): Nine Months Ended September 30, 2019 Revenues from external customers (a) Intersegment Revenues Total Revenues Contracts with customers Other (b) Total Mid-Atlantic $ 3,798 $ 9 $ 3,807 $ 2 $ 3,809 Midwest 3,083 172 3,255 (31 ) 3,224 New York 1,195 16 1,211 — 1,211 ERCOT 594 198 792 13 805 Other Power Regions 2,849 451 3,300 (46 ) 3,254 Total Competitive Businesses Electric Revenues 11,519 846 12,365 (62 ) 12,303 Competitive Businesses Natural Gas Revenues 1,041 438 1,479 62 1,541 Competitive Businesses Other Revenues (c) 343 93 436 — 436 Total Generation Consolidated Operating Revenues $ 12,903 $ 1,377 $ 14,280 $ — $ 14,280 Nine Months Ended September 30, 2018 Revenues from external customers (a) Intersegment Total Contracts with customers Other (b) Total Mid-Atlantic $ 3,971 $ 191 $ 4,162 $ 17 $ 4,179 Midwest 3,432 169 3,601 (8 ) 3,593 New York 1,305 (37 ) 1,268 1 1,269 ERCOT 470 459 929 1 930 Other Power Regions 2,656 574 3,230 (116 ) 3,114 Total Competitive Businesses Electric Revenues 11,834 1,356 13,190 (105 ) 13,085 Competitive Businesses Natural Gas Revenues 1,016 823 1,839 105 1,944 Competitive Businesses Other Revenues (c) 385 (46 ) 339 — 339 Total Generation Consolidated Operating Revenues $ 13,235 $ 2,133 $ 15,368 $ — $ 15,368 __________ (a) Includes all wholesale and retail electric sales to third parties and affiliated sales to the Utility Registrants. (b) Includes revenues from derivatives and leases. (c) Other represents activities not allocated to a region. See text above for a description of included activities. Includes unrealized mark-to-market gains of $64 million and losses of $96 million in 2019 and 2018 , respectively, and elimination of intersegment revenues. Revenues net of purchased power and fuel expense (Generation): Nine Months Ended September 30, 2019 Nine Months Ended September 30, 2018 RNF from external customers (a) Intersegment RNF Total RNF RNF from external customers (a) Intersegment RNF Total RNF Mid-Atlantic $ 2,007 $ 16 $ 2,023 $ 2,303 $ 45 $ 2,348 Midwest 2,269 (22 ) 2,247 2,381 19 2,400 New York 800 10 810 832 9 841 ERCOT 252 (27 ) 225 396 (180 ) 216 Other Power Regions 542 (64 ) 478 740 (133 ) 607 Total Revenues net of purchased power and fuel expense for Reportable Segments 5,870 (87 ) 5,783 6,652 (240 ) 6,412 Other (b) 262 87 349 164 240 404 Total Generation Revenues net of purchased power and fuel expense $ 6,132 $ — $ 6,132 $ 6,816 $ — $ 6,816 __________ (a) Includes purchases and sales from/to third parties and affiliated sales to the Utility Registrants. (b) Other represents activities not allocated to a region. See text above for a description of included activities. Includes unrealized mark-to-market losses of $84 million and $104 million in 2019 and 2018 , respectively, accelerated nuclear fuel amortization associated with announced early plant retirements as discussed in Note 8 — Early Plant Retirements of $13 million and $53 million decrease to RNF in 2019 and 2018 , respectively, and the elimination of intersegment RNF. Electric and Gas Revenue by Customer Class (Utility Registrants): Nine Months Ended September 30, 2019 Revenues from contracts with customers ComEd PECO BGE PHI Pepco DPL ACE Rate-regulated electric revenues Residential $ 2,221 $ 1,231 $ 1,019 $ 1,816 $ 792 $ 499 $ 525 Small commercial & industrial 1,103 304 193 387 114 141 132 Large commercial & industrial 399 163 335 843 633 75 135 Public authorities & electric railroads 35 23 20 47 27 10 10 Other (a) 660 186 242 481 166 151 164 Total rate-regulated electric revenues (b) 4,418 1,907 1,809 3,574 1,732 876 966 Rate-regulated natural gas revenues Residential — 285 327 64 — 64 — Small commercial & industrial — 122 55 30 — 30 — Large commercial & industrial — 1 93 4 — 4 — Transportation — 18 — 11 — 11 — Other (c) — 5 19 6 — 6 — Total rate-regulated natural gas revenues (d) — 431 494 115 — 115 — Total rate-regulated revenues from contracts with customers 4,418 2,338 2,303 3,689 1,732 991 966 Other revenues Revenues from alternative revenue programs (98 ) (16 ) 11 4 10 (6 ) — Other rate-regulated electric revenues (e) 22 10 10 7 6 1 — Other rate-regulated natural gas revenues (e) — 1 3 — — 1 — Total other revenues (76 ) (5 ) 24 11 16 (4 ) — Total rate-regulated revenues for reportable segments $ 4,342 $ 2,333 $ 2,327 $ 3,700 $ 1,748 $ 987 $ 966 Nine Months Ended September 30, 2018 Revenues from contracts with customers ComEd PECO BGE PHI Pepco DPL ACE Rate-regulated electric revenues Residential $ 2,277 $ 1,199 $ 1,054 $ 1,839 $ 792 $ 513 $ 534 Small commercial & industrial 1,132 306 196 370 104 138 128 Large commercial & industrial 411 174 325 845 632 74 139 Public authorities & electric railroads 36 21 21 44 24 10 10 Other (a) 656 181 246 446 145 129 174 Total rate-regulated electric revenues (b) 4,512 1,881 1,842 3,544 1,697 864 985 Rate-regulated natural gas revenues Residential — 259 345 68 — 68 — Small commercial & industrial — 102 55 31 — 31 — Large commercial & industrial — 1 88 7 — 7 — Transportation — 16 — 12 — 12 — Other (c) — 4 49 11 — 11 — Total rate-regulated natural gas revenues (d) — 382 537 129 — 129 — Total rate-regulated revenues from contracts with customers 4,512 2,263 2,379 3,673 1,697 993 985 Other revenues Revenues from alternative revenue programs (27 ) 2 (23 ) 7 6 5 (4 ) Other rate-regulated electric revenues (e) 23 10 10 8 5 3 — Other rate-regulated natural gas revenues (e) — — 3 — — — — Total other revenues (4 ) 12 (10 ) 15 11 8 (4 ) Total rate-regulated revenues for reportable segments $ 4,508 $ 2,275 $ 2,369 $ 3,688 $ 1,708 $ 1,001 $ 981 __________ (a) Includes revenues from transmission revenue from PJM, wholesale electric revenue and mutual assistance revenue. (b) Includes operating revenues from affiliates of $13 million , $4 million , $5 million, $11 million , $5 million , $5 million and $2 million at ComEd, PECO, BGE, PHI, Pepco, DPL and ACE, respectively, in 2019 and $23 million , $5 million , $5 million , $11 million $5 million , $6 million and $2 million at ComEd, PECO, BGE, PHI, Pepco, DPL and ACE, respectively, in 2018 . (c) Includes revenues from off-system natural gas sales. (d) Includes operating revenues from affiliates of less than $1 million and $13 million at PECO and BGE in 2019 and 2018 , respectively. (e) Includes late payment charge revenues. |
Significant Accounting Polici_2
Significant Accounting Policies (Policies) | 9 Months Ended |
Sep. 30, 2019 | |
Accounting Policies [Abstract] | |
Basis of Accounting, Policy [Policy Text Block] | Basis of Presentation (All Registrants) Each of the Registrant’s Consolidated Financial Statements includes the accounts of its subsidiaries. All intercompany transactions have been eliminated. 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” within the consolidated financial statements and include intercompany eliminations unless otherwise disclosed. The accompanying consolidated financial statements as of September 30, 2019 and 2018 and for the three and nine months then ended 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, 2018 Consolidated Balance Sheets were derived from audited financial statements. 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, 2019 . 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. |
New Accounting Pronouncements, Policy [Policy Text Block] | New Accounting Standards (All Registrants) New Accounting Standards Adopted in 2019: In 2019, the Registrants have adopted the following new authoritative accounting guidance issued by the FASB. Leases. The Registrants applied the new guidance with the following transition practical expedients: • a "package of three" expedients that must be taken together and allow entities to (1) not reassess whether existing contracts contain leases, (2) carry forward the existing lease classification, and (3) not reassess initial direct costs associated with existing leases, • an implementation expedient which allows the requirements of the standard in the period of adoption with no restatement of prior periods, and • a land easement expedient which allows entities to not evaluate land easements under the new standard at adoption if they were not previously accounted for as leases. The standard materially impacted the Registrants' Consolidated Balance Sheets but did not have a material impact in the Registrants' Consolidated Statements of Operations and Comprehensive Income, Consolidated Statements of Cash Flows and Consolidated Statements of Changes in Shareholders' Equity. The most significant impact was the recognition of the ROU assets and lease liabilities for operating leases. The operating ROU assets and lease liabilities recognized upon adoption are materially consistent with the balances presented in the Combined Notes to the Consolidated Financial Statements. See Note 5 - Leases for additional information. See Note 1 — Significant Accounting Policies of the Exelon 2018 Form 10-K for additional information on new accounting standards issued and adopted as of January 1, 2019. New Accounting Standards Issued and Not Yet Adopted as of September 30, 2019 : The following new authoritative accounting guidance issued by the FASB has not yet been adopted and reflected by the Registrants in their consolidated financial statements as of September 30, 2019 . Unless otherwise indicated, the Registrants are currently assessing the impacts such guidance may have (which could be material) in their financial statements. The Registrants have assessed other FASB issuances of new standards which are not listed below as the Registrants do not expect such standards to have a material impact to their financial statements. Goodwill Impairment (Issued January 2017). Simplifies the accounting for goodwill impairment by removing Step 2 of the current test, which requires calculation of a hypothetical purchase price allocation. Under the revised guidance, goodwill impairment will be measured as the amount by which a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying amount of goodwill (currently Step 1 of the two-step impairment test). Entities will continue to have the option to perform a qualitative assessment to determine if a quantitative impairment test is necessary. Exelon, Generation, ComEd, PHI and DPL do not expect the updated guidance to have a material impact to their financial statements. The standard is effective January 1, 2020, with early adoption permitted, and must be applied on a prospective basis. Impairment of Financial Instruments (Issued June 2016). Provides for a new Current Expected Credit Loss (CECL) impairment model for specified financial instruments including loans, trade receivables, debt securities classified as held-to-maturity investments and net investments in leases recognized by a lessor. Under the new guidance, on initial recognition and at each reporting period, an entity is required to recognize an allowance that reflects its current estimate of credit losses expected to be incurred over the life of the financial instrument based on historical experience, current conditions and reasonable and supportable forecasts. The standard will be effective January 1, 2020 (with early adoption as of January 1, 2019 permitted) and requires a modified retrospective transition approach through a cumulative-effect adjustment to retained earnings as of the beginning of the period of adoption. This standard is primarily applicable to Generation's and the Utility Registrants' trade accounts receivable balances. The Registrants do not expect that this guidance will have a significant impact on their consolidated financial statements. |
Revenues [Policy Text Block] | 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. Generation’s primary sources of revenue include competitive sales of power, natural gas, and other energy-related products and services. The Utility Registrants’ primary sources of revenue include regulated electric and gas tariff sales, distribution and transmission services. |
Lessee, Leases [Policy Text Block] | Leases (All Registrants) The Registrants recognize a ROU asset and lease liability for operating leases with a term of greater than one year. The ROU asset is included in Other deferred debits and other assets and the lease liability is included in Other current liabilities and Other deferred credits and other liabilities on the Consolidated Balance Sheets. The ROU asset is measured as the sum of (1) the present value of all remaining fixed and in-substance fixed payments using each Registrant’s incremental borrowing rate, (2) any lease payments made at or before the commencement date (less any lease incentives received) and (3) any initial direct costs incurred. The lease liability is measured the same as the ROU asset, but excludes any payments made before the commencement date and initial direct costs incurred. Lease terms include options to extend or terminate the lease if it is reasonably certain they will be exercised. The Registrants include non-lease components, which are service-related costs that are not integral to the use of the asset, in the measurement of the ROU asset and lease liability. Expense for operating leases and leases with a term of one year or less is recognized on a straight-line basis over the term of the lease, unless another systematic and rational basis is more representative of the derivation of benefit from use of the leased property. Variable lease payments are recognized in the period in which the related obligation is incurred and consist primarily of payments for purchases of electricity under contracted generation and are based on the electricity produced by those generating assets. Operating lease expense and variable lease payments are recorded to Purchased power and fuel expense for contracted generation or Operating and maintenance expense for all other lease agreements on the Registrants’ Statements of Operations and Comprehensive Income. Income from operating leases, including subleases, is recognized on a straight-line basis over the term of the lease, unless another systematic and rational basis is more representative of the pattern in which income is earned over the term of the lease. Variable lease payments are recognized in the period in which the related obligation is performed and consist primarily of payments received from sales of electricity under contracted generation and are based on the electricity produced by those generating assets. Operating lease income and variable lease payments are recorded to Operating revenues on the Registrants’ Statements of Operations and Comprehensive Income. The Registrants’ operating leases consist primarily of contracted generation, real estate including office buildings, and vehicles and equipment. The Registrants generally account for contracted generation in which the generating asset is not renewable as a lease if the customer has dispatch rights and obtains substantially all of the economic benefits. For new agreements entered after January 1, 2019, the Registrants will generally not account for contracted generation in which the generating asset is renewable as a lease if the customer does not design the generating asset. The Registrants account for land right arrangements that provide for exclusive use as leases while shared use land arrangements are generally not leases. The Registrants do not account for secondary use pole attachments as leases. See Note 5 — Leases for additional information. |
Fair Value of Financial Instruments, Policy [Policy Text Block] | Valuation Techniques Used to Determine Net Asset Value Certain NDT Fund Investments are not classified within the fair value hierarchy and are included under the heading “Not subject to leveling” in the table above. These investments are measured at fair value using NAV per share as a practical expedient and include commingled funds, mutual funds which are not publicly quoted, managed middle market funds, private equity and real estate funds. For commingled funds and mutual funds, which are not publicly quoted, the fair value is primarily derived from the quoted prices in active markets on the underlying securities and can typically be redeemed monthly with 30 or less days of notice and without further restrictions. For managed middle market funds, the fair value is determined using a combination of valuation models including cost models, market models, and income models and typically cannot be redeemed until maturity of the term loan. Private equity and real estate investments include those in limited partnerships that invest in operating companies and real estate holding companies that are not publicly traded on a stock exchange, such as, leveraged buyouts, growth capital, venture capital, distressed investments, investments in natural resources, and direct investments in pools of real estate properties. These investments typically cannot be redeemed and are generally liquidated over a period of 8 to 10 years from the initial investment date, which is based on Exelon’s understanding of the investment funds. Private equity and real estate valuations are reported by the fund manager and are based on the valuation of the underlying investments, which include inputs such as cost, operating results, discounted future cash flows, market based comparable data, and independent appraisals from sources with professional qualifications. These valuation inputs are unobservable. |
Variable Interest Entities (Tab
Variable Interest Entities (Tables) | 9 Months Ended |
Sep. 30, 2019 | |
Variable Interest Entity [Abstract] | |
VIE - Assets and Liabilities of VIEs which Creditors or Beneficiaries have no Recourse [Table Text Block] | The table below shows the carrying amounts and classification of the consolidated VIEs’ assets and liabilities included in the consolidated financial statements of Exelon, Generation, PHI and ACE as of September 30, 2019 and December 31, 2018 . The assets, except as noted in the footnotes to the table below, can only be used to settle obligations of the VIEs. The liabilities, except as noted in the footnote to the table below, are such that creditors, or beneficiaries, do not have recourse to the general credit of Exelon, Generation, PHI and ACE. September 30, 2019 December 31, 2018 Exelon Generation PHI (a) ACE Exelon Generation PHI (a) ACE Cash and cash equivalents $ 168 $ 168 $ — $ — $ 414 $ 414 $ — $ — Restricted cash and cash equivalents 76 73 3 3 66 62 4 4 Accounts receivable, net Customer 163 163 — — 146 146 — — Other 43 43 — — 23 23 — — Unamortized energy contract asset (b) 23 23 — — 25 25 — — Inventory, net Materials and supplies 222 222 — — 212 212 — — Other current assets 50 48 2 — 52 49 3 — Total current assets 745 740 5 3 938 931 7 4 Property, plant and equipment, net (c) 6,079 6,079 — — 6,188 6,188 — — NDT funds 2,636 2,636 — — 2,351 2,351 — — Unamortized energy contract asset (b) 258 258 — — 274 274 — — Other noncurrent assets 69 52 17 15 258 232 26 19 Total noncurrent assets 9,042 9,025 17 15 9,071 9,045 26 19 Total assets $ 9,787 $ 9,765 $ 22 $ 18 $ 10,009 $ 9,976 $ 33 $ 23 Long-term debt due within one year $ 556 $ 535 $ 21 $ 19 $ 87 $ 66 $ 21 $ 18 Accounts payable 148 148 — — 96 96 — — Accrued expenses 58 57 1 1 73 72 1 1 Unamortized energy contract liabilities 10 10 — — 15 15 — — Other current liabilities 30 30 — — 3 3 — — Total current liabilities 802 780 22 20 274 252 22 19 Long-term debt 532 504 28 26 1,072 1,025 47 40 Asset retirement obligations (d) 2,103 2,103 — — 2,165 2,165 — — Unamortized energy contract liabilities 1 1 — — 1 1 — — Other noncurrent liabilities 84 84 — — 42 42 — — Total noncurrent liabilities 2,720 2,692 28 26 3,280 3,233 47 40 Total liabilities $ 3,522 $ 3,472 $ 50 $ 46 $ 3,554 $ 3,485 $ 69 $ 59 _________ (a) Includes certain purchase accounting adjustments not pushed down to the ACE standalone entity. (b) These are unrestricted assets to Exelon and Generation. (c) Exelon’s and Generation’s balances include unrestricted assets of $41 million and $43 million as of September 30, 2019 and December 31, 2018 , respectively. (d) Exelon’s and Generation’s balances include liabilities with recourse of $5 million as of September 30, 2019 and December 31, 2018 . |
VIE - Summary of Unconsolidated VIEs [Table Text Block] | The following table presents summary information about Exelon's and Generation’s unconsolidated VIE entities: September 30, 2019 December 31, 2018 Commercial Agreement VIEs Equity Investment VIEs Total Commercial Agreement VIEs Equity Investment VIEs Total Total assets (a) $ 614 $ 453 $ 1,067 $ 597 $ 472 $ 1,069 Total liabilities (a) 36 224 260 37 222 259 Exelon's ownership interest in VIE (a) — 201 201 — 223 223 Other ownership interests in VIE (a) 587 28 615 560 27 587 Registrants’ maximum exposure to loss: Carrying amount of equity method investments — 12 12 — 223 223 _________ (a) These items represent amounts in the unconsolidated VIE balance sheets, not in Exelon’s or Generation’s Consolidated Balance Sheets. These items are included to provide information regarding the relative size of the unconsolidated VIEs. |
Revenue from Contracts with C_2
Revenue from Contracts with Customers (Tables) | 9 Months Ended |
Sep. 30, 2019 | |
Revenue from Contract with Customer [Abstract] | |
Contract with Customer, Asset and Liability [Table Text Block] | The following table provides a rollforward of the contract assets and liabilities reflected in Exelon's and Generation's Consolidated Balance Sheets from January 1, 2018 to September 30, 2019 : Contract Assets Contract Liabilities Exelon Generation Exelon Generation Balance as of January 1, 2018 $ 283 $ 283 $ 35 $ 35 Consideration received or due (146 ) (146 ) 179 465 Revenues recognized 50 50 (187 ) (458 ) Balance at December 31, 2018 187 187 27 42 Consideration received or due (109 ) (109 ) 65 198 Revenues recognized 92 92 (66 ) (192 ) Balance at September 30, 2019 170 170 26 48 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Table Text Block] | 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 September 30, 2019 . 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 Generation's power and gas sales contracts as they contain variable volumes and/or variable pricing. This disclosure also 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. 2019 2020 2021 2022 2023 and thereafter Total Exelon 156 341 142 74 244 957 Generation 215 442 197 89 244 1,187 |
Leases (Tables)
Leases (Tables) | 9 Months Ended |
Sep. 30, 2019 | |
Leases [Abstract] | |
Components of Lease Cost [Table Text Block] | The components of lease costs for the three months ended September 30, 2019 were as follows: Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Operating lease costs $ 97 $ 73 $ 1 $ — $ 8 $ 12 $ 3 $ 3 $ 2 Variable lease costs 79 74 — — 1 1 — — — Short-term lease costs 5 5 — — — — — — — Total lease costs (a) $ 181 $ 152 $ 1 $ — $ 9 $ 13 $ 3 $ 3 $ 2 __________ (a) Excludes $29 million , $28 million , $1 million and $1 million of sublease income recorded at Exelon, Generation, PHI and DPL, respectively The components of lease costs for the nine months ended September 30, 2019 were as follows: Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Operating lease costs $ 252 $ 180 $ 2 $ 1 $ 25 $ 35 $ 9 $ 10 $ 5 Variable lease costs 229 214 1 — 1 5 2 2 1 Short-term lease costs 16 16 — — — — — — — Total lease costs (a) $ 497 $ 410 $ 3 $ 1 $ 26 $ 40 $ 11 $ 12 $ 6 __________ (a) Excludes $48 million , $42 million , $6 million and $6 million of sublease income recorded at Exelon, Generation, PHI and DPL, respectively. The weighted average remaining lease terms, in years, and discount rates for operating leases as of September 30, 2019 were as follows: Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Remaining lease term 10.1 10.6 4.7 4.3 5.6 9.0 9.6 9.5 5.3 Discount rate 4.5 % 4.8 % 3.1 % 3.3 % 3.6 % 4.0 % 3.7 % 3.7 % 3.3 % |
Supplemental Balance Sheet Information Related to Lessee Right-of-Use Assets and Lease Liabilities [Table Text Block] | The following table provides additional information regarding the presentation of operating lease ROU assets and lease liabilities within the Registrants’ Consolidated Balance Sheets as of September 30, 2019 : Exelon (a) Generation (a) ComEd PECO BGE PHI Pepco DPL ACE Operating lease ROU assets Other deferred debits and other assets $ 1,374 $ 926 $ 10 $ 2 $ 83 $ 304 $ 66 $ 75 $ 24 Operating lease liabilities Other current liabilities 242 170 3 — 32 35 8 11 5 Other deferred credits and other liabilities 1,355 949 8 1 50 279 60 74 19 Total operating lease liabilities $ 1,597 $ 1,119 $ 11 $ 1 $ 82 $ 314 $ 68 $ 85 $ 24 __________ (a) Exelon's and Generation's operating ROU assets and lease liabilities include $542 million and $703 million , respectively, related to contracted generation. |
Lessee, Operating Lease, Liability, Maturity [Table Text Block] | Future minimum lease payments for operating leases as of September 30, 2019 were as follows: Year Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE 2019 $ 65 $ 50 $ 1 $ — $ 1 $ 11 $ 3 $ 2 $ 2 2020 289 203 3 1 34 45 10 13 5 2021 246 162 3 — 31 43 9 12 5 2022 179 113 2 — 16 42 9 12 4 2023 148 100 1 — — 41 8 11 4 Remaining years 1,123 837 2 — 19 197 43 53 6 Total 2,050 1,465 12 1 101 379 82 103 26 Interest 453 346 1 — 19 65 14 18 2 Total operating lease liabilities $ 1,597 $ 1,119 $ 11 $ 1 $ 82 $ 314 $ 68 $ 85 $ 24 |
Schedule of Future Minimum Lease Payments for Operating Leases [Table Text Block] | Future minimum lease payments for operating leases under the prior lease accounting guidance as of December 31, 2018 were as follows: Year Exelon (a)(b) Generation (a)(b) ComEd (a)(c) PECO (a)(c) BGE (a)(c)(d)(e) PHI (a) Pepco (a) DPL (a)(c) ACE (a) 2019 $ 140 $ 33 $ 7 $ 5 $ 35 $ 48 $ 11 $ 14 $ 7 2020 149 46 5 5 35 46 10 13 6 2021 143 46 4 5 33 43 9 12 5 2022 126 47 4 5 18 42 8 12 5 2023 97 46 3 5 3 39 8 10 4 Remaining years 723 545 — — 19 159 40 35 5 Total minimum future lease payments $ 1,378 $ 763 $ 23 $ 25 $ 143 $ 377 $ 86 $ 96 $ 32 __________ (a) Includes amounts related to shared use land arrangements. (b) Excludes Generation’s contingent operating lease payments associated with contracted generation. (c) Amounts related to certain real estate leases and railroad licenses effectively have indefinite payment periods. As a result, ComEd, PECO, BGE and DPL have excluded these payments from the remaining years as such amounts would not be meaningful. ComEd's, PECO’s, BGE’s and DPL's average annual obligation for these arrangements, included in each of the years 2019 - 2023, was $3 million , $5 million , $1 million and $1 million respectively. Also includes amounts related to shared use land arrangements. (d) Includes all future lease payments on a 99-year real estate lease that expires in 2106. (e) The BGE column above includes minimum future lease payments associated with a 6-year lease for the Baltimore City conduit system that became effective during the fourth quarter of 2016. BGE's total commitments under the lease agreement are $26 million , $28 million , $28 million and $14 million related to years 2019 - 2022, respectively. |
Schedule of Supplemental Cash Flow Information Related to Leases [Table Text Block] | Cash paid for amounts included in the measurement of lease liabilities for the nine months ended September 30, 2019 were as follows: Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Operating cash flows from operating leases $ 225 $ 156 $ 2 $ — $ 32 $ 29 $ 7 $ 6 $ 4 ROU assets obtained in exchange for lease obligations for the nine months ended September 30, 2019 were as follows: Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Operating leases $ 70 $ 11 $ 6 $ — $ 1 $ 20 $ 7 $ 9 $ 4 |
Components of Operating Lease Income [Table Text Block] | The components of lease income for the three months ended September 30, 2019 were as follows: Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Operating lease income $ 30 $ 29 $ — $ — $ — $ 1 $ — $ 1 $ — Variable lease income 80 80 — — — — — — — The components of lease income for the nine months ended September 30, 2019 were as follows: Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Operating lease income $ 48 $ 44 $ — $ — $ — $ 3 $ — $ 3 $ — Variable lease income 209 206 — — — 3 — 3 — |
Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block] | Future minimum lease payments to be recovered under operating leases as of September 30, 2019 were as follows: Year Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE 2019 $ 4 $ 3 $ — $ — $ — $ 1 $ — $ 1 $ — 2020 51 46 — — — 4 — 3 — 2021 50 45 — — — 4 1 3 — 2022 50 45 — — — 5 — 4 — 2023 49 45 — — — 4 — 3 — Remaining years 314 271 1 3 1 38 — 38 — Total $ 518 $ 455 $ 1 $ 3 $ 1 $ 56 $ 1 $ 52 $ — |
Regulatory Matters (Tables)
Regulatory Matters (Tables) | 9 Months Ended |
Sep. 30, 2019 | |
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 2019. Completed Distribution Base Rate Case Proceedings Registrant/Jurisdiction Filing Date Requested Revenue Requirement (Decrease) Increase Approved Revenue Requirement (Decrease) Increase Approved ROE Approval Date Rate Effective Date ComEd - Illinois (Electric) April 16, 2018 $ (23 ) $ (24 ) 8.69% December 4, 2018 January 1, 2019 PECO - Pennsylvania (Electric) March 29, 2018 $ 82 $ 25 N/A (a) December 20, 2018 January 1, 2019 BGE - Maryland (Natural Gas) June 8, 2018 (amended October 12, 2018) $ 61 $ 43 9.8% January 4, 2019 January 4, 2019 ACE - New Jersey (Electric) August 21, 2018 (amended November 19, 2018) $ 122 (b) $ 70 (b) 9.6% March 13, 2019 April 1, 2019 Pepco - Maryland (Electric) January 15, 2019 (amended May 16, 2019) $ 27 $ 10 9.6% August 12, 2019 August 13, 2019 __________ (a) The PECO rate case proceeding was resolved through a settlement agreement, which did not specify an approved ROE. (b) Requested and approved increases are before New Jersey sales and use tax. Pending Distribution Base Rate Case Proceedings Registrant/Jurisdiction Filing Date Requested Revenue Requirement (Decrease) Increase Requested ROE Expected Approval Timing ComEd - Illinois (Electric) (a) April 8, 2019 $ (6 ) 8.91 % December 2019 BGE - Maryland (Electric) (b) May 24, 2019 (amended October 4, 2019) $ 74 10.3 % December 2019 BGE - Maryland (Natural Gas) (b) May 24, 2019 (amended October 4, 2019) $ 59 10.3 % December 2019 Pepco - District of Columbia (Electric) (c) May 30, 2019 (amended September 16, 2019) $ 160 10.3 % Fourth quarter of 2020 __________ (a) Reflects an increase of $57 million for the initial revenue requirement for 2019 and a decrease of $63 million related to the annual reconciliation for 2018. The revenue requirement for 2019 and annual reconciliation for 2018 provides for a weighted average debt and equity return on distribution rate base of 6.53% . See Note 4 — Regulatory Matters of the Exelon 2018 Form 10-K for additional information on ComEd's distribution formula rate filings. (b) On October 25, 2019, BGE filed a settlement agreement with the MDPSC. The settlement provides for an increase to BGE’s annual electric and natural gas distribution rates of $18 million and $45 million , respectively. (c) Reflects a three-year cumulative multi-year plan and total requested revenue requirement increases of $84 million , $40 million and $36 million for years 2020, 2021, and 2022, respectively, to recover capital investments made in 2018 and 2019 and planned capital investments from 2020 to 2022. |
Public Utilities Transmission Rate Filings [Table Text Block] | For 2019, the following total increases/(decreases) were included in ComEd’s, BGE’s, Pepco's, DPL's and ACE's electric transmission formula rate filings: Registrant (a) Initial Revenue Requirement Increase (Decrease) Annual Reconciliation (Decrease) Increase Total Revenue Requirement Increase (Decrease) Allowed Return on Rate Base (c) Allowed ROE (d) ComEd $ 21 $ (16 ) $ 5 8.21 % 11.50 % BGE (10 ) (23 ) (19 ) (b) 7.35 % 10.50 % Pepco 15 11 26 7.75 % 10.50 % DPL 17 (1 ) 16 7.14 % 10.50 % ACE 11 (2 ) 9 7.79 % 10.50 % __________ (a) All rates are effective June 2019 , subject to review by the FERC and other parties, which is due by the fourth quarter of 2019 . (b) The change in BGE's transmission revenue requirement includes a FERC approved dedicated facilities charge of $14 million 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 settlement 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, Pepco, DPL and ACE, 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. |
Public Utilities Energy Efficiency Revenue [Table Text Block] | ComEd filed its annual energy efficiency formula rate update with the ICC on May 23, 2019. The filing establishes the revenue requirement used to set the rates that will take effect in January 2020 after the ICC’s review and approval. The revenue requirement requested is based on a reconciliation of the 2018 actual costs plus projected 2019 and 2020 expenditures. Registrant Initial Revenue Requirement Increase (Decrease) Annual Reconciliation Increase (Decrease) Total Revenue Requirement Increase (Decrease) Requested Return on Rate Base Requested ROE ComEd $ 53 $ (2 ) $ 51 (a) 6.53 % 8.91 % __________ (a) The requested revenue requirement increase provides for a weighted average debt and equity return on rate base of 6.53% inclusive of an allowed ROE of 8.91% . The ROE reflects the average rate on 30-year treasury notes plus 580 basis points. The ROE applicable to the 2018 reconciliation year is 10.91% and the return on rate base is 7.49% , which include the Performance Adjustment, which can either increase or decrease the ROE by up to a maximum of 200 basis points. |
Public Utilities General Disclosures [Table Text Block] | 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 Exelon's and the Utility Registrant's 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 our customers. Exelon ComEd (a) PECO BGE (b) PHI Pepco (c) DPL (c) ACE September 30, 2019 $ 59 $ 4 $ — $ 47 $ 8 $ 5 $ 3 $ — December 31, 2018 $ 65 $ 8 $ — $ 49 $ 8 $ 5 $ 3 $ — _________ (a) Reflects ComEd's unrecognized equity returns earned for ratemaking purposes on its electric distribution formula rate regulatory assets. (b) BGE's authorized amounts capitalized for ratemaking purposes primarily relate to earnings on shareholders' investment on its AMI programs. (c) Pepco's and DPL's authorized amounts capitalized for ratemaking purposes relate to earnings on shareholders' investment on their respective AMI Programs and Energy Efficiency and Demand Response Programs. The earnings on energy efficiency are on Pepco DC and DPL DE programs only. |
Early Plant Retirements (Tables
Early Plant Retirements (Tables) | 9 Months Ended |
Sep. 30, 2019 | |
Property, Plant and Equipment [Abstract] | |
Income statement expense (pre-tax) | As a result of these early nuclear plant retirement decisions, Exelon and Generation recognized incremental non-cash charges to earnings stemming from shortening the expected economic useful lives primarily related to accelerated depreciation of plant assets (including any ARC) and accelerated amortization of nuclear fuel, as well as operating and maintenance expenses. See Note 13 — Nuclear Decommissioning for additional information on changes to the nuclear decommissioning ARO balance. The total impact for the three and nine months ended September 30, 2019 and 2018 are summarized in the table below. Three Months Ended September 30, Nine Months Ended September 30, Income statement expense (pre-tax) 2019 2018 2019 2018 Depreciation and amortization (a) Accelerated depreciation $ 71 $ 152 $ 216 $ 441 Accelerated nuclear fuel amortization 3 18 13 52 Operating and maintenance (b) 39 4 (44 ) 32 Total $ 113 $ 174 $ 185 $ 525 _________ (a) Reflects incremental accelerated depreciation and amortization for TMI for the three and nine months ended September 30, 2019 . Reflects incremental accelerated depreciation for TMI and Oyster Creek for the three and nine months ended September 30, 2018 . The Oyster Creek amounts are from February 2, 2018 through September 17, 2018. The TMI amounts are through September 20, 2019. (b) In 2019, primarily reflects the net impacts associated with the remeasurements of the TMI ARO in the first and third quarters. See Note 13 — Nuclear Decommissioning for additional information on the first quarter 2019 TMI ARO update. In 2018, primarily reflects materials and supplies inventory reserve adjustments, employee related costs and CWIP impairments associated with the early retirement decisions for TMI and Oyster Creek. Excludes the charges in the third quarter of 2018 and second quarter of 2019 to Operating and maintenance expense for the ARO remeasurement due to the sale of Oyster Creek. See Note 3 — Mergers, Acquisitions and Dispositions for additional information. |
Implications of Potential Early Plant Retirement on Balance Sheet [Table Text Block] | The following table provides the balance sheet amounts as of September 30, 2019 for Exelon's and Generation’s significant assets and liabilities associated with the Mystic Units 8 and 9 and Everett Marine Terminal assets that would potentially be impacted by the failure to adopt long-term solutions for reliability and fuel security. September 30, 2019 Asset Balances Materials and supplies inventory $ 31 Fuel inventory 5 Completed plant, net 889 Construction work in progress 7 Liability Balances Asset retirement obligation (2 ) |
Fair Value of Financial Asset_2
Fair Value of Financial Assets and Liabilities (Tables) | 9 Months Ended |
Sep. 30, 2019 | |
Fair Value Disclosures [Abstract] | |
Fair Value of Financial Liabilities Recorded at Amortized Cost | 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, SNF obligation and trust preferred securities (long-term debt to financing trusts or junior subordinated debentures) as of September 30, 2019 and December 31, 2018 . The Registrants have no financial liabilities classified as Level 1. The carrying amounts of the Registrants’ short-term liabilities as presented on their Consolidated Balance Sheets are representative of their fair value (Level 2) because of the short-term nature of these instruments. September 30, 2019 December 31, 2018 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 $ 36,304 $ 38,056 $ 2,541 $ 40,597 $ 35,424 $ 33,711 $ 2,158 $ 35,869 Generation 8,613 7,962 1,398 9,360 8,793 7,467 1,443 8,910 ComEd 8,196 9,622 — 9,622 8,101 8,390 — 8,390 PECO 3,404 3,891 50 3,941 3,084 3,157 50 3,207 BGE 3,270 3,678 — 3,678 2,876 2,950 — 2,950 PHI 6,494 5,993 1,093 7,086 6,259 5,436 665 6,101 Pepco 2,860 3,249 395 3,644 2,719 2,901 196 3,097 DPL 1,495 1,437 232 1,669 1,494 1,303 193 1,496 ACE 1,324 1,034 466 1,500 1,188 987 275 1,262 Long-Term Debt to Financing Trusts (a) Exelon $ 390 $ — $ 426 $ 426 $ 390 $ — $ 400 $ 400 ComEd 205 — 223 223 205 — 209 209 PECO 184 — 203 203 184 — 191 191 SNF Obligation Exelon $ 1,193 $ 1,017 $ — $ 1,017 $ 1,171 $ 949 $ — $ 949 Generation 1,193 1,017 — 1,017 1,171 949 — 949 ____ (a) Includes unamortized debt issuance costs which are not fair valued. |
Assets and liabilities measured and recorded at fair value on recurring basis | 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 September 30, 2019 and December 31, 2018 : Exelon and Generation Exelon Generation As of September 30, 2019 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Assets Cash equivalents (a) $ 1,719 $ — $ — $ — $ 1,719 $ 896 $ — $ — $ — $ 896 NDT fund investments Cash equivalents (b) 315 78 — — 393 315 78 — — 393 Equities 3,121 1,727 — 1,314 6,162 3,121 1,727 — 1,314 6,162 Fixed income Corporate debt — 1,473 259 — 1,732 — 1,473 259 — 1,732 U.S. Treasury and agencies 1,777 152 — — 1,929 1,777 152 — — 1,929 Foreign governments — 56 — — 56 — 56 — — 56 State and municipal debt — 85 — — 85 — 85 — — 85 Other (c) — 23 — 979 1,002 — 23 — 979 1,002 Exelon Generation As of September 30, 2019 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Fixed income subtotal 1,777 1,789 259 979 4,804 1,777 1,789 259 979 4,804 Middle market lending — — 255 445 700 — — 255 445 700 Private equity — — — 398 398 — — — 398 398 Real estate — — — 581 581 — — — 581 581 NDT fund investments subtotal (d) 5,213 3,594 514 3,717 13,038 5,213 3,594 514 3,717 13,038 Rabbi trust investments Cash equivalents 49 — — — 49 4 — — — 4 Mutual funds 77 — — — 77 24 — — — 24 Fixed income — 13 — — 13 — — — — — Life insurance contracts — 76 40 — 116 — 24 — — 24 Rabbi trust investments subtotal 126 89 40 — 255 28 24 — — 52 Commodity derivative assets Economic hedges 533 1,488 1,817 — 3,838 533 1,488 1,817 — 3,838 Proprietary trading — 54 156 — 210 — 54 156 — 210 Effect of netting and allocation of collateral (e)(f) (677 ) (1,261 ) (1,025 ) — (2,963 ) (677 ) (1,261 ) (1,025 ) — (2,963 ) Commodity derivative assets subtotal (144 ) 281 948 — 1,085 (144 ) 281 948 — 1,085 Total assets 6,914 3,964 1,502 3,717 16,097 5,993 3,899 1,462 3,717 15,071 Liabilities Commodity derivative liabilities Economic hedges (773 ) (1,695 ) (1,686 ) — (4,154 ) (773 ) (1,695 ) (1,406 ) — (3,874 ) Proprietary trading — (59 ) (89 ) — (148 ) — (59 ) (89 ) — (148 ) Effect of netting and allocation of collateral (e)(f) 770 1,585 1,329 — 3,684 770 1,585 1,329 — 3,684 Commodity derivative liabilities subtotal (3 ) (169 ) (446 ) — (618 ) (3 ) (169 ) (166 ) — (338 ) Deferred compensation obligation — (140 ) — — (140 ) — (37 ) — — (37 ) Total liabilities (3 ) (309 ) (446 ) — (758 ) (3 ) (206 ) (166 ) — (375 ) Total net assets $ 6,911 $ 3,655 $ 1,056 $ 3,717 $ 15,339 $ 5,990 $ 3,693 $ 1,296 $ 3,717 $ 14,696 Exelon Generation As of December 31, 2018 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Assets Cash equivalents (a) $ 1,243 $ — $ — $ — $ 1,243 $ 581 $ — $ — $ — $ 581 NDT fund investments Cash equivalents (b) 252 86 — — 338 252 86 — — 338 Equities 2,918 1,591 — 1,381 5,890 2,918 1,591 — 1,381 5,890 Fixed income Corporate debt — 1,593 230 — 1,823 — 1,593 230 — 1,823 U.S. Treasury and agencies 2,081 99 — — 2,180 2,081 99 — — 2,180 Foreign governments — 50 — — 50 — 50 — — 50 State and municipal debt — 149 — — 149 — 149 — — 149 Other (c) — 30 — 846 876 — 30 — 846 876 Fixed income subtotal 2,081 1,921 230 846 5,078 2,081 1,921 230 846 5,078 Middle market lending — — 313 367 680 — — 313 367 680 Private equity — — — 329 329 — — — 329 329 Real estate — — — 510 510 — — — 510 510 NDT fund investments subtotal (d) 5,251 3,598 543 3,433 12,825 5,251 3,598 543 3,433 12,825 Rabbi trust investments Cash equivalents 48 — — — 48 5 — — — 5 Mutual funds 72 — — — 72 24 — — — 24 Fixed income — 15 — — 15 — — — — — Life insurance contracts — 70 38 — 108 — 22 — — 22 Rabbi trust investments subtotal 120 85 38 — 243 29 22 — — 51 Commodity derivative assets Economic hedges 541 2,760 1,470 — 4,771 541 2,760 1,470 — 4,771 Proprietary trading — 69 77 — 146 — 69 77 — 146 Effect of netting and allocation of collateral (e)(f) (582 ) (2,357 ) (732 ) — (3,671 ) (582 ) (2,357 ) (732 ) — (3,671 ) Commodity derivative assets subtotal (41 ) 472 815 — 1,246 (41 ) 472 815 — 1,246 Total assets 6,573 4,155 1,396 3,433 15,557 5,820 4,092 1,358 3,433 14,703 Exelon Generation As of December 31, 2018 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Liabilities Commodity derivative liabilities Economic hedges (642 ) (2,963 ) (1,276 ) — (4,881 ) (642 ) (2,963 ) (1,027 ) — (4,632 ) Proprietary trading — (73 ) (21 ) — (94 ) — (73 ) (21 ) — (94 ) Effect of netting and allocation of collateral (e)(f) 639 2,581 808 — 4,028 639 2,581 808 — 4,028 Commodity derivative liabilities subtotal (3 ) (455 ) (489 ) — (947 ) (3 ) (455 ) (240 ) — (698 ) Deferred compensation obligation — (137 ) — — (137 ) — (35 ) — — (35 ) Total liabilities (3 ) (592 ) (489 ) — (1,084 ) (3 ) (490 ) (240 ) — (733 ) Total net assets $ 6,570 $ 3,563 $ 907 $ 3,433 $ 14,473 $ 5,817 $ 3,602 $ 1,118 $ 3,433 $ 13,970 _________ (a) Exelon excludes cash of $347 million and $458 million at September 30, 2019 and December 31, 2018 , respectively, and restricted cash of $112 million and $80 million at September 30, 2019 and December 31, 2018 , respectively, and includes long-term restricted cash of $186 million and $185 million at September 30, 2019 and December 31, 2018 , respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets. Generation excludes cash of $183 million and $283 million at September 30, 2019 and December 31, 2018 , respectively, and restricted cash of $66 million and $39 million at September 30, 2019 and December 31, 2018 , respectively. (b) Includes $85 million and $50 million of cash received from outstanding repurchase agreements at September 30, 2019 and December 31, 2018 , respectively, and is offset by an obligation to repay upon settlement of the agreement as discussed in (d) below. (c) Includes a derivative liability of $2 million and a derivative asset of $44 million , which have total notional amounts of $864 million and $1,432 million at September 30, 2019 and December 31, 2018 , respectively. The notional principal amounts for these instruments provide one measure of the transaction volume outstanding as of the fiscal years ended and do not represent the amount of Exelon and Generation's exposure to credit or market loss. (d) Excludes net liabilities of $176 million and $130 million at September 30, 2019 and December 31, 2018 , respectively. These items consist of receivables related to pending securities sales, interest and dividend receivables, repurchase agreement obligations, and payables related to pending securities purchases. The repurchase agreements are generally short-term in nature with durations generally of 30 days or less. (e) Collateral posted/(received) from counterparties totaled $93 million , $324 million and $304 million allocated to Level 1, Level 2 and Level 3 mark-to-market derivatives, respectively, as of September 30, 2019 . Collateral posted/(received) from counterparties, net of collateral paid to counterparties, totaled $57 million , $224 million and $76 million allocated to Level 1, Level 2 and Level 3 mark-to-market derivatives, respectively, as of December 31, 2018 . (f) Of the collateral posted/(received), $306 million and $(94) million represents variation margin on the exchanges as of September 30, 2019 and December 31, 2018 , respectively. As of September 30, 2019 , Exelon and Generation have outstanding commitments to invest in fixed income, middle market lending, private equity and real estate investments of approximately $93 million , $241 million , $383 million , and $388 million , respectively. These commitments will be funded by Generation’s existing NDT funds. Exelon and Generation hold investments without readily determinable fair values with carrying amounts of $75 million as of September 30, 2019 . Changes were immaterial in fair value, cumulative adjustments and impairments for the three and nine months ended September 30, 2019 . Valuation Techniques Used to Determine Net Asset Value Certain NDT Fund Investments are not classified within the fair value hierarchy and are included under the heading “Not subject to leveling” in the table above. These investments are measured at fair value using NAV per share as a practical expedient and include commingled funds, mutual funds which are not publicly quoted, managed middle market funds, private equity and real estate funds. For commingled funds and mutual funds, which are not publicly quoted, the fair value is primarily derived from the quoted prices in active markets on the underlying securities and can typically be redeemed monthly with 30 or less days of notice and without further restrictions. For managed middle market funds, the fair value is determined using a combination of valuation models including cost models, market models, and income models and typically cannot be redeemed until maturity of the term loan. Private equity and real estate investments include those in limited partnerships that invest in operating companies and real estate holding companies that are not publicly traded on a stock exchange, such as, leveraged buyouts, growth capital, venture capital, distressed investments, investments in natural resources, and direct investments in pools of real estate properties. These investments typically cannot be redeemed and are generally liquidated over a period of 8 to 10 years from the initial investment date, which is based on Exelon’s understanding of the investment funds. Private equity and real estate valuations are reported by the fund manager and are based on the valuation of the underlying investments, which include inputs such as cost, operating results, discounted future cash flows, market based comparable data, and independent appraisals from sources with professional qualifications. These valuation inputs are unobservable. ComEd, PECO and BGE ComEd PECO BGE As of September 30, 2019 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) $ 264 $ — $ — $ 264 $ 207 $ — $ — $ 207 $ 122 $ — $ — $ 122 Rabbi trust investments Mutual funds — — — — 8 — — 8 7 — — 7 Life insurance contracts — — — — — 11 — 11 — — — — Rabbi trust investments subtotal — — — — 8 11 — 19 7 — — 7 Total assets 264 — — 264 215 11 — 226 129 — — 129 Liabilities Deferred compensation obligation — (7 ) — (7 ) — (8 ) — (8 ) — (5 ) — (5 ) Mark-to-market derivative liabilities (b) — — (280 ) (280 ) — — — — — — — — Total liabilities — (7 ) (280 ) (287 ) — (8 ) — (8 ) — (5 ) — (5 ) Total net assets (liabilities) $ 264 $ (7 ) $ (280 ) $ (23 ) $ 215 $ 3 $ — $ 218 $ 129 $ (5 ) $ — $ 124 ComEd PECO BGE As of December 31, 2018 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) $ 209 $ — $ — $ 209 $ 111 $ — $ — $ 111 $ 4 $ — $ — $ 4 Rabbi trust investments Mutual funds — — — — 7 — — 7 6 — — 6 Life insurance contracts — — — — — 10 — 10 — — — — Rabbi trust investments subtotal — — — — 7 10 — 17 6 — — 6 Total assets 209 — — 209 118 10 — 128 10 — — 10 Liabilities Deferred compensation obligation — (6 ) — (6 ) — (10 ) — (10 ) — (5 ) — (5 ) Mark-to-market derivative liabilities (b) — — (249 ) (249 ) — — — — — — — — Total liabilities — (6 ) (249 ) (255 ) — (10 ) — (10 ) — (5 ) — (5 ) Total net assets (liabilities) $ 209 $ (6 ) $ (249 ) $ (46 ) $ 118 $ — $ — $ 118 $ 10 $ (5 ) $ — $ 5 _________ (a) ComEd excludes cash of $76 million and $93 million at September 30, 2019 and December 31, 2018 , respectively, and restricted cash of $31 million and $28 million at September 30, 2019 and December 31, 2018 , respectively, and includes long-term restricted cash of $171 million and $166 million at September 30, 2019 and December 31, 2018 , respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets. PECO excludes cash of $23 million and $24 million at September 30, 2019 and December 31, 2018 , respectively. BGE excludes cash of $8 million and $7 million at September 30, 2019 and December 31, 2018 , respectively, and restricted cash of $1 million and $2 million at September 30, 2019 and December 31, 2018 , respectively. (b) The Level 3 balance consists of the current and noncurrent liability of $27 million and $253 million , respectively, at September 30, 2019 , and $26 million and $223 million , respectively, at December 31, 2018 , related to floating-to-fixed energy swap contracts with unaffiliated suppliers. PHI, Pepco, DPL and ACE As of September 30, 2019 As of December 31, 2018 PHI Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Cash equivalents (a) $ 107 $ — $ — $ 107 $ 147 $ — $ — $ 147 Rabbi trust investments Cash equivalents 43 — — 43 42 — — 42 Mutual funds 13 — — 13 13 — — 13 Fixed income — 13 — 13 — 15 — 15 Life insurance contracts — 24 40 64 — 22 38 60 Rabbi trust investments subtotal 56 37 40 133 55 37 38 130 Total assets 163 37 40 240 202 37 38 277 Liabilities Deferred compensation obligation — (19 ) — (19 ) — (21 ) — (21 ) Total liabilities — (19 ) — (19 ) — (21 ) — (21 ) Total net assets $ 163 $ 18 $ 40 $ 221 $ 202 $ 16 $ 38 $ 256 Pepco DPL ACE As of September 30, 2019 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) $ 34 $ — $ — $ 34 $ — $ — $ — $ — $ 18 $ — $ — $ 18 Rabbi trust investments Cash equivalents 43 — — 43 — — — — — — — — Fixed income — 3 — 3 — — — — — — — — Life insurance contracts — 24 40 64 — — — — — — — — Rabbi trust investments subtotal 43 27 40 110 — — — — — — — — Total assets 77 27 40 144 — — — — 18 — — 18 Liabilities Deferred compensation obligation — (2 ) — (2 ) — — — — — — — — Total liabilities — (2 ) — (2 ) — — — — — — — — Total net assets $ 77 $ 25 $ 40 $ 142 $ — $ — $ — $ — $ 18 $ — $ — $ 18 Pepco DPL ACE As of December 31, 2018 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) $ 38 $ — $ — $ 38 $ 16 $ — $ — $ 16 $ 23 $ — $ — $ 23 Rabbi trust investments Cash equivalents 41 — — 41 — — — — — — — — Fixed income — 5 — 5 — — — — — — — — Life insurance contracts — 22 37 59 — — — — — — — — Rabbi trust investments subtotal 41 27 37 105 — — — — — — — — Total assets 79 27 37 143 16 — — 16 23 — — 23 Liabilities Deferred compensation obligation — (3 ) — (3 ) — (1 ) — (1 ) — — — — Total liabilities — (3 ) — (3 ) — (1 ) — (1 ) — — — — Total net assets (liabilities) $ 79 $ 24 $ 37 $ 140 $ 16 $ (1 ) $ — $ 15 $ 23 $ — $ — $ 23 _________ (a) PHI excludes cash of $45 million and $39 million at September 30, 2019 and December 31, 2018 , respectively, and includes long-term restricted cash of $15 million and $19 million at September 30, 2019 and December 31, 2018 , respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets. Pepco excludes cash of $18 million and $15 million at September 30, 2019 and December 31, 2018 , respectively. DPL excludes cash of $11 million and $8 million at September 30, 2019 and December 31, 2018 , respectively. ACE excludes cash of $13 million and $7 million at September 30, 2019 and December 31, 2018 , respectively, and includes long-term restricted cash of $15 million and $19 million at September 30, 2019 and December 31, 2018 , respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets. |
Fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis | 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 and nine months ended September 30, 2019 and 2018 : Exelon Generation ComEd PHI and Pepco Three Months Ended September 30, 2019 Total NDT Fund Investments Mark-to-Market Derivatives Total Generation Mark-to-Market Derivatives Life Insurance Contracts Eliminated in Consolidation Balance as of June 30, 2019 $ 1,179 $ 539 $ 873 $ 1,412 $ (273 ) $ 40 $ — Total realized / unrealized gains (losses) Included in net income (171 ) 2 (173 ) (a) (171 ) — — — Included in noncurrent payables to affiliates — 11 — 11 — — (11 ) Included in regulatory assets/liabilities 4 — — — (7 ) (b) — 11 Change in collateral 41 — 41 41 — — — Purchases, sales, issuances and settlements Purchases 53 1 52 53 — — — Sales (22 ) (21 ) (1 ) (22 ) — — — Settlements (18 ) (18 ) — (18 ) — — — Transfers into Level 3 1 — 1 (c) 1 — — — Transfers out of Level 3 (11 ) — (11 ) (c) (11 ) — — — Balance at September 30, 2019 $ 1,056 $ 514 $ 782 $ 1,296 $ (280 ) $ 40 $ — The amount of total (losses) gains included in income attributed to the change in unrealized gains (losses) related to assets and liabilities as of September 30, 2019 $ (18 ) $ 2 $ (20 ) $ (18 ) $ — $ — $ — Exelon Generation ComEd PHI and Pepco Nine Months Ended September 30, 2019 Total NDT Fund Investments Mark-to-Market Derivatives Total Generation Mark-to-Market Derivatives Life Insurance Contracts Eliminated in Consolidation Balance as of December 31, 2018 $ 907 $ 543 $ 575 $ 1,118 $ (249 ) $ 38 $ — Total realized / unrealized gains (losses) Included in net income (125 ) 5 (132 ) (a) (127 ) — 2 — Included in noncurrent payables to affiliates — 32 — 32 — — (32 ) Included in regulatory assets 1 — — — (31 ) (b) — 32 Change in collateral 227 — 227 227 — — — Purchases, sales, issuances and settlements Purchases 163 43 120 163 — — — Sales (23 ) (21 ) (2 ) (23 ) — — — Settlements (88 ) (88 ) — (88 ) — — — Transfers into Level 3 5 — 5 (c) 5 — — — Transfers out of Level 3 (11 ) — (11 ) (c) (11 ) — — — Balance as of September 30, 2019 $ 1,056 $ 514 $ 782 $ 1,296 $ (280 ) $ 40 $ — The amount of total gains (losses) included in income attributed to the change in unrealized gains (losses) related to assets and liabilities as of September 30, 2019 $ 173 $ 5 $ 166 $ 171 $ — $ 2 $ — __________ (a) Includes a reduction for the reclassification of $153 million and $298 million of realized gains due to the settlement of derivative contracts for the three and nine months ended September 30, 2019 , respectively. (b) Includes $7 million of decreases in fair value and an increase for realized losses due to settlements of $4 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the three months ended September 30, 2019 . Includes $31 million of decreases in fair value and an increase for realized losses due to settlements of $17 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the nine months ended September 30, 2019 . (c) Transfers into and out of Level 3 generally occur when the contract tenor becomes less and more observable respectively, primarily due to changes in market liquidity or assumptions for certain commodity contracts. Exelon Generation ComEd PHI and Pepco Three Months Ended September 30, 2018 Total NDT Fund Investments Mark-to-Market Derivatives Total Generation Mark-to-Market Derivatives Life Insurance Contracts Eliminated in Consolidation Balance as of June 30, 2018 $ 1,106 $ 585 $ 737 $ 1,322 $ (252 ) $ 36 $ — Total realized / unrealized gains (losses) Included in net income (259 ) (1 ) (259 ) (a) (260 ) — 1 — Included in noncurrent payables to affiliates — (4 ) — (4 ) — — 4 Included in regulatory assets (11 ) — — — (7 ) (b) — (4 ) Change in collateral (44 ) — (44 ) (44 ) — — — Purchases, sales, issuances and settlements Purchases 96 15 81 96 — — — Settlements (29 ) (29 ) — (29 ) — — — Transfers into Level 3 3 — 3 (c) 3 — — — Transfers out of Level 3 (6 ) — (6 ) (c) (6 ) — — — Balance as of September 30, 2018 $ 856 $ 566 $ 512 $ 1,078 $ (259 ) $ 37 $ — The amount of total gains (losses) included in income attributed to the change in unrealized gains (losses) related to assets and liabilities as of September 30, 2018 $ (105 ) $ (1 ) $ (104 ) $ (105 ) $ — $ — $ — Exelon Generation ComEd PHI and Pepco Nine Months Ended September 30, 2018 Total NDT Fund Investments Mark-to-Market Derivatives Total Generation Mark-to-Market Derivatives Life Insurance Contracts Eliminated in Consolidation Balance as of December 31, 2017 $ 966 $ 648 $ 552 $ 1,200 $ (256 ) $ 22 $ — Total realized / unrealized gains (losses) Included in net income (186 ) (1 ) (188 ) (a) (189 ) — 3 — Included in regulatory assets (3 ) — — — (3 ) (b) — — Change in collateral 14 — 14 14 — — — Purchases, sales, issuances and settlements Purchases 215 34 181 215 — — — Sales (3 ) — (3 ) (3 ) — — — Settlements (103 ) (115 ) — (115 ) — 12 — Transfers into Level 3 (21 ) — (21 ) (c) (21 ) — — — Transfers out of Level 3 (23 ) — (23 ) (c) (23 ) — — — Balance as of September 30, 2018 $ 856 $ 566 $ 512 $ 1,078 $ (259 ) $ 37 $ — The amount of total gains (losses) included in income attributed to the change in unrealized gains (losses) related to assets and liabilities as of September 30, 2018 $ 154 $ (5 ) $ 159 $ 154 $ — $ — $ — __________ (a) Includes a reduction for the reclassification of $155 million and $347 million of realized losses due to the settlement of derivative contracts for the three and nine months ended September 30, 2018 , respectively. (b) Includes $4 million of increases in fair value and an increase for realized losses due to settlements of $3 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the three months ended September 30, 2018 . Includes $9 million of decreases in fair value and an increase for realized losses due to settlements of $12 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the nine months ended September 30, 2018 . (c) Transfers into and out of Level 3 generally occur when the contract tenor becomes less and more observable respectively, primarily due to changes in market liquidity or assumptions for certain commodity contracts. |
Total realized and unrealized gains (losses) included in income for Level 3 assets and liabilities measured at fair value on a recurring basis | The following tables present the income statement classification of the total realized and unrealized gains (losses) included in income for Level 3 assets and liabilities measured at fair value on a recurring basis during the three and nine months ended September 30, 2019 and 2018 : Exelon Generation PHI and Pepco Operating Purchased Operating and Maintenance Other, net Operating Purchased Other, net Operating and Maintenance Total realized (losses) gains for the three months ended September 30, 2019 $ (25 ) $ (148 ) $ — $ 2 $ (25 ) $ (148 ) $ 2 $ — Total realized gains (losses) for the nine months ended September 30, 2019 122 (254 ) — 5 122 (254 ) 5 — Total unrealized gains (losses) for the three months ended September 30, 2019 99 (119 ) — 2 99 (119 ) 2 — Total unrealized gains (losses) for the nine months ended September 30, 2019 368 (202 ) 2 5 368 (202 ) 5 2 Exelon Generation PHI and Pepco Operating Purchased Operating and Maintenance Other, net Operating Revenues Purchased Power and Fuel Other, net Operating and Maintenance Total realized (losses) gains for the three months ended September 30, 2018 $ (176 ) $ (83 ) $ 1 $ (1 ) $ (176 ) $ (83 ) $ (1 ) $ 1 Total realized (losses) gains for the nine months ended September 30, 2018 (32 ) (156 ) 3 (1 ) (32 ) (156 ) (1 ) 3 Total unrealized (losses) for the three months ended September 30, 2018 (64 ) (40 ) — (1 ) (64 ) (40 ) (1 ) — Total unrealized gains (losses) for the nine months ended September 30, 2018 174 (15 ) — (5 ) 174 (15 ) (5 ) — |
Fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis, valuation technique | The table below discloses the significant inputs to the forward curve used to value these positions. Type of trade Fair Value at September 30, 2019 Fair Value at December 31, 2018 Valuation Technique Unobservable Input 2019 Range 2018 Range Mark-to-market derivatives — Economic Hedges (Exelon and Generation) (a)(b) $ 411 $ 443 Discounted Forward power $11 - $167 $12 - $174 Forward gas $1.36 - $10.82 $0.78 - $12.38 Option Volatility 9% - 200% 10% - 277% Mark-to-market derivatives — Proprietary trading (Exelon and Generation) (a)(b) $ 67 $ 56 Discounted Forward power $17 - $167 $14 - $174 Mark-to-market derivatives (Exelon and ComEd) $ (280 ) $ (249 ) Discounted Forward heat (c) 9x - 10x 10x - 11x Marketability 4% - 7% 4% - 8% Renewable 87% - 119% 86% - 120% _________ (a) The valuation techniques, unobservable inputs and ranges are the same for the asset and liability positions. (b) The fair values do not include cash collateral posted on level three positions of $304 million and $76 million as of September 30, 2019 and December 31, 2018 , respectively. (c) Quoted forward natural gas rates are utilized to project the forward power curve for the delivery of energy at specified future dates. The natural gas curve is extrapolated beyond its observable period to the end of the contract’s delivery. |
Derivative Financial Instrume_2
Derivative Financial Instruments (Tables) | 9 Months Ended |
Sep. 30, 2019 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Summary of the derivative fair value | The following table provides a summary of the derivative fair value balances recorded by Exelon, Generation and ComEd as of September 30, 2019 and December 31, 2018 : September 30, 2019 Exelon Generation ComEd Derivatives Total Economic Hedges Proprietary Trading Collateral (a)(b) Netting (a) Subtotal Economic Hedges Mark-to-market derivative assets (current assets) $ 602 $ 2,452 $ 143 $ 212 $ (2,205 ) $ 602 $ — Mark-to-market derivative assets (noncurrent assets) 483 1,386 67 104 (1,074 ) 483 — Total mark-to-market derivative assets 1,085 3,838 210 316 (3,279 ) 1,085 — Mark-to-market derivative liabilities (current liabilities) (224 ) (2,550 ) (101 ) 249 2,205 (197 ) (27 ) Mark-to-market derivative liabilities (noncurrent liabilities) (394 ) (1,324 ) (47 ) 156 1,074 (141 ) (253 ) Total mark-to-market derivative liabilities (618 ) (3,874 ) (148 ) 405 3,279 (338 ) (280 ) Total mark-to-market derivative net assets (liabilities) $ 467 $ (36 ) $ 62 $ 721 $ — $ 747 $ (280 ) December 31, 2018 Exelon Generation ComEd Description Total Economic Proprietary Collateral Netting (a) Subtotal Economic Mark-to-market derivative assets $ 801 $ 3,505 $ 105 $ 121 $ (2,930 ) $ 801 $ — Mark-to-market derivative assets 445 1,266 41 51 (913 ) 445 — Total mark-to-market derivative assets 1,246 4,771 146 172 (3,843 ) 1,246 — Mark-to-market derivative liabilities (473 ) (3,429 ) (74 ) 125 2,931 (447 ) (26 ) Mark-to-market derivative liabilities (474 ) (1,203 ) (20 ) 60 912 (251 ) (223 ) Total mark-to-market derivative liabilities (947 ) (4,632 ) (94 ) 185 3,843 (698 ) (249 ) Total mark-to-market derivative net assets (liabilities) $ 299 $ 139 $ 52 $ 357 $ — $ 548 $ (249 ) _________ (a) Exelon and Generation net all available amounts allowed under the derivative authoritative guidance in the balance sheet. These amounts include unrealized derivative transactions with the same counterparty under legally enforceable master netting agreements and cash collateral. In some cases Exelon and Generation may have other offsetting exposures, subject to a master netting or similar agreement, such as trade receivables and payables, transactions that do not qualify as derivatives, letters of credit and other forms of non-cash collateral. These amounts are immaterial and not reflected in the table above. (b) Of the collateral posted/(received), $306 million and $(94) million represents variation margin on the exchanges at September 30, 2019 and December 31, 2018 respectively. |
Economic Hedges (Commodity Price Risk) | For the three and nine months ended September 30, 2019 and 2018 , Exelon and Generation recognized the following net pre-tax commodity mark-to-market gains (losses) which are also located in the Net fair value changes related to derivatives line in the Consolidated Statements of Cash Flows. Three Months Ended Nine Months Ended 2019 2018 2019 2018 Income Statement Location Gain (Loss) Gain (Loss) Operating revenues $ 76 $ 8 $ 65 $ (99 ) Purchased power and fuel (45 ) 66 (127 ) (4 ) Total Exelon and Generation $ 31 $ 74 $ (62 ) $ (103 ) |
Credit-Risk Related Contingent | The following tables provide information on Generation’s credit exposure for all derivative instruments, NPNS and applicable payables and receivables, net of collateral and instruments that are subject to master netting agreements, as of September 30, 2019 . The tables further delineate that exposure by credit rating of the counterparties and provide guidance on the concentration of credit risk to individual counterparties. The figures in the tables below exclude credit risk exposure from individual retail counterparties, nuclear fuel procurement contracts and exposure through RTOs, ISOs, NYMEX, ICE, NASDAQ, NGX and Nodal commodity exchanges. Additionally, the figures in the tables below exclude exposures with affiliates, including net receivables with ComEd, PECO, BGE, Pepco, DPL and ACE of $68 million , $30 million , $32 million , $39 million , $15 million and $8 million as of September 30, 2019 , respectively. Rating as of September 30, 2019 Total Exposure Before Credit Collateral Credit Collateral (a) Net Exposure Number of Counterparties Greater than 10% of Net Exposure Net Exposure of Counterparties Greater than 10% of Net Exposure Investment grade $ 693 $ 10 $ 683 — $ — Non-investment grade 74 38 36 No external ratings Internally rated — investment grade 297 1 296 Internally rated — non-investment grade 175 24 151 Total $ 1,239 $ 73 $ 1,166 — $ — Net Credit Exposure by Type of Counterparty As of Financial institutions $ 1 Investor-owned utilities, marketers, power producers 875 Energy cooperatives and municipalities 255 Other 35 Total $ 1,166 _________ (a) As of September 30, 2019 , credit collateral held from counterparties where Generation had credit exposure included $18 million of cash and $55 million of letters of credit. The credit collateral does not include non-liquid collateral. |
Fair Value of Derivatives with Credit- Risk Related Contingent Features [Table Text Block] [Table Text Block] | The aggregate fair value of all derivative instruments with credit-risk related contingent features in a liability position that are not fully collateralized (excluding transactions on the exchanges that are fully collateralized) is detailed in the table below: Credit-Risk Related Contingent Features September 30, 2019 December 31, 2018 Gross fair value of derivative contracts containing this feature (a) $ (1,249 ) $ (1,723 ) Offsetting fair value of in-the-money contracts under master netting arrangements (b) 947 1,105 Net fair value of derivative contracts containing this feature (c) $ (302 ) $ (618 ) _________ (a) Amount represents the gross fair value of out-of-the-money derivative contracts containing credit-risk related contingent features ignoring the effects of master netting agreements. (b) Amount represents the offsetting fair value of in-the-money derivative contracts under legally enforceable master netting agreements with the same counterparty, which reduces the amount of any liability for which a Registrant could potentially be required to post collateral. (c) Amount represents the net fair value of out-of-the-money derivative contracts containing credit-risk related contingent features after considering the mitigating effects of offsetting positions under master netting arrangements and reflects the actual net liability upon which any potential contingent collateral obligations would be based. |
Cash Collateral and Letters of Credit on Derivative Contracts [Table Text Block] | As of September 30, 2019 and December 31, 2018 , Exelon and Generation posted or held the following amounts of cash collateral and letters of credit on derivative contracts with external counterparties, after giving consideration to offsetting derivative and non-derivative positions under master netting agreements. September 30, 2019 December 31, 2018 Cash collateral posted $ 787 $ 418 Letters of credit posted 273 367 Cash collateral held 96 47 Letters of credit held 58 44 Additional collateral required in the event of a credit downgrade below investment grade 1,481 2,104 |
Debt and Credit Agreements (Tab
Debt and Credit Agreements (Tables) | 9 Months Ended |
Sep. 30, 2019 | |
Debt Disclosure [Abstract] | |
Commercial Paper Borrowings | The following table reflects the Registrants' commercial paper programs as of September 30, 2019 and December 31, 2018 . Generation and PECO had no commercial paper borrowings as of both September 30, 2019 and December 31, 2018 . Outstanding Commercial Average Interest Rate on Commercial Paper Issuer September 30, 2019 December 31, 2018 September 30, 2019 December 31, 2018 Exelon $ 519 $ 89 2.50 % 2.15 % ComEd 387 — 2.51 % 2.14 % BGE — 35 2.49 % 2.18 % PHI 132 54 2.52 % 2.15 % PEPCO 12 40 2.61 % 2.24 % DPL 57 — 2.42 % 2.07 % ACE 63 14 2.57 % 2.21 % |
Schedule of Long-term Debt Instruments [Table Text Block] | During the nine months ended September 30, 2019 , the following long-term debt was issued: Company Type Interest Rate Maturity Amount Use of Proceeds Generation Energy Efficiency Project Financing 3.95 % August 31, 2020 $ 4 Funding to install energy conservation measures for the Fort Meade project. Generation Energy Efficiency Project Financing 3.46 % May 1, 2020 $ 39 Funding to install energy conservation measures for the Marine Corps. Logistics Project. ComEd First Mortgage Bonds, Series 126 4.00 % March 1, 2049 $ 400 Repay a portion of ComEd’s outstanding commercial paper obligations and fund other general corporate purposes. PECO First and Refunding Mortgage Bonds 3.00 % September 15, 2049 $ 325 Repay short-term borrowings and for general corporate purposes BGE Senior Notes 3.20 % September 15, 2049 $ 400 Repay commercial paper obligations and for general corporate purposes Pepco First Mortgage Bonds 3.45 % June 13, 2029 $ 150 Repay existing indebtedness and for general corporate purposes Pepco Unsecured Tax-Exempt Bonds 1.70 % September 1, 2022 $ 110 Refinance existing indebtedness ACE First Mortgage Bonds 3.50 % May 21, 2029 $ 100 Repay existing indebtedness and for general corporate purposes ACE First Mortgage Bonds 4.14 % May 21, 2049 $ 50 Repay existing indebtedness and for general corporate purposes |
Income Taxes (Tables)
Income Taxes (Tables) | 9 Months Ended |
Sep. 30, 2019 | |
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 September 30, 2019 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE U.S. Federal statutory rate 21.0% 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 6.4 5.2 8.1 (0.3) 6.3 4.8 1.9 6.6 6.9 Qualified NDT fund income 3.2 7.1 — — — — — — — Amortization of investment tax credit, including deferred taxes on basis difference (4.1) (8.9) (0.2) — (0.1) (0.2) (0.1) (0.2) (0.3) Plant basis differences (1.7) — (1.0) (7.5) (1.1) (1.8) (2.6) (0.6) (1.9) Production tax credits and other credits (1.2) (2.7) — — — — — — — Noncontrolling interests (2.2) (4.8) — — — — — — — Excess deferred tax amortization (6.5) — (9.9) (3.6) (8.0) (17.7) (16.3) (13.5) (23.3) Other 0.7 0.5 0.4 (0.5) (0.2) 0.8 1.0 (0.1) 0.7 Effective income tax rate 15.6% 17.4% 18.4% 9.1% 17.9% 6.9% 4.9% 13.2% 3.1% Three Months Ended September 30, 2018 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE U.S. Federal statutory rate 21.0% 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 (1.2) (9.0) 8.3 (3.6) 7.3 0.2 1.0 6.6 7.3 Qualified NDT fund income 2.4 5.8 — — — — — — — Amortization of investment tax credit, including deferred taxes on basis difference (0.6) (1.1) (0.2) (0.1) — (0.2) (0.1) (0.3) (0.3) Plant basis differences (2.5) — (0.3) (15.2) (0.8) (2.0) (3.4) (0.7) (1.3) Production tax credits and other credits (1.2) (2.9) (0.1) — — — — — — Noncontrolling interests (1.1) (2.8) — — — — — — — Excess deferred tax amortization (6.8) — (7.8) (4.6) (7.9) (17.7) (21.2) (14.0) (15.4) Tax Cuts and Jobs Act of 2017 1.3 3.5 — — — 0.2 0.1 — — Other 3.2 5.6 0.3 0.9 2.6 0.6 0.3 0.6 0.3 Effective income tax rate 14.5% 20.1% 21.2% (1.6)% 22.2% 2.1% (2.3)% 13.2% 11.6% Nine Months Ended September 30, 2019 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE U.S. Federal statutory rate 21.0% 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 5.1 4.2 8.2 — 6.4 4.8 2.0 6.7 6.9 Qualified NDT fund income 5.3 11.9 — — — — — — — Amortization of investment tax credit, including deferred taxes on basis difference (1.9) (4.0) (0.2) — (0.1) (0.2) (0.1) (0.2) (0.3) Plant basis differences (1.6) — (0.7) (6.8) (1.1) (1.8) (2.3) (0.6) (2.0) Production tax credits and other credits (1.0) (2.1) — — — — — — — Noncontrolling interests (1.0) (2.3) — — — — — — — Excess deferred tax amortization (6.0) — (9.2) (2.9) (7.9) (18.6) (17.3) (15.0) (23.4) Other 0.8 (0.1) 0.2 (0.2) 0.1 0.5 0.7 0.2 — Effective income tax rate 20.7% 28.6% 19.3% 11.1% 18.4% 5.7% 4.0% 12.1% 2.2% Nine Months Ended September 30, 2018 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE U.S. Federal statutory rate 21.0% 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 1.7 (2.6) 8.2 (3.6) 6.6 2.7 2.4 6.5 7.3 Qualified NDT fund income 0.9 2.6 — — — — — — — Amortization of investment tax credit, including deferred taxes on basis difference (0.9) (2.2) (0.2) (0.1) (0.1) (0.2) (0.1) (0.3) (0.3) Plant basis differences (2.7) — (0.1) (15.4) (0.7) (1.9) (2.9) (0.7) (1.3) Production tax credits and other credits (1.8) (5.1) (0.1) — — — — — — Noncontrolling interests (1.1) (3.2) — — — — — — — Excess deferred tax amortization (6.1) — (7.6) (3.4) (8.1) (14.5) (16.5) (11.0) (14.0) Tax Cuts and Jobs Act of 2017 0.2 1.3 (0.2) — — 0.3 — — — Other 0.4 2.0 0.1 — 0.9 0.3 — 0.4 0.9 Effective income tax rate 11.6% 13.8% 21.1% (1.5)% 19.6% 7.7% 3.9% 15.9% 13.6% |
Schedule of Unrecognized Tax Benefits Roll Forward [Table Text Block] | Exelon, Generation, ComEd, PHI and ACE have the following unrecognized tax benefits as of September 30, 2019 and December 31, 2018 . PECO, BGE, Pepco and DPL do not have unrecognized tax benefits for the periods presented. Exelon Generation ComEd PHI ACE September 30, 2019 $ 448 $ 411 $ — $ 45 $ 14 December 31, 2018 $ 477 $ 408 $ 2 $ 45 $ 14 |
Summary of Positions for which Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Table Text Block] | Exelon, Generation, PHI and ACE have the following unrecognized federal and state tax benefits that could significantly decrease within the 12 months after the reporting date as a result of completing audits, potential settlements, refund claims, and the outcomes of pending court cases as of September 30, 2019 : Exelon (a) Generation (a) PHI (b) ACE (b) $ 425 $ 411 $ 14 $ 14 __________ (a) Exelon and Generation have $411 million that, if recognized, would decrease the effective tax rate. (b) The unrecognized tax benefit related to PHI and ACE, if recognized, may be included in future base rates and that portion would have no impact to the effective tax rate. |
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block] | In the third quarter of 2019, Exelon reviewed and updated its marginal state income tax rates based on 2018 state apportionment rates. As a result of the rate changes, the following accounting adjustments were recorded as of September 30, 2019: Exelon Generation Increase to deferred income tax liability $ 23 $ 9 Increase to income tax expense, net of federal taxes 23 9 |
Nuclear Decommissioning (Tables
Nuclear Decommissioning (Tables) | 9 Months Ended |
Sep. 30, 2019 | |
Schedule Of Nuclear Decommissioning [Line Items] | |
Schedule of Change in Asset Retirement Obligation [Table Text Block] | The following table provides a rollforward of the nuclear decommissioning ARO reflected in Exelon’s and Generation’s Consolidated Balance Sheets from December 31, 2018 to September 30, 2019 : Nuclear decommissioning ARO at December 31, 2018 (a)(b) $ 10,005 Sale of Oyster Creek (755 ) Accretion expense 361 Net increase due to changes in, and timing of, estimated future cash flows 211 Costs incurred related to decommissioning plants (52 ) Nuclear decommissioning ARO at September 30, 2019 (a) $ 9,770 _________ (a) Includes $127 million and $22 million as the current portion of the ARO at September 30, 2019 and December 31, 2018 , respectively, which is included in Other current liabilities in Exelon’s and Generation’s Consolidated Balance Sheets. (b) Includes $772 million of ARO related to Oyster Creek which was classified as Liabilities held for sale in Exelon's and Generation's Consolidated Balance Sheets at December 31, 2018 . See Note 3 — Mergers, Acquisitions and Dispositions for additional information. |
Retirement Benefits (Tables)
Retirement Benefits (Tables) | 9 Months Ended |
Sep. 30, 2019 | |
Retirement Benefits [Abstract] | |
Calculation of Net Periodic Benefit Costs | 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 and nine months ended September 30, 2019 and 2018 . Pension Benefits OPEB 2019 2018 2019 2018 Components of net periodic benefit cost: Service cost $ 89 $ 100 $ 23 $ 28 Interest cost 221 201 47 43 Expected return on assets (306 ) (312 ) (38 ) (43 ) Amortization of: Prior service benefit — — (45 ) (47 ) Actuarial loss 104 158 11 18 Settlement charges 7 — — — Contractual termination benefits 1 — — — Net periodic benefit cost $ 116 $ 147 $ (2 ) $ (1 ) Pension Benefits OPEB 2019 2018 2019 2018 Components of net periodic benefit cost: Service cost $ 267 $ 303 $ 70 $ 84 Interest cost 663 602 141 131 Expected return on assets (918 ) (939 ) (115 ) (130 ) Amortization of: Prior service cost (benefit) — 1 (134 ) (140 ) Actuarial loss 310 472 34 50 Settlement charges 7 1 — — Contractual termination benefits 1 — — — Net periodic benefit cost $ 330 $ 440 $ (4 ) $ (5 ) |
Allocated Portion of Pension and Postretirement Benefit Costs | The amounts below represent the Registrants' allocated pension and OPEB plan 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 Generation and 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 September 30, Nine Months Ended September 30, Pension and OPEB Costs 2019 2018 2019 2018 Exelon $ 114 $ 145 $ 326 $ 435 Generation 37 50 100 151 ComEd 23 45 70 133 PECO 4 5 9 14 BGE 16 15 47 44 PHI 23 17 71 51 Pepco 6 3 19 10 DPL 4 2 11 5 ACE 4 3 12 10 |
Defined Contribution Savings Plans | The Registrants participate in various 401(k) defined contribution savings plans that are sponsored by Exelon. The plans are 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 during the three and nine months ended September 30, 2019 and 2018 , respectively. Three Months Ended September 30, Nine Months Ended September 30, Savings Plan Matching Contributions 2019 2018 2019 2018 Exelon $ 36 $ 44 $ 101 $ 126 Generation 14 23 41 65 ComEd 9 8 26 23 PECO 2 2 7 7 BGE 4 2 9 5 PHI 4 4 8 10 Pepco 1 1 2 2 DPL 1 1 2 2 ACE 1 1 1 2 |
Changes in Accumulated Other _2
Changes in Accumulated Other Comprehensive Income (Tables) | 9 Months Ended |
Sep. 30, 2019 | |
Changes in Accumulated Other Comprehensive Income [Abstract] | |
Schedule of Accumulated Other Comprehensive Income (Loss) | The following tables present changes in Exelon's AOCI, net of tax, by component: Three Months Ended September 30, 2019 Losses on Cash Flow Hedges Pension and Non-Pension Postretirement Benefit Plan Items (a) Foreign Currency Items AOCI of Investments in Unconsolidated Affiliates (b) Total Beginning balance $ (2 ) $ (2,957 ) $ (29 ) $ (2 ) $ (2,990 ) OCI before reclassifications — 6 (2 ) — 4 Amounts reclassified from AOCI — 21 — 2 23 Net current-period OCI — 27 (2 ) 2 27 Ending balance $ (2 ) $ (2,930 ) $ (31 ) $ — $ (2,963 ) Three Months Ended September 30, 2018 Losses on Cash Flow Hedges Pension and Non-Pension Postretirement Benefit Plan Items (a) Foreign Currency Items AOCI of Investments in Unconsolidated Affiliates (b) Total Beginning balance $ (2 ) $ (2,890 ) $ (29 ) $ — $ (2,921 ) OCI before reclassifications — 5 2 — 7 Amounts reclassified from AOCI — 45 — — 45 Net current-period OCI — 50 2 — 52 Ending balance $ (2 ) $ (2,840 ) $ (27 ) $ — $ (2,869 ) Nine Months Ended September 30, 2019 Losses on Cash Flow Hedges Pension and Non-Pension Postretirement Benefit Plan Items (a) Foreign Currency Items AOCI of Investments in Unconsolidated Affiliates (b) Total Beginning balance $ (2 ) $ (2,960 ) $ (33 ) $ — $ (2,995 ) OCI before reclassifications — (32 ) 2 (2 ) (32 ) Amounts reclassified from AOCI — 62 — 2 64 Net current-period OCI — 30 2 — 32 Ending balance $ (2 ) $ (2,930 ) $ (31 ) $ — $ (2,963 ) Nine Months Ended September 30, 2018 Gains (Losses) on Cash Flow Hedges Unrealized gains (losses) on Marketable Securities Pension and Non-Pension Postretirement Benefit Plan Items (a) Foreign Currency Items AOCI of Investments in Unconsolidated Affiliates (b) Total Beginning balance $ (14 ) $ 10 $ (2,998 ) $ (23 ) $ (1 ) $ (3,026 ) OCI before reclassifications 11 — 22 (4 ) 1 30 Amounts reclassified from AOCI 1 — 136 — — 137 Net current-period OCI 12 — 158 (4 ) 1 167 Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard (c) — (10 ) — — — (10 ) Ending balance $ (2 ) $ — $ (2,840 ) $ (27 ) $ — $ (2,869 ) _________ (a) AOCI amounts are included in the computation of net periodic pension and OPEB cost. See Note 14 — Retirement Benefits for additional information. See Exelon's Statements of Operations and Comprehensive Income for individual components of AOCI. (b) All amounts are net of noncontrolling interests. (c) Exelon prospectively adopted the new standard Recognition and Measurement of Financial Assets and Liabilities. The standard was adopted as of January 1, 2018, which resulted in an increase to Retained earnings and Accumulated other comprehensive loss of $10 million for Exelon. The amounts reclassified related to Rabbi Trusts. |
Schedule Of Other Comprehensive Income Loss Tax | The following table presents income tax benefit (expense) allocated to each component of Exelon's other comprehensive income (loss): Three Months Ended September 30, Nine Months Ended September 30, 2019 2018 2019 2018 Pension and non-pension postretirement benefit plans: Prior service benefit reclassified to periodic benefit cost $ 6 $ 6 $ 18 $ 18 Actuarial loss reclassified to periodic benefit cost (13 ) (21 ) (39 ) (65 ) Pension and non-pension postretirement benefit plans valuation adjustment — (2 ) 14 (8 ) |
Commitments and Contingencies_2
Commitments and Contingencies (Tables) | 9 Months Ended |
Sep. 30, 2019 | |
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 September 30, 2019 : Description Exelon PHI Pepco DPL ACE Total commitments $ 513 $ 320 $ 120 $ 89 $ 111 Remaining commitments (a) 112 82 67 9 6 |
Commercial Commitments | The Registrants’ commercial commitments as of September 30, 2019 , representing commitments potentially triggered by future events were as follow s: Expiration within Total 2019 2020 2021 2022 2023 2024 and beyond Exelon Letters of credit $ 1,718 $ 1,192 $ 515 $ 11 $ — $ — $ — Surety bonds (a) 991 315 638 38 — — — Financing trust guarantees 378 — — — — — 378 Guaranteed lease residual values (b) 26 — 2 3 4 3 15 Total commercial commitments $ 3,113 $ 1,507 $ 1,155 $ 52 $ 4 $ 3 $ 393 Generation Letters of credit $ 1,686 $ 1,179 $ 496 $ 11 $ — $ — $ — Surety bonds (a) 790 298 492 — — — — Total commercial commitments $ 2,476 $ 1,477 $ 988 $ 11 $ — $ — $ — ComEd Letters of credit $ 7 $ 4 $ 3 $ — $ — $ — $ — Surety bonds (a) 50 5 43 2 — — — Financing trust guarantees 200 — — — — — 200 Total commercial commitments $ 257 $ 9 $ 46 $ 2 $ — $ — $ 200 PECO Surety bonds (a) $ 9 $ 1 $ 8 $ — $ — $ — $ — Financing trust guarantees 178 — — — — — 178 Total commercial commitments $ 187 $ 1 $ 8 $ — $ — $ — $ 178 BGE Letters of credit $ 8 $ 2 $ 6 $ — $ — $ — $ — Surety bonds (a) 17 2 15 — — — — Total commercial commitments $ 25 $ 4 $ 21 $ — $ — $ — $ — PHI Letters of credit $ 11 $ 1 $ 10 $ — $ — $ — $ — Surety bonds (a) 24 5 19 — — — — Guaranteed lease residual values (b) 26 — 2 3 4 3 15 Total commercial commitments $ 61 $ 6 $ 31 $ 3 $ 4 $ 3 $ 15 Pepco Letters of credit $ 10 $ — $ 10 $ — $ — $ — $ — Surety bonds (a) 17 2 15 — — — — Guaranteed lease residual values (b) 9 — — 1 1 1 6 Total commercial commitments $ 36 $ 2 $ 25 $ 1 $ 1 $ 1 $ 6 DPL Letters of credit $ 1 $ 1 $ — $ — $ — $ — $ — Surety bonds (a) 4 2 2 — — — — Guaranteed lease residual values (b) 11 — 1 1 2 1 6 Total commercial commitments $ 16 $ 3 $ 3 $ 1 $ 2 $ 1 $ 6 ACE Surety bonds (a) $ 3 $ 1 $ 2 $ — $ — $ — $ — Guaranteed lease residual values (b) 7 — 1 1 1 1 3 Total commercial commitments $ 10 $ 1 $ 3 $ 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 $68 million guaranteed by Exelon and PHI, of which $22 million , $29 million and $17 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. |
Accrued environmental liabilities | As of September 30, 2019 and December 31, 2018 , the Registrants had accrued the following undiscounted amounts for environmental liabilities in Other current liabilities and Other deferred credits and other liabilities within their respective Consolidated Balance Sheets: September 30, 2019 December 31, 2018 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 $ 507 $ 346 $ 496 $ 356 Generation 107 — 108 — ComEd 328 327 329 327 PECO 20 18 27 25 BGE 3 1 5 4 PHI 49 — 27 — Pepco 47 — 25 — DPL 1 — 1 — ACE 1 — 1 — |
Supplemental Financial Inform_2
Supplemental Financial Information (Tables) | 9 Months Ended |
Sep. 30, 2019 | |
Supplemental Financial Information [Abstract] | |
Taxes Other Than Income | The following tables provide additional information about material items recorded in the Registrants' Consolidated Statements of Operations and Comprehensive Income. Taxes other than income Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Three Months Ended September 30, 2019 Utility taxes (a) $ 241 $ 29 $ 66 $ 38 $ 21 $ 86 $ 81 $ 5 $ — Property 148 66 7 5 39 31 21 9 — Payroll 57 28 7 3 4 6 2 1 1 Three Months Ended September 30, 2018 Utility taxes (a) $ 253 $ 32 $ 67 $ 39 $ 23 $ 92 $ 87 $ 5 $ — Property 145 70 7 4 37 26 16 9 — Payroll 58 31 6 3 4 5 1 1 1 Nine Months Ended September 30, 2019 Utility taxes (a) $ 672 $ 87 $ 183 $ 102 $ 68 $ 231 $ 217 $ 14 $ — Property 444 205 22 12 114 91 64 25 2 Payroll 185 92 21 11 13 20 5 3 2 Nine Months Ended September 30, 2018 Utility taxes (a) $ 705 $ 92 $ 188 $ 102 $ 70 $ 253 $ 238 $ 15 $ — Property 416 204 22 12 106 71 45 24 2 Payroll 191 99 20 11 12 19 5 3 2 _________ (a) Generation’s utility tax represents gross receipts tax related to its retail operations, and the Utility Registrants' utility taxes represents 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. |
Schedule of Other Nonoperating Income, by Component | Other, Net Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Three Months Ended September 30, 2019 Decommissioning-related activities: Net realized income on NDT funds (a) Regulatory agreement units $ 67 $ 67 $ — $ — $ — $ — $ — $ — $ — Non-regulatory agreement units 33 33 — — — — — — — Net unrealized gains on NDT funds Regulatory agreement units 89 89 — — — — — — — Non-regulatory agreement units 55 55 — — — — — — — Regulatory offset to NDT fund-related activities (b) (125 ) (125 ) — — — — — — — Decommissioning-related activities 119 119 — — — — — — — AFUDC — Equity 22 — 4 3 6 9 7 1 1 Non-service net periodic benefit cost (2 ) — — — — — — — — Three Months Ended September 30, 2018 Decommissioning-related activities: Net realized income on NDT funds (a) Regulatory agreement units $ 214 $ 214 $ — $ — $ — $ — $ — $ — $ — Non-regulatory agreement units 58 58 — — — — — — — Net unrealized (losses) gains on NDT funds Regulatory agreement units (66 ) (66 ) — — — — — — — Non-regulatory agreement units 72 72 — — — — — — — Regulatory offset to NDT fund-related activities (b) (110 ) (110 ) — — — — — — — Decommissioning-related activities 168 168 — — — — — — — AFUDC — Equity 16 — 4 1 5 6 6 — — Non-service net periodic benefit cost (12 ) — — — — — — — — Other, Net Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Nine Months Ended September 30, 2019 Decommissioning-related activities: Net realized income on NDT funds (a) Regulatory agreement units $ 197 $ 197 $ — $ — $ — $ — $ — $ — $ — Non-regulatory agreement units 316 316 — — — — — — — Net unrealized gains on NDT funds Regulatory agreement units 565 565 — — — — — — — Non-regulatory agreement units 236 236 — — — — — — — Regulatory offset to NDT fund-related activities (b) (611 ) (611 ) — — — — — — — Decommissioning-related activities 703 703 — — — — — — — AFUDC — Equity 64 — 13 9 16 26 18 3 4 Non-service net periodic benefit cost 8 — — — — — — — — Nine Months Ended September 30, 2018 Decommissioning-related activities: Net realized income on NDT funds (a) Regulatory agreement units $ 476 $ 476 $ — $ — $ — $ — $ — $ — $ — Non-regulatory agreement units 257 257 — — — — — — — Net unrealized losses on NDT funds Regulatory agreement units (335 ) (335 ) — — — — — — — Non-regulatory agreement units (143 ) (143 ) — — — — — — — Regulatory offset to NDT fund-related activities (b) (110 ) (110 ) — — — — — — — Decommissioning-related activities 145 145 — — — — — — — AFUDC — Equity 47 — 12 3 13 19 17 2 — Non-service net periodic benefit cost (33 ) — — — — — — — — _________ (a) Realized income includes interest, dividends and realized gains and losses on sales of NDT fund investments. (b) Includes the elimination of decommissioning-related activities for the Regulatory Agreement Units, including the elimination of income taxes related to all NDT fund activity for those units. See Note 15 — Asset Retirement Obligations of the Exelon 2018 Form 10-K for additional information regarding the accounting for nuclear decommissioning. |
Cash Flow Supplemental Disclosures | The following tables provide additional information about material items recorded in the Registrants' Consolidated Statements of Cash Flows. Depreciation, amortization and accretion Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Nine Months Ended September 30, 2019 Property, plant and equipment (a) $ 2,803 $ 1,184 $ 661 $ 225 $ 263 $ 405 $ 178 $ 109 $ 89 Amortization of regulatory assets (a) 390 — 106 22 105 157 103 29 25 Amortization of intangible assets, net (a) 44 37 — — — — — — — Amortization of energy contract assets and liabilities (b) 14 14 — — — — — — — Nuclear fuel (c) 771 771 — — — — — — — ARO accretion (d) 371 371 — — — — — — — Total depreciation, amortization and accretion $ 4,393 $ 2,377 $ 767 $ 247 $ 368 $ 562 $ 281 $ 138 $ 114 Nine Months Ended September 30, 2018 Property, plant and equipment (a) $ 2,829 $ 1,347 $ 613 $ 204 $ 249 $ 355 $ 161 $ 97 $ 70 Amortization of regulatory assets (a) 412 — 83 20 109 200 125 38 37 Amortization of intangible assets, net (a) 43 36 — — — — — — — Amortization of energy contract assets and liabilities (b) 8 8 — — — — — — — Nuclear fuel (c) 852 852 — — — — — — — ARO accretion (d) 367 365 — — — — — — — Total depreciation, amortization and accretion $ 4,511 $ 2,608 $ 696 $ 224 $ 358 $ 555 $ 286 $ 135 $ 107 _________ (a) Included in Depreciation and amortization in the Registrants' Consolidated Statements of Operations and Comprehensive Income. (b) Included in Operating revenues or Purchased power and fuel expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. (c) Included in Purchased power and fuel expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. (d) Included in Operating and maintenance expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. Other non-cash operating activities Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Nine Months Ended September 30, 2019 Pension and non-pension postretirement benefit costs $ 324 $ 98 $ 70 $ 9 $ 45 $ 71 $ 19 $ 11 $ 12 Provision for uncollectible accounts 89 20 26 22 5 16 7 2 6 Other decommissioning-related activity (a) (400 ) (400 ) — — — — — — — Energy-related options (b) 21 21 — — — — — — — Amortization of rate stabilization deferral (8 ) — — — — (8 ) (9 ) 1 — Discrete impacts from EIMA and FEJA (c) 80 — 80 — — — — — — Long-term incentive plan 33 — — — — — — — — Amortization of operating ROU asset 193 138 2 — 23 26 6 7 4 Change in environmental liabilities 23 — — — — 23 23 — — Nine Months Ended September 30, 2018 Pension and non-pension postretirement benefit costs $ 435 $ 151 $ 133 $ 14 $ 43 $ 51 $ 10 $ 5 $ 10 Provision for uncollectible accounts 133 38 30 25 6 32 12 6 14 Other decommissioning-related activity (a) (39 ) (39 ) — — — — — — — Energy-related options (b) 4 4 — — — — — — — Amortization of rate stabilization deferral — — — — — — — — — Discrete impacts from EIMA and FEJA (c) 27 — 27 — — — — — — Long-term incentive plan 84 — — — — — — — — Asset retirement costs 20 — — — — 20 22 (1 ) (1 ) _______ (a) Includes the elimination of decommissioning-related activity for the Regulatory Agreement Units, including the elimination of operating revenues, ARO accretion, ARC amortization, investment income and income taxes related to all NDT fund activity for these units. See Note 15 — Asset Retirement Obligations of the Exelon 2018 Form 10-K for additional information regarding the accounting for nuclear decommissioning. (b) Includes option premiums reclassified to realized at the settlement of the underlying contracts and recorded in Operating revenues and expenses. (c) Reflects the change in ComEd's distribution and energy efficiency formula rates. See Note 6 — Regulatory Matters 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 Generation ComEd PECO BGE PHI Pepco DPL ACE September 30, 2019 Cash and cash equivalents $ 1,683 $ 1,019 $ 76 $ 224 $ 130 $ 99 $ 18 $ 11 $ 13 Restricted cash 309 126 124 6 1 38 34 — 3 Restricted cash included in other long-term assets 186 — 171 — — 15 — — 15 Total cash, cash equivalents and restricted cash $ 2,178 $ 1,145 $ 371 $ 230 $ 131 $ 152 $ 52 $ 11 $ 31 December 31, 2018 Cash and cash equivalents $ 1,349 $ 750 $ 135 $ 130 $ 7 $ 124 $ 16 $ 23 $ 7 Restricted cash 247 153 29 5 6 43 37 1 4 Restricted cash included in other long-term assets 185 — 166 — — 19 — — 19 Total cash, cash equivalents and restricted cash $ 1,781 $ 903 $ 330 $ 135 $ 13 $ 186 $ 53 $ 24 $ 30 September 30, 2018 Cash and cash equivalents $ 1,918 $ 1,187 $ 124 $ 102 $ 113 $ 153 $ 12 $ 110 $ 11 Restricted cash 240 152 12 5 3 42 35 — 7 Restricted cash included in other long-term assets 163 — 144 — — 19 — — 19 Total cash, cash equivalents and restricted cash $ 2,321 $ 1,339 $ 280 $ 107 $ 116 $ 214 $ 47 $ 110 $ 37 December 31, 2017 Cash and cash equivalents $ 898 $ 416 $ 76 $ 271 $ 17 $ 30 $ 5 $ 2 $ 2 Restricted cash 207 138 5 4 1 42 35 — 6 Restricted cash included in other long-term assets 85 — 63 — — 23 — — 23 Total cash, cash equivalents and restricted cash $ 1,190 $ 554 $ 144 $ 275 $ 18 $ 95 $ 40 $ 2 $ 31 For additional information on restricted cash see Note 1 — Significant Accounting Policies of the Exelon 2018 Form 10-K. |
Supplemental Balance Sheet Disclosures | The following tables provide additional information about material items recorded in the Registrants' Consolidated Balance Sheets. Unbilled customer revenues Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE September 30, 2019 $ 1,256 $ 676 $ 212 $ 102 $ 103 $ 163 $ 91 $ 38 $ 34 December 31, 2018 1,656 965 223 114 168 186 97 59 30 Accrued expenses Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE September 30, 2019 Compensation-related accruals (a) $ 880 $ 336 $ 133 $ 48 $ 63 $ 86 $ 26 $ 17 $ 13 Taxes accrued 431 247 56 13 64 80 61 17 3 Interest accrued 421 106 62 33 36 78 37 20 19 December 31, 2018 Compensation-related accruals (a) $ 1,191 $ 479 $ 187 $ 49 $ 68 $ 99 $ 29 $ 19 $ 12 Taxes accrued 412 226 71 28 46 74 58 4 5 Interest accrued 334 77 105 33 39 50 25 8 12 _________ (a) Primarily includes accrued payroll, bonuses and other incentives, vacation and benefits. |
Segment Information (Tables)
Segment Information (Tables) | 3 Months Ended | 9 Months Ended |
Sep. 30, 2019 | Sep. 30, 2019 | |
Segment Reporting [Abstract] | ||
Analysis and reconciliation of reportable segment information | An analysis and reconciliation of the Registrants’ reportable segment information to the respective information in the consolidated financial statements for the three and nine months ended September 30, 2019 and 2018 is as follows: Three Months Ended September 30, 2019 and 2018 Generation (a) ComEd PECO BGE PHI Other (b) Intersegment Exelon Operating revenues (c) : 2019 Competitive businesses electric revenues $ 4,314 $ — $ — $ — $ — $ — $ (275 ) $ 4,039 Competitive businesses natural gas revenues 265 — — — — — 1 266 Competitive businesses other revenues 195 — — — — — (1 ) 194 Rate-regulated electric revenues — 1,583 716 619 1,357 — (7 ) 4,268 Rate-regulated natural gas revenues — — 62 84 20 — (3 ) 163 Shared service and other revenues — — — — 3 474 (478 ) (1 ) Total operating revenues $ 4,774 $ 1,583 $ 778 $ 703 $ 1,380 $ 474 $ (763 ) $ 8,929 Generation (a) ComEd PECO BGE PHI Other (b) Intersegment Exelon 2018 Competitive businesses electric revenues $ 4,741 $ — $ — $ — $ — $ — $ (306 ) $ 4,435 Competitive businesses natural gas revenues 397 — — — — — — 397 Competitive businesses other revenues 140 — — — — — (1 ) 139 Rate-regulated electric revenues — 1,598 700 645 1,334 — (7 ) 4,270 Rate-regulated natural gas revenues — — 57 86 24 — (5 ) 162 Shared service and other revenues — — — — 3 458 (461 ) — Total operating revenues $ 5,278 $ 1,598 $ 757 $ 731 $ 1,361 $ 458 $ (780 ) $ 9,403 Intersegment revenues (d) : 2019 $ 275 $ 4 $ 1 $ 6 $ 4 $ 474 $ (764 ) $ — 2018 308 4 2 6 3 456 (779 ) — Depreciation and amortization: 2019 $ 407 $ 259 $ 83 $ 116 $ 193 $ 25 $ — $ 1,083 2018 468 237 75 110 192 23 — 1,105 Operating expenses: 2019 $ 4,274 $ 1,256 $ 595 $ 612 $ 1,124 $ 457 $ (759 ) $ 7,559 2018 4,961 1,275 603 628 1,116 459 (790 ) 8,252 Interest expense, net: 2019 $ 109 $ 91 $ 33 $ 31 $ 66 $ 79 $ — $ 409 2018 101 85 32 27 65 83 — 393 Income (loss) before income taxes: 2019 $ 501 $ 245 $ 154 $ 67 $ 203 $ (68 ) $ — $ 1,102 2018 389 245 124 81 191 (83 ) — 947 Income Taxes: 2019 $ 87 $ 45 $ 14 $ 12 $ 14 $ — $ — $ 172 2018 78 52 (2 ) 18 4 (13 ) — 137 Net income (loss): 2019 $ 244 $ 200 $ 140 $ 55 $ 189 $ (68 ) $ — $ 760 2018 300 193 126 63 187 (69 ) — 800 Capital Expenditures 2019 $ 392 $ 452 $ 228 $ 300 $ 308 $ 7 $ — $ 1,687 2018 362 514 204 233 359 18 — 1,690 __________ (a) Intersegment revenues for Generation in 2019 include revenue from sales to PECO of $43 million , sales to BGE of $65 million , sales to Pepco of $65 million , sales to DPL of $14 million and sales to ACE of $3 million in the Mid-Atlantic region, and sales to ComEd of $83 million in the Midwest region, which eliminate upon consolidation. Intersegment revenues for Generation in 2018 include revenue from sales to PECO of $35 million , sales to BGE of $69 million , sales to Pepco of $46 million , sales to DPL of $26 million and sales to ACE of $10 million in the Mid-Atlantic region, and sales to ComEd of $122 million in the Midwest region, which eliminate upon consolidation. (b) Other primarily includes Exelon’s corporate operations, shared service entities and other financing and investment activities. (c) 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 17 — Supplemental Financial Information for additional information on total utility taxes. (d) Intersegment revenues exclude sales to unconsolidated affiliates. The intersegment profit associated with Generation’s sale of certain products and services by and between Exelon’s segments is not eliminated in consolidation due to the recognition of intersegment profit in accordance with regulatory accounting guidance. For Exelon, these amounts are included in Operating revenues in the Consolidated Statements of Operations and Comprehensive Income. PHI: Pepco DPL ACE Other (b) Intersegment PHI Operating revenues (a) : 2019 Rate-regulated electric revenues $ 642 $ 299 $ 419 $ — $ (3 ) $ 1,357 Rate-regulated natural gas revenues — 20 — — — 20 Shared service and other revenues — — — 92 (89 ) 3 Total operating revenues $ 642 $ 319 $ 419 $ 92 $ (92 ) $ 1,380 2018 Rate-regulated electric revenues $ 628 $ 304 $ 406 $ — $ (4 ) $ 1,334 Rate-regulated natural gas revenues — 24 — — — 24 Shared service and other revenues — — — 103 (100 ) 3 Total operating revenues $ 628 $ 328 $ 406 $ 103 $ (104 ) $ 1,361 Intersegment revenues: 2019 $ 2 $ 1 $ 1 $ 93 $ (93 ) $ 4 2018 2 2 1 103 (105 ) 3 Depreciation and amortization: 2019 $ 95 $ 46 $ 43 $ 9 $ — $ 193 2018 99 47 38 8 — 192 Operating expenses: 2019 $ 515 $ 268 $ 340 $ 95 $ (94 ) $ 1,124 2018 516 277 322 105 (104 ) 1,116 Interest expense, net: 2019 $ 33 $ 15 $ 15 $ 3 $ — $ 66 2018 32 15 16 2 — 65 Income (loss) before income taxes: 2019 $ 103 $ 38 $ 65 $ 192 $ (195 ) $ 203 2018 87 38 69 179 (182 ) 191 Income Taxes: 2019 $ 5 $ 5 $ 2 $ 3 $ (1 ) $ 14 2018 (2 ) 5 8 (8 ) 1 4 Net income (loss): 2019 $ 98 $ 33 $ 63 $ (9 ) $ 4 $ 189 2018 89 33 61 1 3 187 Capital Expenditures 2019 $ 157 $ 85 $ 73 $ (7 ) $ — $ 308 2018 188 88 77 6 — 359 __________ (a) 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 17 — Supplemental Financial Information for additional information on total utility taxes. (b) Other primarily includes PHI’s corporate operations, shared service entities and other financing and investment activities. | Nine Months Ended September 30, 2019 and 2018 Generation (a) ComEd PECO BGE PHI Other (b) Intersegment Exelon Operating revenues (c) : 2019 Competitive businesses electric revenues $ 12,365 $ — $ — $ — $ — $ — $ (840 ) $ 11,525 Competitive businesses natural gas revenues 1,479 — — — — — — 1,479 Competitive businesses other revenues 436 — — — — — (4 ) 432 Rate-regulated electric revenues — 4,342 1,901 1,817 3,574 — (25 ) 11,609 Rate-regulated natural gas revenues — — 432 510 116 — (12 ) 1,046 Shared service and other revenues — — — — 10 1,410 (1,415 ) 5 Total operating revenues $ 14,280 $ 4,342 $ 2,333 $ 2,327 $ 3,700 $ 1,410 $ (2,296 ) $ 26,096 2018 Competitive businesses electric revenues $ 13,190 $ — $ — $ — $ — $ — $ (969 ) $ 12,221 Competitive businesses natural gas revenues 1,839 — — — — — (8 ) 1,831 Competitive businesses other revenues 339 — — — — — (4 ) 335 Rate-regulated electric revenues — 4,508 1,893 1,850 3,549 — (34 ) 11,766 Rate-regulated natural gas revenues — — 382 519 129 — (13 ) 1,017 Shared service and other revenues — — — — 10 1,398 (1,408 ) — Total operating revenues $ 15,368 $ 4,508 $ 2,275 $ 2,369 $ 3,688 $ 1,398 $ (2,436 ) $ 27,170 Shared service and other revenues Intersegment revenues (d) : 2019 $ 844 $ 13 $ 4 $ 18 $ 11 $ 1,410 $ (2,300 ) $ — 2018 981 23 5 18 11 1,392 (2,430 ) — Depreciation and amortization: 2019 $ 1,221 $ 767 $ 247 $ 368 $ 562 $ 72 $ — $ 3,237 2018 1,383 696 224 358 555 68 — 3,284 Operating expenses: 2019 $ 13,333 $ 3,431 $ 1,783 $ 1,936 $ 3,106 $ 1,405 $ (2,291 ) $ 22,703 2018 14,475 3,610 1,853 2,005 3,165 1,395 (2,467 ) 24,036 Interest expense, net: 2019 $ 336 $ 268 $ 100 $ 89 $ 197 $ 231 $ — $ 1,221 2018 305 261 96 78 193 205 — 1,138 Generation (a) ComEd PECO BGE PHI Other (b) Intersegment Exelon Income (loss) before income taxes: 2019 $ 1,355 $ 674 $ 461 $ 320 $ 436 $ (218 ) $ — $ 3,028 2018 800 663 331 301 363 (195 ) — 2,263 Income Taxes: 2019 $ 388 $ 130 $ 51 $ 59 $ 25 $ (27 ) $ — $ 626 2018 110 140 (5 ) 59 28 (70 ) — 262 Net income (loss): 2019 $ 784 $ 544 $ 410 $ 261 $ 412 $ (191 ) $ — $ 2,220 2018 667 523 336 242 336 (125 ) — 1,979 Capital Expenditures 2019 $ 1,282 $ 1,413 $ 675 $ 842 $ 1,006 $ 41 $ — $ 5,259 2018 1,660 1,540 615 667 988 27 — 5,497 Total assets: September 30, 2019 $ 47,984 $ 32,326 $ 11,379 $ 10,304 $ 22,576 $ 8,254 $ (10,085 ) $ 122,738 December 31, 2018 47,556 31,213 10,642 9,716 21,984 8,355 (9,800 ) 119,666 __________ (a) Intersegment revenues for Generation in 2019 include revenue from sales to PECO of $123 million , sales to BGE of $199 million , sales to Pepco of $188 million , sales to DPL of $50 million and sales to ACE of $16 million in the Mid-Atlantic region, and sales to ComEd of $266 million in the Midwest region, which eliminate upon consolidation. Intersegment revenues for Generation in 2018 include revenue from sales to PECO of $97 million , sales to BGE of $198 million , sales to Pepco of $143 million , sales to DPL of $103 million and sales to ACE of $21 million in the Mid-Atlantic region, and sales to ComEd of $419 million in the Midwest region, which eliminate upon consolidation. (b) Other primarily includes Exelon’s corporate operations, shared service entities and other financing and investment activities. (c) 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 17 — Supplemental Financial Information for additional information on total utility taxes. (d) Intersegment revenues exclude sales to unconsolidated affiliates. The intersegment profit associated with Generation’s sale of certain products and services by and between Exelon’s segments is not eliminated in consolidation due to the recognition of intersegment profit in accordance with regulatory accounting guidance. For Exelon, these amounts are included in Operating revenues in the Consolidated Statements of Operations and Comprehensive Income. PHI: Pepco DPL ACE Other (b) Intersegment PHI Operating revenues (a) : 2019 Rate-regulated electric revenues $ 1,748 $ 871 $ 966 $ (1 ) $ (10 ) $ 3,574 Rate-regulated natural gas revenues — 116 — — — 116 Shared service and other revenues — — — 298 (288 ) 10 Total operating revenues $ 1,748 $ 987 $ 966 $ 297 $ (298 ) $ 3,700 2018 Rate-regulated electric revenues $ 1,708 $ 872 $ 981 $ — $ (12 ) $ 3,549 Rate-regulated natural gas revenues — 129 — — — 129 Shared service and other revenues — — — 326 (316 ) 10 Total operating revenues $ 1,708 $ 1,001 $ 981 $ 326 $ (328 ) $ 3,688 Intersegment revenues: 2019 $ 5 $ 5 $ 2 $ 297 $ (298 ) $ 11 2018 5 6 2 325 (327 ) 11 Depreciation and amortization: 2019 $ 281 $ 138 $ 114 $ 29 $ — $ 562 2018 286 135 107 27 — 555 Operating expenses: 2019 $ 1,444 $ 820 $ 838 $ 302 $ (298 ) $ 3,106 2018 1,454 859 847 329 (324 ) 3,165 Interest expense, net: 2019 $ 100 $ 45 $ 44 $ 8 $ — $ 197 2018 96 42 48 7 — 193 Income (loss) before income taxes: 2019 $ 226 $ 132 $ 89 $ 411 $ (422 ) $ 436 2018 181 107 88 326 (339 ) 363 Income Taxes: 2019 $ 9 $ 16 $ 2 $ (1 ) $ (1 ) $ 25 2018 7 17 12 (8 ) — 28 Net income (loss): 2019 $ 217 $ 116 $ 87 $ (19 ) $ 11 $ 412 2018 174 90 76 (15 ) 11 336 Capital Expenditures 2019 $ 455 $ 245 $ 300 $ 6 $ — $ 1,006 2018 475 254 247 12 — 988 Total assets: September 30, 2019 $ 8,603 $ 4,724 $ 3,916 $ 11,071 $ (5,738 ) $ 22,576 December 31, 2018 8,299 4,588 3,699 10,819 (5,421 ) 21,984 __________ (a) 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 17 — Supplemental Financial Information for additional information on total utility taxes. (b) Other primarily includes PHI’s corporate operations, shared service entities and other financing and investment activities. |
Analysis and reconciliation of reportable segment revenues for Generation | The following tables disaggregate the Registrants' 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. For Generation, the disaggregation of revenues reflects Generation’s two primary products of power sales and natural gas sales, with further disaggregation of power sales provided by geographic region. For the Utility Registrants, the disaggregation of revenues reflects the two primary utility services of rate-regulated electric sales and rate-regulated natural gas sales (where applicable), with further disaggregation of these tariff sales provided by major customer groups. Exelon’s disaggregated revenues are consistent with Generation and the Utility Registrants, but exclude any intercompany revenues. Competitive Business Revenues (Generation): Three Months Ended September 30, 2019 Revenues from external customers (a) Intersegment Total Contracts with customers Other (b) Total Mid-Atlantic $ 1,351 $ 10 $ 1,361 $ 3 $ 1,364 Midwest 1,052 47 1,099 (17 ) 1,082 New York 414 15 429 — 429 ERCOT 288 72 360 5 365 Other Power Regions 873 192 1,065 (25 ) 1,040 Total Competitive Businesses Electric Revenues 3,978 336 4,314 (34 ) 4,280 Competitive Businesses Natural Gas Revenues 160 105 265 34 299 Competitive Businesses Other Revenues (c) 112 83 195 — 195 Total Generation Consolidated Operating Revenues $ 4,250 $ 524 $ 4,774 $ — $ 4,774 Three Months Ended September 30, 2018 Revenues from external customers (a) Intersegment Total Contracts with customers Other (b) Total Mid-Atlantic $ 1,397 $ 52 $ 1,449 $ 7 $ 1,456 Midwest 1,095 26 1,121 (4 ) 1,117 New York 475 (6 ) 469 — 469 ERCOT 156 289 445 (1 ) 444 Other Power Regions 959 298 1,257 (45 ) 1,212 Total Competitive Businesses Electric Revenues 4,082 659 4,741 (43 ) 4,698 Competitive Businesses Natural Gas Revenues 200 197 397 43 440 Competitive Businesses Other Revenues (c) 130 10 140 — 140 Total Generation Consolidated Operating Revenues $ 4,412 $ 866 $ 5,278 $ — $ 5,278 __________ (a) Includes all wholesale and retail electric sales to third parties and affiliated sales to the Utility Registrants. (b) Includes revenues from derivatives and leases. (c) Other represents activities not allocated to a region. See text above for a description of included activities. Includes unrealized mark-to-market gains of $77 million and $6 million in 2019 and 2018 , respectively, and elimination of intersegment revenues. Revenues net of purchased power and fuel expense (Generation): Three Months Ended September 30, 2019 Three Months Ended September 30, 2018 RNF (a) Intersegment RNF Total RNF RNF (a) Intersegment RNF Total RNF Mid-Atlantic $ 684 $ 5 $ 689 $ 746 $ 17 $ 763 Midwest 763 (16 ) 747 763 5 768 New York 288 3 291 290 2 292 ERCOT 76 (4 ) 72 161 (63 ) 98 Other Power Regions 212 (28 ) 184 226 (46 ) 180 Total Revenues net of purchased power and fuel for Reportable Segments 2,023 (40 ) 1,983 2,186 (85 ) 2,101 Other (b) 100 40 140 112 85 197 Total Generation Revenues net of purchased power and fuel expense $ 2,123 $ — $ 2,123 $ 2,298 $ — $ 2,298 __________ (a) Includes purchases and sales from/to third parties and affiliated sales to the Utility Registrants. (b) Other represents activities not allocated to a region. See text above for a description of included activities. Includes unrealized mark-to-market gains of $17 million and $71 million in 2019 and 2018 , respectively, accelerated nuclear fuel amortization associated with announced early plant retirements as discussed in Note 8 — Early Plant Retirements of $3 million and $18 million decrease to RNF in 2019 and 2018 , respectively, and the elimination of intersegment RNF. | The following tables disaggregate the Registrants' 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. For Generation, the disaggregation of revenues reflects Generation’s two primary products of power sales and natural gas sales, with further disaggregation of power sales provided by geographic region. For the Utility Registrants, the disaggregation of revenues reflects the two primary utility services of rate-regulated electric sales and rate-regulated natural gas sales (where applicable), with further disaggregation of these tariff sales provided by major customer groups. Exelon’s disaggregated revenues are consistent with Generation and the Utility Registrants, but exclude any intercompany revenues. Competitive Business Revenues (Generation): Nine Months Ended September 30, 2019 Revenues from external customers (a) Intersegment Revenues Total Revenues Contracts with customers Other (b) Total Mid-Atlantic $ 3,798 $ 9 $ 3,807 $ 2 $ 3,809 Midwest 3,083 172 3,255 (31 ) 3,224 New York 1,195 16 1,211 — 1,211 ERCOT 594 198 792 13 805 Other Power Regions 2,849 451 3,300 (46 ) 3,254 Total Competitive Businesses Electric Revenues 11,519 846 12,365 (62 ) 12,303 Competitive Businesses Natural Gas Revenues 1,041 438 1,479 62 1,541 Competitive Businesses Other Revenues (c) 343 93 436 — 436 Total Generation Consolidated Operating Revenues $ 12,903 $ 1,377 $ 14,280 $ — $ 14,280 Nine Months Ended September 30, 2018 Revenues from external customers (a) Intersegment Total Contracts with customers Other (b) Total Mid-Atlantic $ 3,971 $ 191 $ 4,162 $ 17 $ 4,179 Midwest 3,432 169 3,601 (8 ) 3,593 New York 1,305 (37 ) 1,268 1 1,269 ERCOT 470 459 929 1 930 Other Power Regions 2,656 574 3,230 (116 ) 3,114 Total Competitive Businesses Electric Revenues 11,834 1,356 13,190 (105 ) 13,085 Competitive Businesses Natural Gas Revenues 1,016 823 1,839 105 1,944 Competitive Businesses Other Revenues (c) 385 (46 ) 339 — 339 Total Generation Consolidated Operating Revenues $ 13,235 $ 2,133 $ 15,368 $ — $ 15,368 __________ (a) Includes all wholesale and retail electric sales to third parties and affiliated sales to the Utility Registrants. (b) Includes revenues from derivatives and leases. (c) Other represents activities not allocated to a region. See text above for a description of included activities. Includes unrealized mark-to-market gains of $64 million and losses of $96 million in 2019 and 2018 , respectively, and elimination of intersegment revenues. Revenues net of purchased power and fuel expense (Generation): Nine Months Ended September 30, 2019 Nine Months Ended September 30, 2018 RNF from external customers (a) Intersegment RNF Total RNF RNF from external customers (a) Intersegment RNF Total RNF Mid-Atlantic $ 2,007 $ 16 $ 2,023 $ 2,303 $ 45 $ 2,348 Midwest 2,269 (22 ) 2,247 2,381 19 2,400 New York 800 10 810 832 9 841 ERCOT 252 (27 ) 225 396 (180 ) 216 Other Power Regions 542 (64 ) 478 740 (133 ) 607 Total Revenues net of purchased power and fuel expense for Reportable Segments 5,870 (87 ) 5,783 6,652 (240 ) 6,412 Other (b) 262 87 349 164 240 404 Total Generation Revenues net of purchased power and fuel expense $ 6,132 $ — $ 6,132 $ 6,816 $ — $ 6,816 __________ (a) Includes purchases and sales from/to third parties and affiliated sales to the Utility Registrants. (b) Other represents activities not allocated to a region. See text above for a description of included activities. Includes unrealized mark-to-market losses of $84 million and $104 million in 2019 and 2018 , respectively, accelerated nuclear fuel amortization associated with announced early plant retirements as discussed in Note 8 — Early Plant Retirements of $13 million and $53 million decrease to RNF in 2019 and 2018 , respectively, and the elimination of intersegment RNF. |
Schedule of Revenue by Major Customers by Reporting Segments [Table Text Block] | Electric and Gas Revenue by Customer Class (Utility Registrants): Three Months Ended September 30, 2019 Revenues from contracts with customers ComEd PECO BGE PHI Pepco DPL ACE Rate-regulated electric revenues Residential $ 865 $ 479 $ 352 $ 741 $ 311 $ 178 $ 252 Small commercial & industrial 393 109 64 147 41 48 58 Large commercial & industrial 141 63 116 297 222 26 49 Public authorities & electric railroads 12 9 7 17 11 3 3 Other (a) 222 63 82 164 58 50 56 Total rate-regulated electric revenues (b) $ 1,633 $ 723 $ 621 $ 1,366 $ 643 $ 305 $ 418 Rate-regulated natural gas revenues Residential $ — $ 38 $ 49 $ 9 $ — $ 9 $ — Small commercial & industrial — 17 9 4 — 4 — Large commercial & industrial — — 20 1 — 1 — Transportation — 5 — 4 — 4 — Other (c) — 2 5 2 — 2 — Total rate-regulated natural gas revenues (d) $ — $ 62 $ 83 $ 20 $ — $ 20 $ — Total rate-regulated revenues from contracts with customers $ 1,633 $ 785 $ 704 $ 1,386 $ 643 $ 325 $ 418 Other revenues Revenues from alternative revenue programs $ (56 ) $ (11 ) $ (5 ) $ (9 ) $ (3 ) $ (6 ) $ 1 Other rate-regulated electric revenues (e) 6 4 3 3 2 — — Other rate-regulated natural gas revenues (e) — — 1 — — — — Total other revenues $ (50 ) $ (7 ) $ (1 ) $ (6 ) $ (1 ) $ (6 ) $ 1 Total rate-regulated revenues for reportable segments $ 1,583 $ 778 $ 703 $ 1,380 $ 642 $ 319 $ 419 Three Months Ended September 30, 2018 Revenues from contracts with customers ComEd PECO BGE PHI Pepco DPL ACE Rate-regulated electric revenues Residential $ 861 $ 458 $ 366 $ 726 $ 306 $ 180 $ 240 Small commercial & industrial 391 108 68 140 39 48 53 Large commercial & industrial 131 64 117 303 230 25 48 Public authorities & electric railroads 11 7 7 14 8 3 3 Other (a) 212 59 91 156 47 47 63 Total rate-regulated electric revenues (b) $ 1,606 $ 696 $ 649 $ 1,339 $ 630 $ 303 $ 407 Rate-regulated natural gas revenues Residential $ — $ 36 $ 46 $ 8 $ — $ 8 $ — Small commercial & industrial — 15 8 5 — 5 — Large commercial & industrial — — 17 2 — 2 — Transportation — 5 — 3 — 3 — Other (c) — 1 12 6 — 6 — Total rate-regulated natural gas revenues (d) $ — $ 57 $ 83 $ 24 $ — $ 24 $ — Total rate-regulated revenues from contracts with customers $ 1,606 $ 753 $ 732 $ 1,363 $ 630 $ 327 $ 407 Other revenues Revenues from alternative revenue programs $ (15 ) $ 1 $ (6 ) $ (5 ) $ (4 ) $ — $ (1 ) Other rate-regulated electric revenues (e) 7 3 4 3 2 1 — Other rate-regulated natural gas revenues (e) — — 1 — — — — Total other revenues $ (8 ) $ 4 $ (1 ) $ (2 ) $ (2 ) $ 1 $ (1 ) Total rate-regulated revenues for reportable segments $ 1,598 $ 757 $ 731 $ 1,361 $ 628 $ 328 $ 406 __________ (a) Includes revenues from transmission revenue from PJM, wholesale electric revenue and mutual assistance revenue. (b) Includes operating revenues from affiliates of $4 million , $1 million , $2 million , $4 million , $2 million , $1 million and $1 million at ComEd, PECO, BGE, PHI, Pepco, DPL and ACE, respectively, in 2019 and $4 million , $2 million , $1 million , $3 million $2 million , $2 million and $1 million at ComEd, PECO, BGE, PHI, Pepco, DPL and ACE, respectively, in 2018 . (c) Includes revenues from off-system natural gas sales. (d) Includes operating revenues from affiliates of less than $1 million and $4 million at PECO and BGE, respectively, in 2019 and less than $1 million and $5 million at PECO and BGE, respectively, in 2018 . (e) Includes late payment charge revenues. | Electric and Gas Revenue by Customer Class (Utility Registrants): Nine Months Ended September 30, 2019 Revenues from contracts with customers ComEd PECO BGE PHI Pepco DPL ACE Rate-regulated electric revenues Residential $ 2,221 $ 1,231 $ 1,019 $ 1,816 $ 792 $ 499 $ 525 Small commercial & industrial 1,103 304 193 387 114 141 132 Large commercial & industrial 399 163 335 843 633 75 135 Public authorities & electric railroads 35 23 20 47 27 10 10 Other (a) 660 186 242 481 166 151 164 Total rate-regulated electric revenues (b) 4,418 1,907 1,809 3,574 1,732 876 966 Rate-regulated natural gas revenues Residential — 285 327 64 — 64 — Small commercial & industrial — 122 55 30 — 30 — Large commercial & industrial — 1 93 4 — 4 — Transportation — 18 — 11 — 11 — Other (c) — 5 19 6 — 6 — Total rate-regulated natural gas revenues (d) — 431 494 115 — 115 — Total rate-regulated revenues from contracts with customers 4,418 2,338 2,303 3,689 1,732 991 966 Other revenues Revenues from alternative revenue programs (98 ) (16 ) 11 4 10 (6 ) — Other rate-regulated electric revenues (e) 22 10 10 7 6 1 — Other rate-regulated natural gas revenues (e) — 1 3 — — 1 — Total other revenues (76 ) (5 ) 24 11 16 (4 ) — Total rate-regulated revenues for reportable segments $ 4,342 $ 2,333 $ 2,327 $ 3,700 $ 1,748 $ 987 $ 966 Nine Months Ended September 30, 2018 Revenues from contracts with customers ComEd PECO BGE PHI Pepco DPL ACE Rate-regulated electric revenues Residential $ 2,277 $ 1,199 $ 1,054 $ 1,839 $ 792 $ 513 $ 534 Small commercial & industrial 1,132 306 196 370 104 138 128 Large commercial & industrial 411 174 325 845 632 74 139 Public authorities & electric railroads 36 21 21 44 24 10 10 Other (a) 656 181 246 446 145 129 174 Total rate-regulated electric revenues (b) 4,512 1,881 1,842 3,544 1,697 864 985 Rate-regulated natural gas revenues Residential — 259 345 68 — 68 — Small commercial & industrial — 102 55 31 — 31 — Large commercial & industrial — 1 88 7 — 7 — Transportation — 16 — 12 — 12 — Other (c) — 4 49 11 — 11 — Total rate-regulated natural gas revenues (d) — 382 537 129 — 129 — Total rate-regulated revenues from contracts with customers 4,512 2,263 2,379 3,673 1,697 993 985 Other revenues Revenues from alternative revenue programs (27 ) 2 (23 ) 7 6 5 (4 ) Other rate-regulated electric revenues (e) 23 10 10 8 5 3 — Other rate-regulated natural gas revenues (e) — — 3 — — — — Total other revenues (4 ) 12 (10 ) 15 11 8 (4 ) Total rate-regulated revenues for reportable segments $ 4,508 $ 2,275 $ 2,369 $ 3,688 $ 1,708 $ 1,001 $ 981 __________ (a) Includes revenues from transmission revenue from PJM, wholesale electric revenue and mutual assistance revenue. (b) Includes operating revenues from affiliates of $13 million , $4 million , $5 million, $11 million , $5 million , $5 million and $2 million at ComEd, PECO, BGE, PHI, Pepco, DPL and ACE, respectively, in 2019 and $23 million , $5 million , $5 million , $11 million $5 million , $6 million and $2 million at ComEd, PECO, BGE, PHI, Pepco, DPL and ACE, respectively, in 2018 . (c) Includes revenues from off-system natural gas sales. (d) Includes operating revenues from affiliates of less than $1 million and $13 million at PECO and BGE in 2019 and 2018 , respectively. (e) Includes late payment charge revenues. |
Variable Interest Entities - Na
Variable Interest Entities - Narrative (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Apr. 01, 2014 |
Variable Interest Entity [Line Items] | ||
Guarantor Obligations, Maximum Exposure, Undiscounted | $ 68 | |
Payment Guarantee [Member] | CENG [Member] | ||
Variable Interest Entity [Line Items] | ||
Guarantor Obligations, Maximum Exposure, Undiscounted | $ 245 | |
Financial Guarantee [Member] | CENG [Member] | ||
Variable Interest Entity [Line Items] | ||
Guarantor Obligations, Maximum Exposure, Undiscounted | 165 | |
Exelon Generation Co L L C [Member] | CENG [Member] | ||
Variable Interest Entity [Line Items] | ||
Due from Affiliates | $ 400 | |
Guarantor Obligations, Current Carrying Value | 688 | |
Atlantic City Electric Company [Member] | ||
Variable Interest Entity [Line Items] | ||
Guarantor Obligations, Maximum Exposure, Undiscounted | 17 | |
Pepco Holdings LLC [Member] | ||
Variable Interest Entity [Line Items] | ||
Guarantor Obligations, Maximum Exposure, Undiscounted | $ 68 |
Variable Interest Entities - As
Variable Interest Entities - Assets and Liabilities of VIES which Creditors or Beneficiaries have no Recourse (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Dec. 31, 2018 | Sep. 30, 2018 | Dec. 31, 2017 | |
Variable Interest Entity [Line Items] | |||||
Cash and cash equivalents | $ 1,683 | $ 1,349 | $ 1,918 | $ 898 | |
Restricted cash and cash equivalents | 309 | 247 | 240 | 207 | |
Accounts receivable, net | |||||
Customer | 4,188 | 4,607 | |||
Other | 1,085 | 1,256 | |||
Unamortized energy contract asset | 49 | 48 | |||
Inventory, net | |||||
Materials and supplies | 1,458 | 1,351 | |||
Other current assets | 1,296 | 1,238 | |||
Total current assets | 12,206 | 13,360 | |||
Property, plant and equipment, net | 78,593 | 76,707 | |||
NDT funds | 12,706 | 11,661 | |||
Unamortized energy contract asset | 353 | 372 | |||
Other Assets, Noncurrent | 3,123 | 1,575 | |||
Total assets | [1] | 122,738 | 119,666 | ||
Long-term debt due within one year | 4,248 | 1,349 | |||
Accounts payable | 3,348 | 3,800 | |||
Accrued expenses | 1,877 | 2,112 | |||
Unamortized energy contract liabilities | 138 | 149 | |||
Other Liabilities, Current | 1,425 | 1,035 | |||
Total current liabilities | 13,085 | 11,404 | |||
Long-term debt | 32,056 | 34,075 | |||
Asset retirement obligations, noncurrent | 10,089 | 9,679 | |||
Unamortized energy contract liabilities | 368 | 463 | |||
Other Liabilities, Noncurrent | 3,123 | 2,130 | |||
Total liabilities | [1] | 88,386 | 86,596 | ||
Variable Interest Entity, Primary Beneficiary [Member] | |||||
Variable Interest Entity [Line Items] | |||||
Cash and cash equivalents | 168 | 414 | |||
Restricted cash and cash equivalents | 76 | 66 | |||
Accounts receivable, net | |||||
Customer | 163 | 146 | |||
Other | 43 | 23 | |||
Unamortized energy contract asset | 23 | 25 | |||
Inventory, net | |||||
Materials and supplies | 222 | 212 | |||
Other current assets | 50 | 52 | |||
Total current assets | 745 | 938 | |||
Property, plant and equipment, net | 6,079 | 6,188 | |||
NDT funds | 2,636 | 2,351 | |||
Unamortized energy contract asset | 258 | 274 | |||
Other Assets, Noncurrent | 69 | 258 | |||
Total noncurrent assets | 9,042 | 9,071 | |||
Total assets | 9,787 | 10,009 | |||
Long-term debt due within one year | 556 | 87 | |||
Accounts payable | 148 | 96 | |||
Accrued expenses | 58 | 73 | |||
Unamortized energy contract liabilities | 10 | 15 | |||
Other Liabilities, Current | 30 | 3 | |||
Total current liabilities | 802 | 274 | |||
Long-term debt | 532 | 1,072 | |||
Asset retirement obligations, noncurrent | 2,103 | 2,165 | |||
Unamortized energy contract liabilities | 1 | 1 | |||
Other Liabilities, Noncurrent | 84 | 42 | |||
Total noncurrent liabilities | 2,720 | 3,280 | |||
Total liabilities | 3,522 | 3,554 | |||
PP&E - unrestricted asset | 41 | 43 | |||
Variable Interest Entity, Consolidated, Liabilities, Recourse | 5 | 5 | |||
Exelon Generation Co L L C [Member] | |||||
Variable Interest Entity [Line Items] | |||||
Cash and cash equivalents | 1,019 | 750 | 1,187 | 416 | |
Restricted cash and cash equivalents | 126 | 153 | 152 | 138 | |
Accounts receivable, net | |||||
Customer | 2,587 | 2,941 | |||
Other | 337 | 562 | |||
Unamortized energy contract asset | 49 | 49 | |||
Inventory, net | |||||
Materials and supplies | 1,010 | 963 | |||
Other current assets | 1,002 | 883 | |||
Total current assets | 7,159 | 8,433 | |||
Property, plant and equipment, net | 23,591 | 23,981 | |||
NDT funds | 12,706 | 11,661 | |||
Unamortized energy contract asset | 352 | 371 | |||
Other Assets, Noncurrent | 1,915 | 755 | |||
Total assets | [2] | 47,984 | 47,556 | ||
Long-term debt due within one year | 2,706 | 906 | |||
Accounts payable | 1,583 | 1,847 | |||
Accrued expenses | 762 | 898 | |||
Unamortized energy contract liabilities | 21 | 31 | |||
Other Liabilities, Current | 541 | 279 | |||
Total current liabilities | 6,344 | 5,769 | |||
Long-term debt | 5,018 | 6,989 | |||
Asset retirement obligations, noncurrent | 9,855 | 9,450 | |||
Unamortized energy contract liabilities | 11 | 20 | |||
Other Liabilities, Noncurrent | 1,466 | 610 | |||
Total liabilities | [2] | 32,391 | 32,048 | ||
Exelon Generation Co L L C [Member] | Variable Interest Entity, Primary Beneficiary [Member] | |||||
Variable Interest Entity [Line Items] | |||||
Cash and cash equivalents | 168 | 414 | |||
Restricted cash and cash equivalents | 73 | 62 | |||
Accounts receivable, net | |||||
Customer | 163 | 146 | |||
Other | 43 | 23 | |||
Unamortized energy contract asset | 23 | 25 | |||
Inventory, net | |||||
Materials and supplies | 222 | 212 | |||
Other current assets | 48 | 49 | |||
Total current assets | 740 | 931 | |||
Property, plant and equipment, net | 6,079 | 6,188 | |||
NDT funds | 2,636 | 2,351 | |||
Unamortized energy contract asset | 258 | 274 | |||
Other Assets, Noncurrent | 52 | 232 | |||
Total noncurrent assets | 9,025 | 9,045 | |||
Total assets | 9,765 | 9,976 | |||
Long-term debt due within one year | 535 | 66 | |||
Accounts payable | 148 | 96 | |||
Accrued expenses | 57 | 72 | |||
Unamortized energy contract liabilities | 10 | 15 | |||
Other Liabilities, Current | 30 | 3 | |||
Total current liabilities | 780 | 252 | |||
Long-term debt | 504 | 1,025 | |||
Asset retirement obligations, noncurrent | 2,103 | 2,165 | |||
Unamortized energy contract liabilities | 1 | 1 | |||
Other Liabilities, Noncurrent | 84 | 42 | |||
Total noncurrent liabilities | 2,692 | 3,233 | |||
Total liabilities | 3,472 | 3,485 | |||
PP&E - unrestricted asset | 41 | 43 | |||
Variable Interest Entity, Consolidated, Liabilities, Recourse | 5 | 5 | |||
Pepco Holdings LLC [Member] | |||||
Variable Interest Entity [Line Items] | |||||
Cash and cash equivalents | 99 | 124 | 153 | 30 | |
Restricted cash and cash equivalents | 38 | 43 | 42 | 42 | |
Accounts receivable, net | |||||
Customer | 512 | 453 | |||
Other | 189 | 177 | |||
Inventory, net | |||||
Materials and supplies | 203 | 163 | |||
Other current assets | 50 | 75 | |||
Total current assets | 1,578 | 1,533 | |||
Property, plant and equipment, net | 13,968 | 13,446 | |||
Other Assets, Noncurrent | 356 | 60 | |||
Total assets | [3] | 22,576 | 21,984 | ||
Long-term debt due within one year | 118 | 125 | |||
Accounts payable | 416 | 496 | |||
Accrued expenses | 279 | 256 | |||
Unamortized energy contract liabilities | 117 | 119 | |||
Other Liabilities, Current | 152 | 123 | |||
Total current liabilities | 1,515 | 1,592 | |||
Long-term debt | 6,376 | 6,134 | |||
Asset retirement obligations, noncurrent | 57 | 52 | |||
Unamortized energy contract liabilities | 357 | 442 | |||
Other Liabilities, Noncurrent | 610 | 369 | |||
Total liabilities | [3] | 13,028 | 12,702 | ||
Pepco Holdings LLC [Member] | Variable Interest Entity, Primary Beneficiary [Member] | |||||
Variable Interest Entity [Line Items] | |||||
Cash and cash equivalents | 0 | 0 | |||
Restricted cash and cash equivalents | 3 | 4 | |||
Accounts receivable, net | |||||
Customer | 0 | 0 | |||
Other | 0 | 0 | |||
Unamortized energy contract asset | 0 | 0 | |||
Inventory, net | |||||
Materials and supplies | 0 | 0 | |||
Other current assets | 2 | 3 | |||
Total current assets | 5 | 7 | |||
Property, plant and equipment, net | 0 | 0 | |||
NDT funds | 0 | 0 | |||
Unamortized energy contract asset | 0 | 0 | |||
Other Assets, Noncurrent | 17 | 26 | |||
Total noncurrent assets | 17 | 26 | |||
Total assets | 22 | 33 | |||
Long-term debt due within one year | 21 | 21 | |||
Accounts payable | 0 | 0 | |||
Accrued expenses | 1 | 1 | |||
Unamortized energy contract liabilities | 0 | 0 | |||
Other Liabilities, Current | 0 | 0 | |||
Total current liabilities | 22 | 22 | |||
Long-term debt | 28 | 47 | |||
Asset retirement obligations, noncurrent | 0 | 0 | |||
Unamortized energy contract liabilities | 0 | 0 | |||
Other Liabilities, Noncurrent | 0 | 0 | |||
Total noncurrent liabilities | 28 | 47 | |||
Total liabilities | 50 | 69 | |||
Atlantic City Electric Company [Member] | |||||
Variable Interest Entity [Line Items] | |||||
Cash and cash equivalents | 13 | 7 | 11 | 2 | |
Restricted cash and cash equivalents | 3 | 4 | $ 7 | $ 6 | |
Accounts receivable, net | |||||
Customer | 142 | 95 | |||
Other | 47 | 55 | |||
Inventory, net | |||||
Other current assets | 7 | 5 | |||
Total current assets | 307 | 240 | |||
Property, plant and equipment, net | 3,124 | 2,966 | |||
Other Assets, Noncurrent | 59 | 40 | |||
Total assets | [4] | 3,916 | 3,699 | ||
Long-term debt due within one year | 19 | 18 | |||
Accounts payable | 139 | 154 | |||
Accrued expenses | 40 | 35 | |||
Other Liabilities, Current | 11 | 4 | |||
Total current liabilities | 347 | 422 | |||
Long-term debt | 1,305 | 1,170 | |||
Other Liabilities, Noncurrent | 44 | 27 | |||
Total liabilities | [4] | 2,648 | 2,573 | ||
Atlantic City Electric Company [Member] | Variable Interest Entity, Primary Beneficiary [Member] | |||||
Variable Interest Entity [Line Items] | |||||
Cash and cash equivalents | 0 | 0 | |||
Restricted cash and cash equivalents | 3 | 4 | |||
Accounts receivable, net | |||||
Customer | 0 | 0 | |||
Other | 0 | 0 | |||
Unamortized energy contract asset | 0 | 0 | |||
Inventory, net | |||||
Materials and supplies | 0 | 0 | |||
Other current assets | 0 | 0 | |||
Total current assets | 3 | 4 | |||
Property, plant and equipment, net | 0 | 0 | |||
NDT funds | 0 | 0 | |||
Unamortized energy contract asset | 0 | 0 | |||
Other Assets, Noncurrent | 15 | 19 | |||
Total noncurrent assets | 15 | 19 | |||
Total assets | 18 | 23 | |||
Long-term debt due within one year | 19 | 18 | |||
Accounts payable | 0 | 0 | |||
Accrued expenses | 1 | 1 | |||
Unamortized energy contract liabilities | 0 | 0 | |||
Other Liabilities, Current | 0 | 0 | |||
Total current liabilities | 20 | 19 | |||
Long-term debt | 26 | 40 | |||
Asset retirement obligations, noncurrent | 0 | 0 | |||
Unamortized energy contract liabilities | 0 | 0 | |||
Other Liabilities, Noncurrent | 0 | 0 | |||
Total noncurrent liabilities | 26 | 40 | |||
Total liabilities | $ 46 | $ 59 | |||
[1] | Exelon’s consolidated assets include $9,465 million and $9,667 million at September 30, 2019 and December 31, 2018 , respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Exelon’s consolidated liabilities include $3,517 million and $3,548 million at September 30, 2019 and December 31, 2018 , respectively, of certain VIEs for which the VIE creditors do not have recourse to Exelon. See Note 2 — Variable Interest Entities for additional information. | ||||
[2] | Generation’s consolidated assets include $9,443 million and $9,634 million at September 30, 2019 and December 31, 2018 , respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Generation’s consolidated liabilities include $3,467 million and $3,480 million at September 30, 2019 and December 31, 2018 , respectively, of certain VIEs for which the VIE creditors do not have recourse to Generation. See Note 2 — Variable Interest Entities for additional information. | ||||
[3] | PHI’s consolidated total assets include $22 million and $33 million at September 30, 2019 and December 31, 2018 , respectively, of PHI's consolidated VIE that can only be used to settle the liabilities of the VIE. PHI’s consolidated total liabilities include $50 million and $69 million at September 30, 2019 and December 31, 2018 , respectively, of PHI's consolidated VIE for which the VIE creditors do not have recourse to PHI. See Note 2 — Variable Interest Entities for additional information. | ||||
[4] | ACE’s consolidated total assets include $18 million and $23 million at September 30, 2019 and December 31, 2018 , respectively, of ACE's consolidated VIE that can only be used to settle the liabilities of the VIE. ACE’s consolidated total liabilities include $46 million and $59 million at September 30, 2019 and December 31, 2018 , respectively, of ACE's consolidated VIE for which the VIE creditors do not have recourse to ACE. See Note 2 — Variable Interest Entities for additional information. |
Variable Interest Entities - Su
Variable Interest Entities - Summary of Significant Unconsolidated VIEs (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Dec. 31, 2018 |
Variable Interest Entity [Line Items] | ||
Total assets | $ 1,067 | $ 1,069 |
Total liabilities | 260 | 259 |
Exelon's ownership interest in VIE | 201 | 223 |
Other ownership interests in VIE | 615 | 587 |
Carrying amount of equity method investments | ||
Variable Interest Entity [Line Items] | ||
Registrants' maximum exposure to loss | 12 | 223 |
Commercial Agreement Variable Interest Entities [Member] | ||
Variable Interest Entity [Line Items] | ||
Total assets | 614 | 597 |
Total liabilities | 36 | 37 |
Exelon's ownership interest in VIE | 0 | 0 |
Other ownership interests in VIE | 587 | 560 |
Commercial Agreement Variable Interest Entities [Member] | Carrying amount of equity method investments | ||
Variable Interest Entity [Line Items] | ||
Registrants' maximum exposure to loss | 0 | 0 |
Equity Investment VIE [Member] | ||
Variable Interest Entity [Line Items] | ||
Total assets | 453 | 472 |
Total liabilities | 224 | 222 |
Exelon's ownership interest in VIE | 201 | 223 |
Other ownership interests in VIE | 28 | 27 |
Equity Investment VIE [Member] | Carrying amount of equity method investments | ||
Variable Interest Entity [Line Items] | ||
Registrants' maximum exposure to loss | 12 | 223 |
Exelon Generation Co L L C [Member] | ||
Variable Interest Entity [Line Items] | ||
Total assets | 1,067 | 1,069 |
Total liabilities | 260 | 259 |
Exelon's ownership interest in VIE | 201 | 223 |
Other ownership interests in VIE | 615 | 587 |
Exelon Generation Co L L C [Member] | Carrying amount of equity method investments | ||
Variable Interest Entity [Line Items] | ||
Registrants' maximum exposure to loss | 12 | 223 |
Exelon Generation Co L L C [Member] | Commercial Agreement Variable Interest Entities [Member] | ||
Variable Interest Entity [Line Items] | ||
Total assets | 614 | 597 |
Total liabilities | 36 | 37 |
Exelon's ownership interest in VIE | 0 | 0 |
Other ownership interests in VIE | 587 | 560 |
Exelon Generation Co L L C [Member] | Commercial Agreement Variable Interest Entities [Member] | Carrying amount of equity method investments | ||
Variable Interest Entity [Line Items] | ||
Registrants' maximum exposure to loss | 0 | 0 |
Exelon Generation Co L L C [Member] | Equity Investment VIE [Member] | ||
Variable Interest Entity [Line Items] | ||
Total assets | 453 | 472 |
Total liabilities | 224 | 222 |
Exelon's ownership interest in VIE | 201 | 223 |
Other ownership interests in VIE | 28 | 27 |
Exelon Generation Co L L C [Member] | Equity Investment VIE [Member] | Carrying amount of equity method investments | ||
Variable Interest Entity [Line Items] | ||
Registrants' maximum exposure to loss | $ 12 | $ 223 |
Mergers, Acquisitions and Dis_2
Mergers, Acquisitions and Dispositions - Acquisitions Narrative (Details) - USD ($) $ in Millions | Apr. 04, 2018 | Sep. 30, 2019 | Sep. 30, 2018 |
Business Acquisition [Line Items] | |||
Payments to Acquire Businesses, Gross | $ 0 | $ 57 | |
Handley [Member] | |||
Business Acquisition [Line Items] | |||
Payments to Acquire Businesses, Gross | $ 62 | ||
Exelon Generation Co L L C [Member] | |||
Business Acquisition [Line Items] | |||
Payments to Acquire Businesses, Gross | $ 0 | $ 57 | |
Exelon Generation Co L L C [Member] | Handley [Member] | |||
Business Acquisition [Line Items] | |||
Payments to Acquire Businesses, Gross | $ 62 |
Mergers, Acquisitions and Dis_3
Mergers, Acquisitions and Dispositions - Dispositions Narrative (Details) - USD ($) $ in Millions | Feb. 28, 2018 | Sep. 30, 2019 | Jun. 30, 2019 | Mar. 31, 2019 | Sep. 30, 2018 | Sep. 30, 2018 | Dec. 31, 2018 |
Business Dispositions [Line Items] | |||||||
Assets held for sale | $ 18 | $ 904 | |||||
Liabilities held for sale | 11 | 777 | |||||
Asset Retirement Obligation, Revision of Estimate | (300) | $ 330 | $ 20 | ||||
Exelon Generation Co L L C [Member] | |||||||
Business Dispositions [Line Items] | |||||||
Assets held for sale | 18 | 904 | |||||
Liabilities held for sale | 11 | 777 | |||||
Asset Retirement Obligation, Revision of Estimate | (300) | $ 330 | $ 0 | ||||
Oyster Creek [Member] | |||||||
Business Dispositions [Line Items] | |||||||
Assets held for sale | 897 | ||||||
Liabilities held for sale | 777 | ||||||
Oyster Creek [Member] | Exelon Generation Co L L C [Member] | |||||||
Business Dispositions [Line Items] | |||||||
Assets held for sale | 897 | ||||||
Liabilities held for sale | $ 777 | ||||||
Electrical Contracting Business [Member] | |||||||
Business Dispositions [Line Items] | |||||||
Proceeds from Divestiture of Businesses | $ 87 | ||||||
Electrical Contracting Business [Member] | Exelon Generation Co L L C [Member] | |||||||
Business Dispositions [Line Items] | |||||||
Proceeds from Divestiture of Businesses | $ 87 | ||||||
Operating Expense [Member] | |||||||
Business Dispositions [Line Items] | |||||||
Asset Retirement Obligation, Revision of Estimate | (65) | ||||||
Operating Expense [Member] | Exelon Generation Co L L C [Member] | |||||||
Business Dispositions [Line Items] | |||||||
Asset Retirement Obligation, Revision of Estimate | $ (65) | ||||||
Operating Expense [Member] | Oyster Creek [Member] | |||||||
Business Dispositions [Line Items] | |||||||
Asset Retirement Obligation, Revision of Estimate | $ 9 | $ 84 | |||||
Operating Expense [Member] | Oyster Creek [Member] | Exelon Generation Co L L C [Member] | |||||||
Business Dispositions [Line Items] | |||||||
Asset Retirement Obligation, Revision of Estimate | $ 9 | $ 84 |
Revenue from Contracts with C_3
Revenue from Contracts with Customers - Change in Contract with Customer, Asset and Liability (Details) - USD ($) $ in Millions | 9 Months Ended | 12 Months Ended | |
Sep. 30, 2019 | Dec. 31, 2018 | Dec. 31, 2017 | |
Change in Contract with Customer, Asset and Liability [Line Items] | |||
Contract Assets | $ 170 | $ 187 | $ 283 |
Contract Liabilities | 26 | 27 | 35 |
Consideration (received) due, contract assets | (109) | (146) | |
Consideration received (due), contract liabilities | 65 | 179 | |
Revenues recognized, contract assets | 92 | 50 | |
Revenues recognized, contract liabilities | (66) | (187) | |
Exelon Generation Co L L C [Member] | |||
Change in Contract with Customer, Asset and Liability [Line Items] | |||
Contract Assets | 170 | 187 | 283 |
Contract Liabilities | 48 | 42 | $ 35 |
Consideration (received) due, contract assets | (109) | (146) | |
Consideration received (due), contract liabilities | 198 | 465 | |
Revenues recognized, contract assets | 92 | 50 | |
Revenues recognized, contract liabilities | $ (192) | $ (458) |
Revenue from Contracts with C_4
Revenue from Contracts with Customers - Performance Obligations (Details) $ in Millions | Sep. 30, 2019USD ($) |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation, Amount | $ 156 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | Exelon Generation Co L L C [Member] | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation, Amount | 215 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation, Amount | 341 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | Exelon Generation Co L L C [Member] | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation, Amount | 442 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation, Amount | 142 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Exelon Generation Co L L C [Member] | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation, Amount | 197 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation, Amount | 74 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Exelon Generation Co L L C [Member] | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation, Amount | 89 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation, Amount | 244 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Exelon Generation Co L L C [Member] | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation, Amount | 244 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil) | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation, Amount | 957 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil) | Exelon Generation Co L L C [Member] | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation, Amount | $ 1,187 |
Leases Lessee - Narrative (Deta
Leases Lessee - Narrative (Details) | 9 Months Ended |
Sep. 30, 2019 | |
Contracted Generation [Member] | |
Lessee, Lease, Description [Line Items] | |
Lessee, Operating Lease, Description | ● |
Real Estate [Member] | |
Lessee, Lease, Description [Line Items] | |
Lessee, Operating Lease, Description | ● |
Vehicles & Equipment [Member] | |
Lessee, Lease, Description [Line Items] | |
Lessee, Operating Lease, Description | ● |
Minimum [Member] | |
Lessee, Lease, Description [Line Items] | |
Remaining lease terms | 1 year |
Options to extend the term | 3 years |
Options to terminate within | 2 years |
Maximum [Member] | |
Lessee, Lease, Description [Line Items] | |
Remaining lease terms | 87 years |
Options to extend the term | 30 years |
Options to terminate within | 14 years |
Exelon Generation Co L L C [Member] | Contracted Generation [Member] | |
Lessee, Lease, Description [Line Items] | |
Lessee, Operating Lease, Description | ● |
Exelon Generation Co L L C [Member] | Real Estate [Member] | |
Lessee, Lease, Description [Line Items] | |
Lessee, Operating Lease, Description | ● |
Exelon Generation Co L L C [Member] | Vehicles & Equipment [Member] | |
Lessee, Lease, Description [Line Items] | |
Lessee, Operating Lease, Description | ● |
Exelon Generation Co L L C [Member] | Minimum [Member] | |
Lessee, Lease, Description [Line Items] | |
Remaining lease terms | 1 year |
Options to extend the term | 3 years |
Options to terminate within | 2 years |
Exelon Generation Co L L C [Member] | Maximum [Member] | |
Lessee, Lease, Description [Line Items] | |
Remaining lease terms | 37 years |
Options to extend the term | 30 years |
Options to terminate within | 2 years |
Commonwealth Edison Co [Member] | Real Estate [Member] | |
Lessee, Lease, Description [Line Items] | |
Lessee, Operating Lease, Description | ● |
Commonwealth Edison Co [Member] | Vehicles & Equipment [Member] | |
Lessee, Lease, Description [Line Items] | |
Lessee, Operating Lease, Description | ● |
Commonwealth Edison Co [Member] | Minimum [Member] | |
Lessee, Lease, Description [Line Items] | |
Remaining lease terms | 1 year |
Options to extend the term | 5 years |
Options to terminate within | 4 years |
Commonwealth Edison Co [Member] | Maximum [Member] | |
Lessee, Lease, Description [Line Items] | |
Remaining lease terms | 6 years |
Options to extend the term | 5 years |
Options to terminate within | 4 years |
PECO Energy Co [Member] | Real Estate [Member] | |
Lessee, Lease, Description [Line Items] | |
Lessee, Operating Lease, Description | ● |
PECO Energy Co [Member] | Vehicles & Equipment [Member] | |
Lessee, Lease, Description [Line Items] | |
Lessee, Operating Lease, Description | ● |
PECO Energy Co [Member] | Minimum [Member] | |
Lessee, Lease, Description [Line Items] | |
Remaining lease terms | 1 year |
PECO Energy Co [Member] | Maximum [Member] | |
Lessee, Lease, Description [Line Items] | |
Remaining lease terms | 15 years |
Baltimore Gas and Electric Company [Member] | Real Estate [Member] | |
Lessee, Lease, Description [Line Items] | |
Lessee, Operating Lease, Description | ● |
Baltimore Gas and Electric Company [Member] | Vehicles & Equipment [Member] | |
Lessee, Lease, Description [Line Items] | |
Lessee, Operating Lease, Description | ● |
Baltimore Gas and Electric Company [Member] | Minimum [Member] | |
Lessee, Lease, Description [Line Items] | |
Remaining lease terms | 1 year |
Options to terminate within | 3 years |
Baltimore Gas and Electric Company [Member] | Maximum [Member] | |
Lessee, Lease, Description [Line Items] | |
Remaining lease terms | 87 years |
Options to terminate within | 3 years |
Pepco Holdings LLC [Member] | Real Estate [Member] | |
Lessee, Lease, Description [Line Items] | |
Lessee, Operating Lease, Description | ● |
Pepco Holdings LLC [Member] | Vehicles & Equipment [Member] | |
Lessee, Lease, Description [Line Items] | |
Lessee, Operating Lease, Description | ● |
Pepco Holdings LLC [Member] | Minimum [Member] | |
Lessee, Lease, Description [Line Items] | |
Remaining lease terms | 1 year |
Options to extend the term | 3 years |
Pepco Holdings LLC [Member] | Maximum [Member] | |
Lessee, Lease, Description [Line Items] | |
Remaining lease terms | 13 years |
Options to extend the term | 30 years |
Potomac Electric Power Company [Member] | Real Estate [Member] | |
Lessee, Lease, Description [Line Items] | |
Lessee, Operating Lease, Description | ● |
Potomac Electric Power Company [Member] | Vehicles & Equipment [Member] | |
Lessee, Lease, Description [Line Items] | |
Lessee, Operating Lease, Description | ● |
Potomac Electric Power Company [Member] | Minimum [Member] | |
Lessee, Lease, Description [Line Items] | |
Remaining lease terms | 1 year |
Options to extend the term | 5 years |
Potomac Electric Power Company [Member] | Maximum [Member] | |
Lessee, Lease, Description [Line Items] | |
Remaining lease terms | 13 years |
Options to extend the term | 5 years |
Delmarva Power and Light Company [Member] | Real Estate [Member] | |
Lessee, Lease, Description [Line Items] | |
Lessee, Operating Lease, Description | ● |
Delmarva Power and Light Company [Member] | Vehicles & Equipment [Member] | |
Lessee, Lease, Description [Line Items] | |
Lessee, Operating Lease, Description | ● |
Delmarva Power and Light Company [Member] | Minimum [Member] | |
Lessee, Lease, Description [Line Items] | |
Remaining lease terms | 1 year |
Options to extend the term | 3 years |
Delmarva Power and Light Company [Member] | Maximum [Member] | |
Lessee, Lease, Description [Line Items] | |
Remaining lease terms | 13 years |
Options to extend the term | 30 years |
Atlantic City Electric Company [Member] | Real Estate [Member] | |
Lessee, Lease, Description [Line Items] | |
Lessee, Operating Lease, Description | ● |
Atlantic City Electric Company [Member] | Vehicles & Equipment [Member] | |
Lessee, Lease, Description [Line Items] | |
Lessee, Operating Lease, Description | ● |
Atlantic City Electric Company [Member] | Minimum [Member] | |
Lessee, Lease, Description [Line Items] | |
Remaining lease terms | 1 year |
Atlantic City Electric Company [Member] | Maximum [Member] | |
Lessee, Lease, Description [Line Items] | |
Remaining lease terms | 8 years |
Leases Lessee - Components of L
Leases Lessee - Components of Lease Cost (Details) $ in Millions | 3 Months Ended | 9 Months Ended |
Sep. 30, 2019USD ($) | Sep. 30, 2019USD ($) | |
Schedule of Components of Lease Cost [Line Items] | ||
Operating Lease Costs | $ 97 | $ 252 |
Variable Lease Costs | 79 | 229 |
Short-term Lease Costs | 5 | 16 |
Total Lease Costs | 181 | 497 |
Sublease Income | $ 29 | $ 48 |
Operating Lease, Weighted Average Remaining Lease Term | 10 years 1 month 6 days | 10 years 1 month 6 days |
Operating Lease Weighted Average Discount Rate, Percent | 4.50% | 4.50% |
Exelon Generation Co L L C [Member] | ||
Schedule of Components of Lease Cost [Line Items] | ||
Operating Lease Costs | $ 73 | $ 180 |
Variable Lease Costs | 74 | 214 |
Short-term Lease Costs | 5 | 16 |
Total Lease Costs | 152 | 410 |
Sublease Income | $ 28 | $ 42 |
Operating Lease, Weighted Average Remaining Lease Term | 10 years 7 months 6 days | 10 years 7 months 6 days |
Operating Lease Weighted Average Discount Rate, Percent | 4.80% | 4.80% |
Commonwealth Edison Co [Member] | ||
Schedule of Components of Lease Cost [Line Items] | ||
Operating Lease Costs | $ 1 | $ 2 |
Variable Lease Costs | 0 | 1 |
Short-term Lease Costs | 0 | 0 |
Total Lease Costs | $ 1 | $ 3 |
Operating Lease, Weighted Average Remaining Lease Term | 4 years 8 months 12 days | 4 years 8 months 12 days |
Operating Lease Weighted Average Discount Rate, Percent | 3.10% | 3.10% |
PECO Energy Co [Member] | ||
Schedule of Components of Lease Cost [Line Items] | ||
Operating Lease Costs | $ 0 | $ 1 |
Variable Lease Costs | 0 | 0 |
Short-term Lease Costs | 0 | 0 |
Total Lease Costs | $ 0 | $ 1 |
Operating Lease, Weighted Average Remaining Lease Term | 4 years 3 months 18 days | 4 years 3 months 18 days |
Operating Lease Weighted Average Discount Rate, Percent | 3.30% | 3.30% |
Baltimore Gas and Electric Company [Member] | ||
Schedule of Components of Lease Cost [Line Items] | ||
Operating Lease Costs | $ 8 | $ 25 |
Variable Lease Costs | 1 | 1 |
Short-term Lease Costs | 0 | 0 |
Total Lease Costs | $ 9 | $ 26 |
Operating Lease, Weighted Average Remaining Lease Term | 5 years 7 months 6 days | 5 years 7 months 6 days |
Operating Lease Weighted Average Discount Rate, Percent | 3.60% | 3.60% |
Pepco Holdings LLC [Member] | ||
Schedule of Components of Lease Cost [Line Items] | ||
Operating Lease Costs | $ 12 | $ 35 |
Variable Lease Costs | 1 | 5 |
Short-term Lease Costs | 0 | 0 |
Total Lease Costs | 13 | 40 |
Sublease Income | $ 1 | $ 6 |
Operating Lease, Weighted Average Remaining Lease Term | 9 years | 9 years |
Operating Lease Weighted Average Discount Rate, Percent | 4.00% | 4.00% |
Potomac Electric Power Company [Member] | ||
Schedule of Components of Lease Cost [Line Items] | ||
Operating Lease Costs | $ 3 | $ 9 |
Variable Lease Costs | 0 | 2 |
Short-term Lease Costs | 0 | 0 |
Total Lease Costs | $ 3 | $ 11 |
Operating Lease, Weighted Average Remaining Lease Term | 9 years 7 months 6 days | 9 years 7 months 6 days |
Operating Lease Weighted Average Discount Rate, Percent | 3.70% | 3.70% |
Delmarva Power and Light Company [Member] | ||
Schedule of Components of Lease Cost [Line Items] | ||
Operating Lease Costs | $ 3 | $ 10 |
Variable Lease Costs | 0 | 2 |
Short-term Lease Costs | 0 | 0 |
Total Lease Costs | 3 | 12 |
Sublease Income | $ 1 | $ 6 |
Operating Lease, Weighted Average Remaining Lease Term | 9 years 6 months | 9 years 6 months |
Operating Lease Weighted Average Discount Rate, Percent | 3.70% | 3.70% |
Atlantic City Electric Company [Member] | ||
Schedule of Components of Lease Cost [Line Items] | ||
Operating Lease Costs | $ 2 | $ 5 |
Variable Lease Costs | 0 | 1 |
Short-term Lease Costs | 0 | 0 |
Total Lease Costs | $ 2 | $ 6 |
Operating Lease, Weighted Average Remaining Lease Term | 5 years 3 months 18 days | 5 years 3 months 18 days |
Operating Lease Weighted Average Discount Rate, Percent | 3.30% | 3.30% |
Leases Lessee - Supplemental Ba
Leases Lessee - Supplemental Balance Sheet Information Related to Lessee Right-of-Use Assets and Lease Liabilities (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Dec. 31, 2018 |
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred debits and other assets | $ 3,123 | $ 1,575 |
Other current liabilities | 1,425 | 1,035 |
Other deferred credits and other liabilities | 3,123 | 2,130 |
Total Operating Lease Liabilities | 1,597 | |
Exelon Generation Co L L C [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred debits and other assets | 1,915 | 755 |
Other current liabilities | 541 | 279 |
Other deferred credits and other liabilities | 1,466 | 610 |
Total Operating Lease Liabilities | 1,119 | |
Commonwealth Edison Co [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred debits and other assets | 351 | 395 |
Other current liabilities | 138 | 96 |
Other deferred credits and other liabilities | 621 | 630 |
Total Operating Lease Liabilities | 11 | |
PECO Energy Co [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred debits and other assets | 30 | 27 |
Other current liabilities | 27 | 24 |
Other deferred credits and other liabilities | 79 | 76 |
Total Operating Lease Liabilities | 1 | |
Baltimore Gas and Electric Company [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred debits and other assets | 88 | 5 |
Other current liabilities | 63 | 27 |
Other deferred credits and other liabilities | 112 | 73 |
Total Operating Lease Liabilities | 82 | |
Pepco Holdings LLC [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred debits and other assets | 356 | 60 |
Other current liabilities | 152 | 123 |
Other deferred credits and other liabilities | 610 | 369 |
Total Operating Lease Liabilities | 314 | |
Potomac Electric Power Company [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred debits and other assets | 76 | 15 |
Other current liabilities | 25 | 42 |
Other deferred credits and other liabilities | 311 | 275 |
Total Operating Lease Liabilities | 68 | |
Delmarva Power and Light Company [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred debits and other assets | 82 | 6 |
Other current liabilities | 33 | 7 |
Other deferred credits and other liabilities | 114 | 50 |
Total Operating Lease Liabilities | 85 | |
Atlantic City Electric Company [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred debits and other assets | 59 | 40 |
Other current liabilities | 11 | 4 |
Other deferred credits and other liabilities | 44 | $ 27 |
Total Operating Lease Liabilities | 24 | |
Contracted Generation [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred debits and other assets | 542 | |
Total Operating Lease Liabilities | 703 | |
Contracted Generation [Member] | Exelon Generation Co L L C [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred debits and other assets | 542 | |
Total Operating Lease Liabilities | 703 | |
Other Deferred Debits and Other Assets [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred debits and other assets | 1,374 | |
Other Deferred Debits and Other Assets [Member] | Exelon Generation Co L L C [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred debits and other assets | 926 | |
Other Deferred Debits and Other Assets [Member] | Commonwealth Edison Co [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred debits and other assets | 10 | |
Other Deferred Debits and Other Assets [Member] | PECO Energy Co [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred debits and other assets | 2 | |
Other Deferred Debits and Other Assets [Member] | Baltimore Gas and Electric Company [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred debits and other assets | 83 | |
Other Deferred Debits and Other Assets [Member] | Pepco Holdings LLC [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred debits and other assets | 304 | |
Other Deferred Debits and Other Assets [Member] | Potomac Electric Power Company [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred debits and other assets | 66 | |
Other Deferred Debits and Other Assets [Member] | Delmarva Power and Light Company [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred debits and other assets | 75 | |
Other Deferred Debits and Other Assets [Member] | Atlantic City Electric Company [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred debits and other assets | 24 | |
Other Current Liabilities [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other current liabilities | 242 | |
Other Current Liabilities [Member] | Exelon Generation Co L L C [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other current liabilities | 170 | |
Other Current Liabilities [Member] | Commonwealth Edison Co [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other current liabilities | 3 | |
Other Current Liabilities [Member] | PECO Energy Co [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other current liabilities | 0 | |
Other Current Liabilities [Member] | Baltimore Gas and Electric Company [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other current liabilities | 32 | |
Other Current Liabilities [Member] | Pepco Holdings LLC [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other current liabilities | 35 | |
Other Current Liabilities [Member] | Potomac Electric Power Company [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other current liabilities | 8 | |
Other Current Liabilities [Member] | Delmarva Power and Light Company [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other current liabilities | 11 | |
Other Current Liabilities [Member] | Atlantic City Electric Company [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other current liabilities | 5 | |
Other Deferred Credits and Other Liabilities [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred credits and other liabilities | 1,355 | |
Other Deferred Credits and Other Liabilities [Member] | Exelon Generation Co L L C [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred credits and other liabilities | 949 | |
Other Deferred Credits and Other Liabilities [Member] | Commonwealth Edison Co [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred credits and other liabilities | 8 | |
Other Deferred Credits and Other Liabilities [Member] | PECO Energy Co [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred credits and other liabilities | 1 | |
Other Deferred Credits and Other Liabilities [Member] | Baltimore Gas and Electric Company [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred credits and other liabilities | 50 | |
Other Deferred Credits and Other Liabilities [Member] | Pepco Holdings LLC [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred credits and other liabilities | 279 | |
Other Deferred Credits and Other Liabilities [Member] | Potomac Electric Power Company [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred credits and other liabilities | 60 | |
Other Deferred Credits and Other Liabilities [Member] | Delmarva Power and Light Company [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred credits and other liabilities | 74 | |
Other Deferred Credits and Other Liabilities [Member] | Atlantic City Electric Company [Member] | ||
Supplemental Balance Sheet Information [Line Items] | ||
Other deferred credits and other liabilities | $ 19 |
Leases Lessee - Future Minimum
Leases Lessee - Future Minimum Operating Lease Maturity Payments (Details) $ in Millions | Sep. 30, 2019USD ($) |
Schedule of Lessee, Operating Lease, Liability, Maturity [Line Items] | |
2019 | $ 65 |
2020 | 289 |
2021 | 246 |
2022 | 179 |
2023 | 148 |
Remaining Years | 1,123 |
Total | 2,050 |
Interest | 453 |
Total Operating Lease Liabilities | 1,597 |
Exelon Generation Co L L C [Member] | |
Schedule of Lessee, Operating Lease, Liability, Maturity [Line Items] | |
2019 | 50 |
2020 | 203 |
2021 | 162 |
2022 | 113 |
2023 | 100 |
Remaining Years | 837 |
Total | 1,465 |
Interest | 346 |
Total Operating Lease Liabilities | 1,119 |
Commonwealth Edison Co [Member] | |
Schedule of Lessee, Operating Lease, Liability, Maturity [Line Items] | |
2019 | 1 |
2020 | 3 |
2021 | 3 |
2022 | 2 |
2023 | 1 |
Remaining Years | 2 |
Total | 12 |
Interest | 1 |
Total Operating Lease Liabilities | 11 |
PECO Energy Co [Member] | |
Schedule of Lessee, Operating Lease, Liability, Maturity [Line Items] | |
2019 | 0 |
2020 | 1 |
2021 | 0 |
2022 | 0 |
2023 | 0 |
Remaining Years | 0 |
Total | 1 |
Interest | 0 |
Total Operating Lease Liabilities | 1 |
Baltimore Gas and Electric Company [Member] | |
Schedule of Lessee, Operating Lease, Liability, Maturity [Line Items] | |
2019 | 1 |
2020 | 34 |
2021 | 31 |
2022 | 16 |
2023 | 0 |
Remaining Years | 19 |
Total | 101 |
Interest | 19 |
Total Operating Lease Liabilities | 82 |
Pepco Holdings LLC [Member] | |
Schedule of Lessee, Operating Lease, Liability, Maturity [Line Items] | |
2019 | 11 |
2020 | 45 |
2021 | 43 |
2022 | 42 |
2023 | 41 |
Remaining Years | 197 |
Total | 379 |
Interest | 65 |
Total Operating Lease Liabilities | 314 |
Potomac Electric Power Company [Member] | |
Schedule of Lessee, Operating Lease, Liability, Maturity [Line Items] | |
2019 | 3 |
2020 | 10 |
2021 | 9 |
2022 | 9 |
2023 | 8 |
Remaining Years | 43 |
Total | 82 |
Interest | 14 |
Total Operating Lease Liabilities | 68 |
Delmarva Power and Light Company [Member] | |
Schedule of Lessee, Operating Lease, Liability, Maturity [Line Items] | |
2019 | 2 |
2020 | 13 |
2021 | 12 |
2022 | 12 |
2023 | 11 |
Remaining Years | 53 |
Total | 103 |
Interest | 18 |
Total Operating Lease Liabilities | 85 |
Atlantic City Electric Company [Member] | |
Schedule of Lessee, Operating Lease, Liability, Maturity [Line Items] | |
2019 | 2 |
2020 | 5 |
2021 | 5 |
2022 | 4 |
2023 | 4 |
Remaining Years | 6 |
Total | 26 |
Interest | 2 |
Total Operating Lease Liabilities | $ 24 |
Leases Lessee - 2018 Schedule o
Leases Lessee - 2018 Schedule of Minimum Future Operating Lease Payments (Details) $ in Millions | Dec. 31, 2018USD ($) |
Operating Leases Future Minimum Payments Due [Line Items] | |
2019 | $ 140 |
2020 | 149 |
2021 | 143 |
2022 | 126 |
2023 | 97 |
Remaining Years | 723 |
Total Minimum Future Lease Payments | 1,378 |
Exelon Generation Co L L C [Member] | |
Operating Leases Future Minimum Payments Due [Line Items] | |
2019 | 33 |
2020 | 46 |
2021 | 46 |
2022 | 47 |
2023 | 46 |
Remaining Years | 545 |
Total Minimum Future Lease Payments | 763 |
Commonwealth Edison Co [Member] | |
Operating Leases Future Minimum Payments Due [Line Items] | |
2019 | 7 |
2020 | 5 |
2021 | 4 |
2022 | 4 |
2023 | 3 |
Remaining Years | 0 |
Total Minimum Future Lease Payments | 23 |
PECO Energy Co [Member] | |
Operating Leases Future Minimum Payments Due [Line Items] | |
2019 | 5 |
2020 | 5 |
2021 | 5 |
2022 | 5 |
2023 | 5 |
Remaining Years | 0 |
Total Minimum Future Lease Payments | 25 |
Baltimore Gas and Electric Company [Member] | |
Operating Leases Future Minimum Payments Due [Line Items] | |
2019 | 35 |
2020 | 35 |
2021 | 33 |
2022 | 18 |
2023 | 3 |
Remaining Years | 19 |
Total Minimum Future Lease Payments | 143 |
Pepco Holdings LLC [Member] | |
Operating Leases Future Minimum Payments Due [Line Items] | |
2019 | 48 |
2020 | 46 |
2021 | 43 |
2022 | 42 |
2023 | 39 |
Remaining Years | 159 |
Total Minimum Future Lease Payments | 377 |
Potomac Electric Power Company [Member] | |
Operating Leases Future Minimum Payments Due [Line Items] | |
2019 | 11 |
2020 | 10 |
2021 | 9 |
2022 | 8 |
2023 | 8 |
Remaining Years | 40 |
Total Minimum Future Lease Payments | 86 |
Delmarva Power and Light Company [Member] | |
Operating Leases Future Minimum Payments Due [Line Items] | |
2019 | 14 |
2020 | 13 |
2021 | 12 |
2022 | 12 |
2023 | 10 |
Remaining Years | 35 |
Total Minimum Future Lease Payments | 96 |
Atlantic City Electric Company [Member] | |
Operating Leases Future Minimum Payments Due [Line Items] | |
2019 | 7 |
2020 | 6 |
2021 | 5 |
2022 | 5 |
2023 | 4 |
Remaining Years | 5 |
Total Minimum Future Lease Payments | 32 |
Real Estate Leases and Railroad Licenses [Member] | Commonwealth Edison Co [Member] | |
Operating Leases Future Minimum Payments Due [Line Items] | |
Total Minimum Future Lease Payments | 3 |
Real Estate Leases and Railroad Licenses [Member] | PECO Energy Co [Member] | |
Operating Leases Future Minimum Payments Due [Line Items] | |
Total Minimum Future Lease Payments | 5 |
Real Estate Leases and Railroad Licenses [Member] | Baltimore Gas and Electric Company [Member] | |
Operating Leases Future Minimum Payments Due [Line Items] | |
Total Minimum Future Lease Payments | 1 |
Real Estate Leases and Railroad Licenses [Member] | Delmarva Power and Light Company [Member] | |
Operating Leases Future Minimum Payments Due [Line Items] | |
Total Minimum Future Lease Payments | 1 |
Electrical Conduit System [Member] | Baltimore Gas and Electric Company [Member] | |
Operating Leases Future Minimum Payments Due [Line Items] | |
2019 | 26 |
2020 | 28 |
2021 | 28 |
2022 | $ 14 |
Leases Lessee - Supplemental Ca
Leases Lessee - Supplemental Cash Flow Information Related to Leases (Details) $ in Millions | 9 Months Ended |
Sep. 30, 2019USD ($) | |
Supplemental Cash Flow Information [Line Items] | |
Operating cash flows from operating leases | $ 225 |
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability | 70 |
Exelon Generation Co L L C [Member] | |
Supplemental Cash Flow Information [Line Items] | |
Operating cash flows from operating leases | 156 |
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability | 11 |
Commonwealth Edison Co [Member] | |
Supplemental Cash Flow Information [Line Items] | |
Operating cash flows from operating leases | 2 |
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability | 6 |
PECO Energy Co [Member] | |
Supplemental Cash Flow Information [Line Items] | |
Operating cash flows from operating leases | 0 |
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability | 0 |
Baltimore Gas and Electric Company [Member] | |
Supplemental Cash Flow Information [Line Items] | |
Operating cash flows from operating leases | 32 |
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability | 1 |
Pepco Holdings LLC [Member] | |
Supplemental Cash Flow Information [Line Items] | |
Operating cash flows from operating leases | 29 |
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability | 20 |
Potomac Electric Power Company [Member] | |
Supplemental Cash Flow Information [Line Items] | |
Operating cash flows from operating leases | 7 |
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability | 7 |
Delmarva Power and Light Company [Member] | |
Supplemental Cash Flow Information [Line Items] | |
Operating cash flows from operating leases | 6 |
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability | 9 |
Atlantic City Electric Company [Member] | |
Supplemental Cash Flow Information [Line Items] | |
Operating cash flows from operating leases | 4 |
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability | $ 4 |
Leases Lessor - Narrative (Deta
Leases Lessor - Narrative (Details) | 9 Months Ended |
Sep. 30, 2019 | |
Contracted Generation [Member] | |
Lessor, Lease, Description [Line Items] | |
Lessor, Operating Lease, Description | ● |
Real Estate [Member] | |
Lessor, Lease, Description [Line Items] | |
Lessor, Operating Lease, Description | ● |
Minimum [Member] | |
Lessor, Lease, Description [Line Items] | |
Remaining lease terms | 1 year |
Options to extend the term | 1 years |
Maximum [Member] | |
Lessor, Lease, Description [Line Items] | |
Remaining lease terms | 84 years |
Options to extend the term | 79 years |
Exelon Generation Co L L C [Member] | Contracted Generation [Member] | |
Lessor, Lease, Description [Line Items] | |
Lessor, Operating Lease, Description | ● |
Exelon Generation Co L L C [Member] | Real Estate [Member] | |
Lessor, Lease, Description [Line Items] | |
Lessor, Operating Lease, Description | ● |
Exelon Generation Co L L C [Member] | Minimum [Member] | |
Lessor, Lease, Description [Line Items] | |
Remaining lease terms | 1 year |
Options to extend the term | 1 years |
Exelon Generation Co L L C [Member] | Maximum [Member] | |
Lessor, Lease, Description [Line Items] | |
Remaining lease terms | 33 years |
Options to extend the term | 5 years |
Commonwealth Edison Co [Member] | Real Estate [Member] | |
Lessor, Lease, Description [Line Items] | |
Lessor, Operating Lease, Description | ● |
Commonwealth Edison Co [Member] | Minimum [Member] | |
Lessor, Lease, Description [Line Items] | |
Remaining lease terms | 1 year |
Options to extend the term | 5 years |
Commonwealth Edison Co [Member] | Maximum [Member] | |
Lessor, Lease, Description [Line Items] | |
Remaining lease terms | 18 years |
Options to extend the term | 79 years |
PECO Energy Co [Member] | Real Estate [Member] | |
Lessor, Lease, Description [Line Items] | |
Lessor, Operating Lease, Description | ● |
PECO Energy Co [Member] | Minimum [Member] | |
Lessor, Lease, Description [Line Items] | |
Remaining lease terms | 1 year |
Options to extend the term | 5 years |
PECO Energy Co [Member] | Maximum [Member] | |
Lessor, Lease, Description [Line Items] | |
Remaining lease terms | 84 years |
Options to extend the term | 50 years |
Baltimore Gas and Electric Company [Member] | Real Estate [Member] | |
Lessor, Lease, Description [Line Items] | |
Lessor, Operating Lease, Description | ● |
Baltimore Gas and Electric Company [Member] | Minimum [Member] | |
Lessor, Lease, Description [Line Items] | |
Remaining lease terms | 24 years |
Baltimore Gas and Electric Company [Member] | Maximum [Member] | |
Lessor, Lease, Description [Line Items] | |
Remaining lease terms | 24 years |
Pepco Holdings LLC [Member] | Real Estate [Member] | |
Lessor, Lease, Description [Line Items] | |
Lessor, Operating Lease, Description | ● |
Pepco Holdings LLC [Member] | Minimum [Member] | |
Lessor, Lease, Description [Line Items] | |
Remaining lease terms | 1 year |
Options to extend the term | 5 years |
Pepco Holdings LLC [Member] | Maximum [Member] | |
Lessor, Lease, Description [Line Items] | |
Remaining lease terms | 14 years |
Options to extend the term | 5 years |
Potomac Electric Power Company [Member] | Real Estate [Member] | |
Lessor, Lease, Description [Line Items] | |
Lessor, Operating Lease, Description | ● |
Potomac Electric Power Company [Member] | Minimum [Member] | |
Lessor, Lease, Description [Line Items] | |
Remaining lease terms | 2 years |
Potomac Electric Power Company [Member] | Maximum [Member] | |
Lessor, Lease, Description [Line Items] | |
Remaining lease terms | 7 years |
Delmarva Power and Light Company [Member] | Real Estate [Member] | |
Lessor, Lease, Description [Line Items] | |
Lessor, Operating Lease, Description | ● |
Delmarva Power and Light Company [Member] | Minimum [Member] | |
Lessor, Lease, Description [Line Items] | |
Remaining lease terms | 13 years |
Delmarva Power and Light Company [Member] | Maximum [Member] | |
Lessor, Lease, Description [Line Items] | |
Remaining lease terms | 14 years |
Atlantic City Electric Company [Member] | Real Estate [Member] | |
Lessor, Lease, Description [Line Items] | |
Lessor, Operating Lease, Description | ● |
Atlantic City Electric Company [Member] | Minimum [Member] | |
Lessor, Lease, Description [Line Items] | |
Remaining lease terms | 1 year |
Atlantic City Electric Company [Member] | Maximum [Member] | |
Lessor, Lease, Description [Line Items] | |
Remaining lease terms | 3 years |
Leases Lessor - Components of O
Leases Lessor - Components of Operating Lease Income (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended |
Sep. 30, 2019 | Sep. 30, 2019 | |
Schedule of Operating Lease, Lease Income [Line Items] | ||
Operating Lease Income | $ 30 | $ 48 |
Variable Lease Income | 80 | 209 |
Exelon Generation Co L L C [Member] | ||
Schedule of Operating Lease, Lease Income [Line Items] | ||
Operating Lease Income | 29 | 44 |
Variable Lease Income | 80 | 206 |
Commonwealth Edison Co [Member] | ||
Schedule of Operating Lease, Lease Income [Line Items] | ||
Operating Lease Income | 0 | 0 |
Variable Lease Income | 0 | 0 |
PECO Energy Co [Member] | ||
Schedule of Operating Lease, Lease Income [Line Items] | ||
Operating Lease Income | 0 | 0 |
Variable Lease Income | 0 | 0 |
Baltimore Gas and Electric Company [Member] | ||
Schedule of Operating Lease, Lease Income [Line Items] | ||
Operating Lease Income | 0 | 0 |
Variable Lease Income | 0 | 0 |
Pepco Holdings LLC [Member] | ||
Schedule of Operating Lease, Lease Income [Line Items] | ||
Operating Lease Income | 1 | 3 |
Variable Lease Income | 0 | 3 |
Potomac Electric Power Company [Member] | ||
Schedule of Operating Lease, Lease Income [Line Items] | ||
Operating Lease Income | 0 | 0 |
Variable Lease Income | 0 | 0 |
Delmarva Power and Light Company [Member] | ||
Schedule of Operating Lease, Lease Income [Line Items] | ||
Operating Lease Income | 1 | 3 |
Variable Lease Income | 0 | 3 |
Atlantic City Electric Company [Member] | ||
Schedule of Operating Lease, Lease Income [Line Items] | ||
Operating Lease Income | 0 | 0 |
Variable Lease Income | $ 0 | $ 0 |
Leases Lessor - Future Minimum
Leases Lessor - Future Minimum Operating Lease Maturity Payments (Details) $ in Millions | Sep. 30, 2019USD ($) |
Schedule of Lessor, Operating Lease, Payments to be Received, Maturity [Line Items] | |
2019 | $ 4 |
2020 | 51 |
2021 | 50 |
2022 | 50 |
2023 | 49 |
Remaining years | 314 |
Total | 518 |
Exelon Generation Co L L C [Member] | |
Schedule of Lessor, Operating Lease, Payments to be Received, Maturity [Line Items] | |
2019 | 3 |
2020 | 46 |
2021 | 45 |
2022 | 45 |
2023 | 45 |
Remaining years | 271 |
Total | 455 |
Commonwealth Edison Co [Member] | |
Schedule of Lessor, Operating Lease, Payments to be Received, Maturity [Line Items] | |
2019 | 0 |
2020 | 0 |
2021 | 0 |
2022 | 0 |
2023 | 0 |
Remaining years | 1 |
Total | 1 |
PECO Energy Co [Member] | |
Schedule of Lessor, Operating Lease, Payments to be Received, Maturity [Line Items] | |
2019 | 0 |
2020 | 0 |
2021 | 0 |
2022 | 0 |
2023 | 0 |
Remaining years | 3 |
Total | 3 |
Baltimore Gas and Electric Company [Member] | |
Schedule of Lessor, Operating Lease, Payments to be Received, Maturity [Line Items] | |
2019 | 0 |
2020 | 0 |
2021 | 0 |
2022 | 0 |
2023 | 0 |
Remaining years | 1 |
Total | 1 |
Pepco Holdings LLC [Member] | |
Schedule of Lessor, Operating Lease, Payments to be Received, Maturity [Line Items] | |
2019 | 1 |
2020 | 4 |
2021 | 4 |
2022 | 5 |
2023 | 4 |
Remaining years | 38 |
Total | 56 |
Potomac Electric Power Company [Member] | |
Schedule of Lessor, Operating Lease, Payments to be Received, Maturity [Line Items] | |
2019 | 0 |
2020 | 0 |
2021 | 1 |
2022 | 0 |
2023 | 0 |
Remaining years | 0 |
Total | 1 |
Delmarva Power and Light Company [Member] | |
Schedule of Lessor, Operating Lease, Payments to be Received, Maturity [Line Items] | |
2019 | 1 |
2020 | 3 |
2021 | 3 |
2022 | 4 |
2023 | 3 |
Remaining years | 38 |
Total | 52 |
Atlantic City Electric Company [Member] | |
Schedule of Lessor, Operating Lease, Payments to be Received, Maturity [Line Items] | |
2019 | 0 |
2020 | 0 |
2021 | 0 |
2022 | 0 |
2023 | 0 |
Remaining years | 0 |
Total | $ 0 |
Regulatory Matters - Narrative
Regulatory Matters - Narrative (Details) - USD ($) $ in Millions | Oct. 29, 2019 | Jul. 22, 2019 | May 23, 2019 | Apr. 18, 2019 | Feb. 28, 2019 | May 01, 2017 | Sep. 30, 2019 | Sep. 30, 2018 | Dec. 31, 2017 | Sep. 30, 2019 | Sep. 30, 2018 |
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Payments to Acquire Property, Plant, and Equipment | $ 1,687 | $ 1,690 | $ 5,259 | $ 5,497 | |||||||
Maximum [Member] | One-Time Revenue Adjustment [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 80 | 80 | |||||||||
PECO Energy Co [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | $ 22 | ||||||||||
Public Utilities, Requested Equity Capital Structure, Percentage | 10.35% | 11.00% | |||||||||
Revenue | 8 | 6 | |||||||||
Payments to Acquire Property, Plant, and Equipment | 675 | 615 | |||||||||
Increase (Decrease) in Regulatory Assets | 62 | ||||||||||
Commonwealth Edison Co [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | $ 51 | 5 | |||||||||
Revenue | $ (2) | (16) | |||||||||
Payments to Acquire Property, Plant, and Equipment | 1,413 | 1,540 | |||||||||
Increase (Decrease) in Regulatory Assets | 122 | ||||||||||
Commonwealth Edison Co [Member] | Maximum [Member] | One-Time Revenue Adjustment [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 52 | 52 | |||||||||
Baltimore Gas and Electric Company [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | (19) | ||||||||||
Revenue | (23) | ||||||||||
Payments to Acquire Property, Plant, and Equipment | 842 | 667 | |||||||||
Increase (Decrease) in Regulatory Liabilities | (90) | ||||||||||
Baltimore Gas and Electric Company [Member] | Maximum [Member] | One-Time Revenue Adjustment [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 16 | 16 | |||||||||
Pepco Holdings LLC [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Payments to Acquire Property, Plant, and Equipment | 1,006 | 988 | |||||||||
Pepco Holdings LLC [Member] | Maximum [Member] | One-Time Revenue Adjustment [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 12 | 12 | |||||||||
Potomac Electric Power Company [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | 26 | ||||||||||
Revenue | 11 | ||||||||||
Payments to Acquire Property, Plant, and Equipment | 455 | 475 | |||||||||
Increase (Decrease) in Regulatory Assets | (84) | ||||||||||
Increase (Decrease) in Regulatory Liabilities | (71) | ||||||||||
Potomac Electric Power Company [Member] | Maximum [Member] | One-Time Revenue Adjustment [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 4 | 4 | |||||||||
Atlantic City Electric Company [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | 9 | ||||||||||
Revenue | (2) | ||||||||||
Payments to Acquire Property, Plant, and Equipment | $ 96 | $ 338 | 300 | 247 | |||||||
Increase (Decrease) in Regulatory Liabilities | (30) | ||||||||||
Atlantic City Electric Company [Member] | Maximum [Member] | One-Time Revenue Adjustment [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 2 | 2 | |||||||||
Delmarva Power and Light Company [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | 16 | ||||||||||
Revenue | (1) | ||||||||||
Payments to Acquire Property, Plant, and Equipment | 245 | 254 | |||||||||
Increase (Decrease) in Regulatory Liabilities | (42) | ||||||||||
Delmarva Power and Light Company [Member] | Maximum [Member] | One-Time Revenue Adjustment [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 6 | 6 | |||||||||
Exelon Generation Co L L C [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Payments to Acquire Property, Plant, and Equipment | 1,282 | 1,660 | |||||||||
Deferred Income Tax Charge [Member] | PECO Energy Co [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Increase (Decrease) in Regulatory Assets | 95 | ||||||||||
Deferred Income Tax Charge [Member] | Baltimore Gas and Electric Company [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Increase (Decrease) in Regulatory Liabilities | (40) | ||||||||||
Deferred Income Tax Charge [Member] | Potomac Electric Power Company [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Increase (Decrease) in Regulatory Liabilities | (73) | ||||||||||
Deferred Income Tax Charge [Member] | Atlantic City Electric Company [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Increase (Decrease) in Regulatory Liabilities | (32) | ||||||||||
Deferred Income Tax Charge [Member] | Delmarva Power and Light Company [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Increase (Decrease) in Regulatory Liabilities | (29) | ||||||||||
Removal Costs [Member] | Baltimore Gas and Electric Company [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Increase (Decrease) in Regulatory Liabilities | (43) | ||||||||||
Clean Energy Legislation [Member] | Exelon Generation Co L L C [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Competitive businesses other revenues | $ 21 | $ 31 | |||||||||
Nuclear Plant [Member] | Exelon Generation Co L L C [Member] | Salem [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Jointly Owned Utility Plant, Proportionate Ownership Interest, percentage | 42.59% | 42.59% | |||||||||
Generation commodities and services | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Revenue from Contract with Customer, Including Assessed Tax | $ 4,499 | 4,971 | $ 13,436 | 14,387 | |||||||
Generation commodities and services | Exelon Generation Co L L C [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 4,499 | $ 4,970 | 13,436 | $ 14,389 | |||||||
Generation commodities and services | Zero Emission Standard [Member] | Exelon Generation Co L L C [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Revenue from Contract with Customer, Including Assessed Tax | $ 150 | ||||||||||
License and Service [Member] | Conowingo [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
License Costs | 41 | 41 | |||||||||
License and Service [Member] | Conowingo [Member] | Subsequent Event [Member] | Maximum [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Environmental Remediation Expense | $ 14 | ||||||||||
License and Service [Member] | Conowingo [Member] | Subsequent Event [Member] | Minimum [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Environmental Remediation Expense | 11 | ||||||||||
License and Service [Member] | Conowingo [Member] | Exelon Generation Co L L C [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
License Costs | $ 41 | 41 | |||||||||
License and Service [Member] | Conowingo [Member] | Exelon Generation Co L L C [Member] | Subsequent Event [Member] | Maximum [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Environmental Remediation Expense | 14 | ||||||||||
License and Service [Member] | Conowingo [Member] | Exelon Generation Co L L C [Member] | Subsequent Event [Member] | Minimum [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Environmental Remediation Expense | $ 11 | ||||||||||
Energy Efficiency Costs [Member] | PECO Energy Co [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Increase (Decrease) in Regulatory Assets | (34) | ||||||||||
Energy Efficiency Costs [Member] | Commonwealth Edison Co [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Increase (Decrease) in Regulatory Assets | 186 | ||||||||||
Renewable Energy Program [Member] | Commonwealth Edison Co [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Increase (Decrease) in Regulatory Assets | 32 | ||||||||||
Electric Distribution Formula Rate Annual Reconciliations [Member] | Commonwealth Edison Co [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Increase (Decrease) in Regulatory Assets | (97) | ||||||||||
Under Recovered Energy and Natural Gas Costs [Member] | Potomac Electric Power Company [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Increase (Decrease) in Regulatory Assets | (39) | ||||||||||
Under Recovered Energy and Natural Gas Costs [Member] | Delmarva Power and Light Company [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Increase (Decrease) in Regulatory Liabilities | (10) | ||||||||||
DC PLUG Charge [Member] | Potomac Electric Power Company [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Increase (Decrease) in Regulatory Assets | (26) | ||||||||||
Advanced Metering Infrastructure Legacy Meter Costs [Member] | Potomac Electric Power Company [Member] | |||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | |||||||||||
Increase (Decrease) in Regulatory Assets | $ (14) |
Regulatory Matters Schedule of
Regulatory Matters Schedule of Completed Rate Cases (Details) (Details) - USD ($) $ in Millions | Aug. 12, 2019 | May 24, 2019 | May 23, 2019 | Apr. 08, 2019 | Mar. 13, 2019 | Jan. 15, 2019 | Jan. 04, 2019 | Dec. 20, 2018 | Dec. 04, 2018 | Nov. 19, 2018 | Jun. 08, 2018 | Apr. 16, 2018 | Mar. 29, 2018 | Sep. 30, 2019 | Dec. 31, 2018 |
Commonwealth Edison Co [Member] | |||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||
Requested Revenue Requirement Increase (Decrease) | $ 53 | $ 21 | |||||||||||||
Approved Return on Equity, Percentage | 11.50% | 10.91% | |||||||||||||
Commonwealth Edison Co [Member] | Electric Distribution [Member] | |||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||
Requested Revenue Requirement Increase (Decrease) | $ (6) | $ (23) | $ 57 | ||||||||||||
Approved Revenue Requirement Increase (Decrease) | $ (24) | $ (63) | |||||||||||||
Approved Return on Equity, Percentage | 8.69% | ||||||||||||||
PECO Energy Co [Member] | Electricity [Member] | |||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||
Requested Revenue Requirement Increase (Decrease) | $ 82 | ||||||||||||||
Approved Revenue Requirement Increase (Decrease) | $ 25 | ||||||||||||||
Baltimore Gas and Electric Company [Member] | |||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||
Requested Revenue Requirement Increase (Decrease) | $ (10) | ||||||||||||||
Approved Return on Equity, Percentage | 10.50% | ||||||||||||||
Baltimore Gas and Electric Company [Member] | Electric Distribution [Member] | |||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||
Requested Revenue Requirement Increase (Decrease) | $ 74 | ||||||||||||||
Baltimore Gas and Electric Company [Member] | Gas Distribution [Member] | |||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||
Requested Revenue Requirement Increase (Decrease) | $ 59 | $ 61 | |||||||||||||
Approved Revenue Requirement Increase (Decrease) | $ 43 | ||||||||||||||
Approved Return on Equity, Percentage | 9.80% | ||||||||||||||
Atlantic City Electric Company [Member] | |||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||
Requested Revenue Requirement Increase (Decrease) | $ 11 | ||||||||||||||
Approved Return on Equity, Percentage | 10.50% | ||||||||||||||
Atlantic City Electric Company [Member] | Electric Distribution [Member] | |||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||
Requested Revenue Requirement Increase (Decrease) | $ 122 | ||||||||||||||
Approved Revenue Requirement Increase (Decrease) | $ 70 | ||||||||||||||
Approved Return on Equity, Percentage | 9.60% | ||||||||||||||
Potomac Electric Power Company [Member] | |||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||
Requested Revenue Requirement Increase (Decrease) | $ 15 | ||||||||||||||
Approved Return on Equity, Percentage | 10.50% | ||||||||||||||
MARYLAND | Potomac Electric Power Company [Member] | Electric Distribution [Member] | |||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||
Requested Revenue Requirement Increase (Decrease) | $ 27 | ||||||||||||||
Approved Revenue Requirement Increase (Decrease) | $ 10 | ||||||||||||||
Approved Return on Equity, Percentage | 9.60% |
Regulatory Matters Schedule o_2
Regulatory Matters Schedule of Pending Rate Cases (Details) (Details) - USD ($) $ in Millions | Oct. 25, 2019 | Aug. 12, 2019 | May 30, 2019 | May 24, 2019 | May 23, 2019 | Apr. 08, 2019 | Jan. 15, 2019 | Jan. 04, 2019 | Dec. 04, 2018 | Jun. 08, 2018 | Apr. 16, 2018 | Sep. 30, 2019 | Dec. 31, 2022 | Dec. 31, 2021 | Dec. 31, 2020 | Dec. 31, 2018 |
Potomac Electric Power Company [Member] | ||||||||||||||||
Regulatory Matters Pending Rate Cases [Line Items] | ||||||||||||||||
Requested Revenue Requirement Increase (Decrease), Amended | $ 26 | |||||||||||||||
Requested Revenue Requirement Increase (Decrease) | 15 | |||||||||||||||
Commonwealth Edison Co [Member] | ||||||||||||||||
Regulatory Matters Pending Rate Cases [Line Items] | ||||||||||||||||
Requested Revenue Requirement Increase (Decrease), Amended | $ 51 | 5 | ||||||||||||||
Requested Revenue Requirement Increase (Decrease) | $ 53 | 21 | ||||||||||||||
Requested Return on Equity, Percentage | 8.91% | |||||||||||||||
Baltimore Gas and Electric Company [Member] | ||||||||||||||||
Regulatory Matters Pending Rate Cases [Line Items] | ||||||||||||||||
Requested Revenue Requirement Increase (Decrease), Amended | (19) | |||||||||||||||
Requested Revenue Requirement Increase (Decrease) | (10) | |||||||||||||||
Electric Distribution [Member] | Commonwealth Edison Co [Member] | ||||||||||||||||
Regulatory Matters Pending Rate Cases [Line Items] | ||||||||||||||||
Requested Revenue Requirement Increase (Decrease) | $ (6) | $ (23) | $ 57 | |||||||||||||
Requested Return on Equity, Percentage | 8.91% | |||||||||||||||
Approved Revenue Requirement Increase (Decrease) | $ (24) | $ (63) | ||||||||||||||
Requested Return on Distribution Rate Base, Percentage | 6.53% | 6.53% | ||||||||||||||
Electric Distribution [Member] | Baltimore Gas and Electric Company [Member] | ||||||||||||||||
Regulatory Matters Pending Rate Cases [Line Items] | ||||||||||||||||
Requested Revenue Requirement Increase (Decrease) | $ 74 | |||||||||||||||
Requested Return on Equity, Percentage | 10.30% | |||||||||||||||
Electric Distribution [Member] | Baltimore Gas and Electric Company [Member] | Subsequent Event [Member] | ||||||||||||||||
Regulatory Matters Pending Rate Cases [Line Items] | ||||||||||||||||
Requested Revenue Requirement Increase (Decrease) | $ 18 | |||||||||||||||
Requested Return on Equity, Percentage | 4500000000.00% | |||||||||||||||
Gas Distribution [Member] | Baltimore Gas and Electric Company [Member] | ||||||||||||||||
Regulatory Matters Pending Rate Cases [Line Items] | ||||||||||||||||
Requested Revenue Requirement Increase (Decrease) | $ 59 | $ 61 | ||||||||||||||
Requested Return on Equity, Percentage | 10.30% | |||||||||||||||
Approved Revenue Requirement Increase (Decrease) | $ 43 | |||||||||||||||
MARYLAND | Electric Distribution [Member] | Potomac Electric Power Company [Member] | ||||||||||||||||
Regulatory Matters Pending Rate Cases [Line Items] | ||||||||||||||||
Requested Revenue Requirement Increase (Decrease) | $ 27 | |||||||||||||||
Approved Revenue Requirement Increase (Decrease) | $ 10 | |||||||||||||||
DISTRICT OF COLUMBIA | Electric Distribution [Member] | Potomac Electric Power Company [Member] | ||||||||||||||||
Regulatory Matters Pending Rate Cases [Line Items] | ||||||||||||||||
Requested Revenue Requirement Increase (Decrease) | $ 160 | |||||||||||||||
Requested Return on Equity, Percentage | 10.30% | |||||||||||||||
DISTRICT OF COLUMBIA | Forecast [Member] | Electric Distribution [Member] | Potomac Electric Power Company [Member] | ||||||||||||||||
Regulatory Matters Pending Rate Cases [Line Items] | ||||||||||||||||
Requested Revenue Requirement Increase (Decrease) | $ 36 | $ 40 | $ 84 |
Regulatory Matters - Annual Ele
Regulatory Matters - Annual Electric Transmission Fillings (Details) - USD ($) $ in Millions | May 23, 2019 | Sep. 30, 2019 | Sep. 30, 2019 | Dec. 31, 2018 |
Commonwealth Edison Co [Member] | ||||
Public Utilities, General Disclosures [Line Items] | ||||
Initial Revenue Requirement Increase (Decrease) | $ 53 | $ 21 | ||
Annual Reconciliation Increase (Decrease) | (2) | (16) | ||
Total Revenue Requirement Increase (Decrease) | $ 51 | $ 5 | ||
Allowed Return on Rate Base, Percentage | 8.21% | |||
Allowed Return on Equity, Percentage | 11.50% | 10.91% | ||
Cap on Equity Component of Rate of Return on Common Equity in Federal Energy Regulatory Committee Complaint | 55.00% | |||
Baltimore Gas and Electric Company [Member] | ||||
Public Utilities, General Disclosures [Line Items] | ||||
Initial Revenue Requirement Increase (Decrease) | $ (10) | |||
Annual Reconciliation Increase (Decrease) | (23) | |||
Total Revenue Requirement Increase (Decrease) | $ (19) | |||
Allowed Return on Rate Base, Percentage | 7.35% | |||
Allowed Return on Equity, Percentage | 10.50% | |||
Proposed Capital Expenditure | $ 14 | |||
Potomac Electric Power Company [Member] | ||||
Public Utilities, General Disclosures [Line Items] | ||||
Initial Revenue Requirement Increase (Decrease) | 15 | |||
Annual Reconciliation Increase (Decrease) | 11 | |||
Total Revenue Requirement Increase (Decrease) | $ 26 | |||
Allowed Return on Rate Base, Percentage | 7.75% | |||
Allowed Return on Equity, Percentage | 10.50% | |||
Delmarva Power and Light Company [Member] | ||||
Public Utilities, General Disclosures [Line Items] | ||||
Initial Revenue Requirement Increase (Decrease) | $ 17 | |||
Annual Reconciliation Increase (Decrease) | (1) | |||
Total Revenue Requirement Increase (Decrease) | $ 16 | |||
Allowed Return on Rate Base, Percentage | 7.14% | |||
Allowed Return on Equity, Percentage | 10.50% | |||
Atlantic City Electric Company [Member] | ||||
Public Utilities, General Disclosures [Line Items] | ||||
Initial Revenue Requirement Increase (Decrease) | $ 11 | |||
Annual Reconciliation Increase (Decrease) | (2) | |||
Total Revenue Requirement Increase (Decrease) | $ 9 | |||
Allowed Return on Rate Base, Percentage | 7.79% | |||
Allowed Return on Equity, Percentage | 10.50% | |||
Clean Energy Legislation [Member] | Exelon Generation Co L L C [Member] | ||||
Public Utilities, General Disclosures [Line Items] | ||||
Other Operating Income | $ 21 | $ 31 |
Regulatory Matters Energy Effic
Regulatory Matters Energy Efficiency Formula Rate (Details) - Commonwealth Edison Co [Member] - USD ($) $ in Millions | May 23, 2019 | Apr. 08, 2019 | Dec. 04, 2018 | Apr. 16, 2018 | Sep. 30, 2019 | Dec. 31, 2018 |
Schedule of Energy Efficiency Formula Rate Updates [Line Items] | ||||||
Initial Revenue Requirement Increase (Decrease) | $ 53 | $ 21 | ||||
Annual Reconciliation Increase (Decrease) | (2) | (16) | ||||
Total Revenue Requirement Increase (Decrease) | $ 51 | $ 5 | ||||
Requested Return on Equity, Percentage | 8.91% | |||||
Allowed Return on Equity, Percentage | 11.50% | 10.91% | ||||
Allowed Return on Rate Base, Percentage | 8.21% | |||||
Electric Distribution [Member] | ||||||
Schedule of Energy Efficiency Formula Rate Updates [Line Items] | ||||||
Initial Revenue Requirement Increase (Decrease) | $ (6) | $ (23) | $ 57 | |||
Requested Return on Distribution Rate Base, Percentage | 6.53% | 6.53% | ||||
Requested Return on Equity, Percentage | 8.91% | |||||
Allowed Return on Equity, Percentage | 8.69% | |||||
Allowed Return on Rate Base, Percentage | 7.49% |
Regulatory Matters - Capitalize
Regulatory Matters - Capitalized Ratemaking Amount Not Recognized (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Dec. 31, 2018 |
Public Utility, Property, Plant and Equipment [Line Items] | ||
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes | $ 59 | $ 65 |
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 | 4 | 8 |
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 | 47 | 49 |
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 | 8 | 8 |
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 | 5 | 5 |
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 | 3 | 3 |
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 |
Asset Impairments - Narrative (
Asset Impairments - Narrative (Details) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2019USD ($) | Sep. 30, 2018USD ($) | Sep. 30, 2019USD ($)MW | Sep. 30, 2018USD ($) | |
Property, Plant and Equipment [Line Items] | ||||
Net Income (Loss) Attributable to Noncontrolling Interest | $ (12) | $ 67 | $ 56 | $ 121 |
Deferred Income Taxes and Tax Credits | 412 | 97 | ||
Impairment of long-lived assets | 174 | 49 | ||
Exelon Generation Co L L C [Member] | ||||
Property, Plant and Equipment [Line Items] | ||||
Net Income (Loss) Attributable to Noncontrolling Interest | (13) | $ 66 | 56 | 120 |
Deferred Income Taxes and Tax Credits | 201 | (278) | ||
Impairment of long-lived assets | 174 | $ 49 | ||
Antelope Valley [Member] | ||||
Property, Plant and Equipment [Line Items] | ||||
Long-lived assets | 730 | 730 | ||
Impairment of long-lived assets | $ 0 | |||
Antelope Valley [Member] | Exelon Generation Co L L C [Member] | ||||
Property, Plant and Equipment [Line Items] | ||||
Capacity Of Facility Of Company Owned Solar Distribution Generation Facilities | MW | 242 | |||
Long-lived assets | 730 | $ 730 | ||
Impairment of long-lived assets | 0 | |||
ExGen Renewables IV, LLC [Member] | ||||
Property, Plant and Equipment [Line Items] | ||||
Long-lived assets | 1,930 | 1,930 | ||
ExGen Renewables IV, LLC [Member] | Exelon Generation Co L L C [Member] | ||||
Property, Plant and Equipment [Line Items] | ||||
Long-lived assets | 1,930 | $ 1,930 | ||
Certain Distributed Energy Companies [Member] | ||||
Property, Plant and Equipment [Line Items] | ||||
Equity Method Investment, Other than Temporary Impairment | 164 | |||
Net Income (Loss) Attributable to Noncontrolling Interest | 96 | |||
Deferred Income Taxes and Tax Credits | (46) | |||
Income (Loss) from Equity Method Investments | (15) | |||
Certain Distributed Energy Companies [Member] | Exelon Generation Co L L C [Member] | ||||
Property, Plant and Equipment [Line Items] | ||||
Equity Method Investment, Other than Temporary Impairment | 164 | |||
Net Income (Loss) Attributable to Noncontrolling Interest | 96 | |||
Deferred Income Taxes and Tax Credits | (46) | |||
Income (Loss) from Equity Method Investments | $ (15) |
Early Plant Retirements - Narra
Early Plant Retirements - Narrative (Details) | Sep. 30, 2019 |
Salem [Member] | Nuclear Plant [Member] | Exelon Generation Co L L C [Member] | |
Property, Plant and Equipment [Line Items] | |
Jointly Owned Utility Plant, Proportionate Ownership Share | 42.59% |
Early Plant Retirements - Preta
Early Plant Retirements - Pretax Expense (Details) - Facility Closing [Member] - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2019 | Sep. 30, 2018 | |
Three Mile Island [Member] | ||||
Accelerated depreciation | $ 71 | $ 216 | ||
Accelerated nuclear fuel amortization | 3 | 13 | ||
Operating and maintenance | 39 | (44) | ||
Restructuring and Related Cost, Incurred Cost | 113 | 185 | ||
TMI,OysterCreek [Member] | ||||
Accelerated depreciation | $ 152 | $ 441 | ||
Accelerated nuclear fuel amortization | 18 | 52 | ||
Operating and maintenance | 4 | 32 | ||
Restructuring and Related Cost, Incurred Cost | 174 | 525 | ||
Exelon Generation Co L L C [Member] | Three Mile Island [Member] | ||||
Accelerated depreciation | 71 | 216 | ||
Accelerated nuclear fuel amortization | 3 | 13 | ||
Operating and maintenance | 39 | (44) | ||
Restructuring and Related Cost, Incurred Cost | $ 113 | $ 185 | ||
Exelon Generation Co L L C [Member] | TMI,OysterCreek [Member] | ||||
Accelerated depreciation | 152 | 441 | ||
Accelerated nuclear fuel amortization | 18 | 52 | ||
Operating and maintenance | 4 | 32 | ||
Restructuring and Related Cost, Incurred Cost | $ 174 | $ 525 |
Early Plant Retirements - Impli
Early Plant Retirements - Implications of Potential Early Plant Retirement on Balance Sheet (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Dec. 31, 2018 |
Implications of Potential Early Plant Retirement [Line Items] | ||
Completed plant, net | $ 78,593 | $ 76,707 |
Mystic Generating Station [Member] | Facility Closing [Member] | ||
Implications of Potential Early Plant Retirement [Line Items] | ||
Materials and supplies inventory | 31 | |
Fuel inventory | 5 | |
Completed plant, net | 889 | |
Construction work in progress | 7 | |
Asset retirement obligation | (2) | |
Exelon Generation Co L L C [Member] | ||
Implications of Potential Early Plant Retirement [Line Items] | ||
Completed plant, net | 23,591 | $ 23,981 |
Exelon Generation Co L L C [Member] | Mystic Generating Station [Member] | Facility Closing [Member] | ||
Implications of Potential Early Plant Retirement [Line Items] | ||
Materials and supplies inventory | 31 | |
Fuel inventory | 5 | |
Completed plant, net | 889 | |
Construction work in progress | 7 | |
Asset retirement obligation | $ (2) |
Fair Value of Financial Asset_3
Fair Value of Financial Assets and Liabilities - Narrative (Details) $ in Millions | Sep. 30, 2019USD ($) |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Equity Securities without Readily Determinable Fair Value, Amount | $ 75 |
Exelon Generation Co L L C [Member] | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Equity Securities without Readily Determinable Fair Value, Amount | 75 |
Fixed Income Securities [Member] | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments | 93 |
Fixed Income Securities [Member] | Exelon Generation Co L L C [Member] | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments | 93 |
Middle Market Lending [Member] | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments | 241 |
Middle Market Lending [Member] | Exelon Generation Co L L C [Member] | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments | 241 |
Private Equity Funds [Member] | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments | 383 |
Private Equity Funds [Member] | Exelon Generation Co L L C [Member] | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments | 383 |
Real Estate Funds [Member] | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments | 388 |
Real Estate Funds [Member] | Exelon Generation Co L L C [Member] | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments | $ 388 |
Fair Value of Financial Asset_4
Fair Value of Financial Assets and Liabilities - Fair Value of Financial Liabilities Recorded at Amortized Cost (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Dec. 31, 2018 |
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt to financing trust | $ 390 | $ 390 |
Spent Nuclear Fuel Obligation, Noncurrent | 1,193 | 1,171 |
Reported Value Measurement [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 36,304 | 35,424 |
Long-term debt to financing trust | 390 | 390 |
Spent Nuclear Fuel Obligation, Noncurrent | 1,193 | 1,171 |
Estimate of Fair Value Measurement [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 40,597 | 35,869 |
Long-term debt to financing trust | 426 | 400 |
Spent Nuclear Fuel Obligation, Noncurrent | 1,017 | 949 |
Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 0 | 0 |
Long-term debt to financing trust | 0 | 0 |
Spent Nuclear Fuel Obligation, Noncurrent | 0 | 0 |
Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 38,056 | 33,711 |
Long-term debt to financing trust | 0 | 0 |
Spent Nuclear Fuel Obligation, Noncurrent | 1,017 | 949 |
Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 2,541 | 2,158 |
Long-term debt to financing trust | 426 | 400 |
Spent Nuclear Fuel Obligation, Noncurrent | 0 | 0 |
Exelon Generation Co L L C [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Spent Nuclear Fuel Obligation, Noncurrent | 1,193 | 1,171 |
Exelon Generation Co L L C [Member] | Reported Value Measurement [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 8,613 | 8,793 |
Spent Nuclear Fuel Obligation, Noncurrent | 1,193 | 1,171 |
Exelon Generation Co L L C [Member] | Estimate of Fair Value Measurement [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 9,360 | 8,910 |
Spent Nuclear Fuel Obligation, Noncurrent | 1,017 | 949 |
Exelon Generation Co L L C [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 0 | 0 |
Spent Nuclear Fuel Obligation, Noncurrent | 0 | 0 |
Exelon Generation Co L L C [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 7,962 | 7,467 |
Spent Nuclear Fuel Obligation, Noncurrent | 1,017 | 949 |
Exelon Generation Co L L C [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 1,398 | 1,443 |
Spent Nuclear Fuel Obligation, Noncurrent | 0 | 0 |
Commonwealth Edison Co [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt to financing trust | 205 | 205 |
Commonwealth Edison Co [Member] | Reported Value Measurement [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 8,196 | 8,101 |
Long-term debt to financing trust | 205 | 205 |
Commonwealth Edison Co [Member] | Estimate of Fair Value Measurement [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 9,622 | 8,390 |
Long-term debt to financing trust | 223 | 209 |
Commonwealth Edison Co [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 0 | 0 |
Long-term debt to financing trust | 0 | 0 |
Commonwealth Edison Co [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 9,622 | 8,390 |
Long-term debt to financing trust | 0 | 0 |
Commonwealth Edison Co [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 0 | 0 |
Long-term debt to financing trust | 223 | 209 |
PECO Energy Co [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt to financing trust | 184 | 184 |
PECO Energy Co [Member] | Reported Value Measurement [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 3,404 | 3,084 |
Long-term debt to financing trust | 184 | 184 |
PECO Energy Co [Member] | Estimate of Fair Value Measurement [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 3,941 | 3,207 |
Long-term debt to financing trust | 203 | 191 |
PECO Energy Co [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 0 | 0 |
Long-term debt to financing trust | 0 | 0 |
PECO Energy Co [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 3,891 | 3,157 |
Long-term debt to financing trust | 0 | 0 |
PECO Energy Co [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 50 | 50 |
Long-term debt to financing trust | 203 | 191 |
Baltimore Gas and Electric Company [Member] | Reported Value Measurement [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 3,270 | 2,876 |
Baltimore Gas and Electric Company [Member] | Estimate of Fair Value Measurement [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 3,678 | 2,950 |
Baltimore Gas and Electric Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 0 | 0 |
Baltimore Gas and Electric Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 3,678 | 2,950 |
Baltimore Gas and Electric Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 0 | 0 |
Pepco Holdings LLC [Member] | Reported Value Measurement [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 6,494 | 6,259 |
Pepco Holdings LLC [Member] | Estimate of Fair Value Measurement [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 7,086 | 6,101 |
Pepco Holdings LLC [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 0 | 0 |
Pepco Holdings LLC [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 5,993 | 5,436 |
Pepco Holdings LLC [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 1,093 | 665 |
Potomac Electric Power Company [Member] | Reported Value Measurement [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 2,860 | 2,719 |
Potomac Electric Power Company [Member] | Estimate of Fair Value Measurement [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 3,644 | 3,097 |
Potomac Electric Power Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 0 | 0 |
Potomac Electric Power Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 3,249 | 2,901 |
Potomac Electric Power Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 395 | 196 |
Delmarva Power and Light Company [Member] | Reported Value Measurement [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 1,495 | 1,494 |
Delmarva Power and Light Company [Member] | Estimate of Fair Value Measurement [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 1,669 | 1,496 |
Delmarva Power and Light Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 0 | 0 |
Delmarva Power and Light Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 1,437 | 1,303 |
Delmarva Power and Light Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 232 | 193 |
Atlantic City Electric Company [Member] | Reported Value Measurement [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 1,324 | 1,188 |
Atlantic City Electric Company [Member] | Estimate of Fair Value Measurement [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 1,500 | 1,262 |
Atlantic City Electric Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 0 | 0 |
Atlantic City Electric Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | 1,034 | 987 |
Atlantic City Electric Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member] | ||
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract] | ||
Long-term debt (including amounts due within one year) | $ 466 | $ 275 |
Fair Value of Financial Asset_5
Fair Value of Financial Assets and Liabilities - Fair Value Measurements of Assets and Liabilities, Recurring and Nonrecurring (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Dec. 31, 2018 |
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Mark-to-market derivative liabilities (current liabilities) | $ 239 | $ 475 |
Derivative Liability, Noncurrent | 416 | 479 |
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value | 2 | |
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value | 44 | |
Derivative Asset, Notional Amount | 864 | 1,432 |
Margin Deposit Liabilities | (94) | |
Margin Deposit Assets | 306 | |
Cash and Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 347 | 458 |
Restricted cash member [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 112 | 80 |
Other Assets [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 186 | 185 |
Nuclear Decommissioning Trust Fund Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Net assets (liabilities) excluded from nuclear decommissioning trust fund investments | 176 | 130 |
Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 1,719 | 1,243 |
Assets, Fair Value Disclosure | 16,097 | 15,557 |
Deferred Compensation Liability, Current and Noncurrent | (140) | (137) |
Total Liabilities | (758) | (1,084) |
Fair Value, Net Asset (Liability) | 15,339 | 14,473 |
Fair Value, Recurring [Member] | Commodity Derivative Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (618) | (947) |
Fair Value, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (4,154) | (4,881) |
Fair Value, Recurring [Member] | Proprietary Trading Liabilities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (148) | (94) |
Fair Value, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | 3,684 | 4,028 |
Fair Value, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 13,038 | 12,825 |
Fair Value, Recurring [Member] | Cash Equivalents NDT [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 393 | 338 |
Fair Value, Recurring [Member] | Equity Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 6,162 | 5,890 |
Fair Value, Recurring [Member] | Fixed Income Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 4,804 | 5,078 |
Fair Value, Recurring [Member] | Corporate Debt Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 1,732 | 1,823 |
Fair Value, Recurring [Member] | US Treasury and Government [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 1,929 | 2,180 |
Fair Value, Recurring [Member] | Debt Security, Government, Non-US [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 56 | 50 |
Fair Value, Recurring [Member] | State and municipal debt [Domain] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 85 | 149 |
Fair Value, Recurring [Member] | Other Fixed Income [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 1,002 | 876 |
Fair Value, Recurring [Member] | Middle Market Lending [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 700 | 680 |
Fair Value, Recurring [Member] | Private Equity Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 398 | 329 |
Fair Value, Recurring [Member] | Real Estate Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 581 | 510 |
Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 255 | 243 |
Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 49 | 48 |
Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 77 | 72 |
Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 13 | 15 |
Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 116 | 108 |
Fair Value, Recurring [Member] | Economic Hedging Instrument [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 3,838 | 4,771 |
Fair Value, Recurring [Member] | Proprietary Trading [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 210 | 146 |
Fair Value, Recurring [Member] | Effects of netting and allocation of collateral [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | (2,963) | (3,671) |
Fair Value, Recurring [Member] | Commodity Derivative Assets [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 1,085 | 1,246 |
Fair Value, Inputs, Level 1 [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Collateral received from counterparties, net of collateral paid to counterparties | 93 | 57 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 1,719 | 1,243 |
Assets, Fair Value Disclosure | 6,914 | 6,573 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | (3) | (3) |
Fair Value, Net Asset (Liability) | 6,911 | 6,570 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (3) | (3) |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (773) | (642) |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Proprietary Trading Liabilities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | 0 | 0 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | 770 | 639 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 5,213 | 5,251 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Cash Equivalents NDT [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 315 | 252 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Equity Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 3,121 | 2,918 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Fixed Income Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 1,777 | 2,081 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Corporate Debt Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | US Treasury and Government [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 1,777 | 2,081 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Debt Security, Government, Non-US [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | State and municipal debt [Domain] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Other Fixed Income [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Middle Market Lending [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Private Equity Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Real Estate Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 126 | 120 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 49 | 48 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 77 | 72 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 533 | 541 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Proprietary Trading [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 0 | 0 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Effects of netting and allocation of collateral [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | (677) | (582) |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Assets [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | (144) | (41) |
Fair Value, Inputs, Level 2 [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Collateral received from counterparties, net of collateral paid to counterparties | 324 | 224 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 0 |
Assets, Fair Value Disclosure | 3,964 | 4,155 |
Deferred Compensation Liability, Current and Noncurrent | (140) | (137) |
Total Liabilities | (309) | (592) |
Fair Value, Net Asset (Liability) | 3,655 | 3,563 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (169) | (455) |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (1,695) | (2,963) |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Proprietary Trading Liabilities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (59) | (73) |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | 1,585 | 2,581 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 3,594 | 3,598 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Cash Equivalents NDT [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 78 | 86 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Equity Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 1,727 | 1,591 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Fixed Income Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 1,789 | 1,921 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Corporate Debt Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 1,473 | 1,593 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | US Treasury and Government [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 152 | 99 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Debt Security, Government, Non-US [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 56 | 50 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | State and municipal debt [Domain] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 85 | 149 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Other Fixed Income [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 23 | 30 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Middle Market Lending [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Private Equity Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Real Estate Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 89 | 85 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 13 | 15 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 76 | 70 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 1,488 | 2,760 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Proprietary Trading [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 54 | 69 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Effects of netting and allocation of collateral [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | (1,261) | (2,357) |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Assets [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 281 | 472 |
Fair Value, Inputs, Level 3 [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Collateral received from counterparties, net of collateral paid to counterparties | 304 | 76 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 0 |
Assets, Fair Value Disclosure | 1,502 | 1,396 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | (446) | (489) |
Fair Value, Net Asset (Liability) | 1,056 | 907 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (446) | (489) |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (1,686) | (1,276) |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Proprietary Trading Liabilities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (89) | (21) |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | 1,329 | 808 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 514 | 543 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Cash Equivalents NDT [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Equity Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Fixed Income Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 259 | 230 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Corporate Debt Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 259 | 230 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | US Treasury and Government [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Debt Security, Government, Non-US [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | State and municipal debt [Domain] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Other Fixed Income [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Middle Market Lending [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 255 | 313 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Private Equity Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Real Estate Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 40 | 38 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 40 | 38 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 1,817 | 1,470 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Proprietary Trading [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 156 | 77 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Effects of netting and allocation of collateral [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | (1,025) | (732) |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Assets [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 948 | 815 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 0 |
Assets, Fair Value Disclosure | 3,717 | 3,433 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | 0 | 0 |
Fair Value, Net Asset (Liability) | 3,717 | 3,433 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Commodity Derivative Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | 0 | 0 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | 0 | 0 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Proprietary Trading Liabilities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | 0 | 0 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | 0 | 0 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 3,717 | 3,433 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Cash Equivalents NDT [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Equity Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 1,314 | 1,381 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Fixed Income Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 979 | 846 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Corporate Debt Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | US Treasury and Government [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Debt Security, Government, Non-US [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | State and municipal debt [Domain] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Other Fixed Income [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 979 | 846 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Middle Market Lending [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 445 | 367 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Private Equity Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 398 | 329 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Real Estate Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 581 | 510 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 0 | 0 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Proprietary Trading [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 0 | 0 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Effects of netting and allocation of collateral [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 0 | 0 |
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Commodity Derivative Assets [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 0 | 0 |
Exelon Generation Co L L C [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Mark-to-market derivative liabilities (current liabilities) | 212 | 449 |
Derivative Liability, Noncurrent | 163 | 252 |
Derivative Instruments Not Designated as Hedging Instruments, Liability, at Fair Value | 2 | |
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value | 44 | |
Derivative Asset, Notional Amount | 864 | 1,432 |
Margin Deposit Liabilities | (94) | |
Margin Deposit Assets | 306 | |
Exelon Generation Co L L C [Member] | Cash and Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 183 | 283 |
Exelon Generation Co L L C [Member] | Restricted cash member [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 66 | 39 |
Exelon Generation Co L L C [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Net assets (liabilities) excluded from nuclear decommissioning trust fund investments | 176 | 130 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 896 | 581 |
Assets, Fair Value Disclosure | 15,071 | 14,703 |
Deferred Compensation Liability, Current and Noncurrent | (37) | (35) |
Total Liabilities | (375) | (733) |
Fair Value, Net Asset (Liability) | 14,696 | 13,970 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Commodity Derivative Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (338) | (698) |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (3,874) | (4,632) |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Proprietary Trading Liabilities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (148) | (94) |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | 3,684 | 4,028 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 13,038 | 12,825 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Cash Equivalents NDT [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 393 | 338 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Equity Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 6,162 | 5,890 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Fixed Income Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 4,804 | 5,078 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Corporate Debt Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 1,732 | 1,823 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | US Treasury and Government [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 1,929 | 2,180 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Debt Security, Government, Non-US [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 56 | 50 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | State and municipal debt [Domain] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 85 | 149 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Other Fixed Income [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 1,002 | 876 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Middle Market Lending [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 700 | 680 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Private Equity Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 398 | 329 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Real Estate Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 581 | 510 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 52 | 51 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 4 | 5 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 24 | 24 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 24 | 22 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 3,838 | 4,771 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Proprietary Trading [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 210 | 146 |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Effects of netting and allocation of collateral [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | (2,963) | (3,671) |
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Commodity Derivative Assets [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 1,085 | 1,246 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Collateral received from counterparties, net of collateral paid to counterparties | 93 | 57 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 896 | 581 |
Assets, Fair Value Disclosure | 5,993 | 5,820 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | (3) | (3) |
Fair Value, Net Asset (Liability) | 5,990 | 5,817 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (3) | (3) |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (773) | (642) |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Proprietary Trading Liabilities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | 770 | 639 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 5,213 | 5,251 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Cash Equivalents NDT [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 315 | 252 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Equity Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 3,121 | 2,918 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Fixed Income Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 1,777 | 2,081 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Corporate Debt Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | US Treasury and Government [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 1,777 | 2,081 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Debt Security, Government, Non-US [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | State and municipal debt [Domain] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Other Fixed Income [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Middle Market Lending [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Private Equity Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Real Estate Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 28 | 29 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 4 | 5 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 24 | 24 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 533 | 541 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Proprietary Trading [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Effects of netting and allocation of collateral [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | (677) | (582) |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Assets [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | (144) | (41) |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Collateral received from counterparties, net of collateral paid to counterparties | 324 | 224 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 0 |
Assets, Fair Value Disclosure | 3,899 | 4,092 |
Deferred Compensation Liability, Current and Noncurrent | (37) | (35) |
Total Liabilities | (206) | (490) |
Fair Value, Net Asset (Liability) | 3,693 | 3,602 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (169) | (455) |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (1,695) | (2,963) |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Proprietary Trading Liabilities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (59) | (73) |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | 1,585 | 2,581 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 3,594 | 3,598 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Cash Equivalents NDT [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 78 | 86 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Equity Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 1,727 | 1,591 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Fixed Income Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 1,789 | 1,921 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Corporate Debt Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 1,473 | 1,593 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | US Treasury and Government [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 152 | 99 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Debt Security, Government, Non-US [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 56 | 50 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | State and municipal debt [Domain] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 85 | 149 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Other Fixed Income [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 23 | 30 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Middle Market Lending [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Private Equity Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Real Estate Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 24 | 22 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 24 | 22 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 1,488 | 2,760 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Proprietary Trading [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 54 | 69 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Effects of netting and allocation of collateral [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | (1,261) | (2,357) |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Assets [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 281 | 472 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Collateral received from counterparties, net of collateral paid to counterparties | 304 | 76 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 0 |
Assets, Fair Value Disclosure | 1,462 | 1,358 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | (166) | (240) |
Fair Value, Net Asset (Liability) | 1,296 | 1,118 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (166) | (240) |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (1,406) | (1,027) |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Proprietary Trading Liabilities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | (89) | (21) |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | 1,329 | 808 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 514 | 543 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Cash Equivalents NDT [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Equity Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Fixed Income Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 259 | 230 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Corporate Debt Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 259 | 230 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | US Treasury and Government [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Debt Security, Government, Non-US [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | State and municipal debt [Domain] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Other Fixed Income [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Middle Market Lending [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 255 | 313 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Private Equity Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Real Estate Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 1,817 | 1,470 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Proprietary Trading [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 156 | 77 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Effects of netting and allocation of collateral [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | (1,025) | (732) |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Assets [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 948 | 815 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 0 |
Assets, Fair Value Disclosure | 3,717 | 3,433 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | 0 | 0 |
Fair Value, Net Asset (Liability) | 3,717 | 3,433 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Commodity Derivative Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Proprietary Trading Liabilities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilites [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Total mark-to-market derivative liabilities | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 3,717 | 3,433 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Cash Equivalents NDT [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Equity Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 1,314 | 1,381 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Fixed Income Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 979 | 846 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Corporate Debt Securities [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | US Treasury and Government [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Debt Security, Government, Non-US [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | State and municipal debt [Domain] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Other Fixed Income [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 979 | 846 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Middle Market Lending [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 445 | 367 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Private Equity Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 398 | 329 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Real Estate Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 581 | 510 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Proprietary Trading [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Effects of netting and allocation of collateral [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Commodity Derivative Assets [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative Asset | 0 | 0 |
Commonwealth Edison Co [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Mark-to-market derivative liabilities (current liabilities) | 27 | 26 |
Derivative Liability, Noncurrent | 253 | 223 |
Commonwealth Edison Co [Member] | Cash and Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 76 | 93 |
Commonwealth Edison Co [Member] | Restricted cash member [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 31 | 28 |
Commonwealth Edison Co [Member] | Other Assets [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 171 | 166 |
Commonwealth Edison Co [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 264 | 209 |
Assets, Fair Value Disclosure | 264 | 209 |
Total mark-to-market derivative liabilities | (280) | (249) |
Deferred Compensation Liability, Current and Noncurrent | (7) | (6) |
Total Liabilities | (287) | (255) |
Fair Value, Net Asset (Liability) | (23) | (46) |
Commonwealth Edison Co [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Commonwealth Edison Co [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Commonwealth Edison Co [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 264 | 209 |
Assets, Fair Value Disclosure | 264 | 209 |
Total mark-to-market derivative liabilities | 0 | 0 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | 0 | 0 |
Fair Value, Net Asset (Liability) | 264 | 209 |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 0 |
Assets, Fair Value Disclosure | 0 | 0 |
Total mark-to-market derivative liabilities | 0 | 0 |
Deferred Compensation Liability, Current and Noncurrent | (7) | (6) |
Total Liabilities | (7) | (6) |
Fair Value, Net Asset (Liability) | (7) | (6) |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 0 |
Assets, Fair Value Disclosure | 0 | 0 |
Total mark-to-market derivative liabilities | (280) | (249) |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | (280) | (249) |
Fair Value, Net Asset (Liability) | (280) | (249) |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
PECO Energy Co [Member] | Cash and Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 23 | 24 |
PECO Energy Co [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 207 | 111 |
Assets, Fair Value Disclosure | 226 | 128 |
Total mark-to-market derivative liabilities | 0 | 0 |
Deferred Compensation Liability, Current and Noncurrent | (8) | (10) |
Total Liabilities | (8) | (10) |
Fair Value, Net Asset (Liability) | 218 | 118 |
PECO Energy Co [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 19 | 17 |
PECO Energy Co [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 8 | 7 |
PECO Energy Co [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 11 | 10 |
PECO Energy Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 207 | 111 |
Assets, Fair Value Disclosure | 215 | 118 |
Total mark-to-market derivative liabilities | 0 | 0 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | 0 | 0 |
Fair Value, Net Asset (Liability) | 215 | 118 |
PECO Energy Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 8 | 7 |
PECO Energy Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 8 | 7 |
PECO Energy Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
PECO Energy Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 0 |
Assets, Fair Value Disclosure | 11 | 10 |
Total mark-to-market derivative liabilities | 0 | 0 |
Deferred Compensation Liability, Current and Noncurrent | (8) | (10) |
Total Liabilities | (8) | (10) |
Fair Value, Net Asset (Liability) | 3 | 0 |
PECO Energy Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 11 | 10 |
PECO Energy Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
PECO Energy Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 11 | 10 |
PECO Energy Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 0 |
Assets, Fair Value Disclosure | 0 | 0 |
Total mark-to-market derivative liabilities | 0 | 0 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | 0 | 0 |
Fair Value, Net Asset (Liability) | 0 | 0 |
PECO Energy Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
PECO Energy Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
PECO Energy Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Baltimore Gas and Electric Company [Member] | Cash and Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 8 | 7 |
Baltimore Gas and Electric Company [Member] | Restricted cash member [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 1 | 2 |
Baltimore Gas and Electric Company [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 122 | 4 |
Assets, Fair Value Disclosure | 129 | 10 |
Total mark-to-market derivative liabilities | 0 | 0 |
Deferred Compensation Liability, Current and Noncurrent | (5) | (5) |
Total Liabilities | (5) | (5) |
Fair Value, Net Asset (Liability) | 124 | 5 |
Baltimore Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 7 | 6 |
Baltimore Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 7 | 6 |
Baltimore Gas and Electric Company [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 122 | 4 |
Assets, Fair Value Disclosure | 129 | 10 |
Total mark-to-market derivative liabilities | 0 | 0 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | 0 | 0 |
Fair Value, Net Asset (Liability) | 129 | 10 |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 7 | 6 |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 7 | 6 |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 0 |
Assets, Fair Value Disclosure | 0 | 0 |
Total mark-to-market derivative liabilities | 0 | 0 |
Deferred Compensation Liability, Current and Noncurrent | (5) | (5) |
Total Liabilities | (5) | (5) |
Fair Value, Net Asset (Liability) | (5) | (5) |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 0 |
Assets, Fair Value Disclosure | 0 | 0 |
Total mark-to-market derivative liabilities | 0 | 0 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | 0 | 0 |
Fair Value, Net Asset (Liability) | 0 | 0 |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Pepco Holdings LLC [Member] | Cash and Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 45 | 39 |
Pepco Holdings LLC [Member] | Other Assets [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 15 | 19 |
Pepco Holdings LLC [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 107 | 147 |
Assets, Fair Value Disclosure | 240 | 277 |
Deferred Compensation Liability, Current and Noncurrent | (19) | (21) |
Total Liabilities | (19) | (21) |
Fair Value, Net Asset (Liability) | 221 | 256 |
Pepco Holdings LLC [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 133 | 130 |
Pepco Holdings LLC [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 43 | 42 |
Pepco Holdings LLC [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 13 | 13 |
Pepco Holdings LLC [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 13 | 15 |
Pepco Holdings LLC [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 64 | 60 |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 107 | 147 |
Assets, Fair Value Disclosure | 163 | 202 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | 0 | 0 |
Fair Value, Net Asset (Liability) | 163 | 202 |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 56 | 55 |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 43 | 42 |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 13 | 13 |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 0 |
Assets, Fair Value Disclosure | 37 | 37 |
Deferred Compensation Liability, Current and Noncurrent | (19) | (21) |
Total Liabilities | (19) | (21) |
Fair Value, Net Asset (Liability) | 18 | 16 |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 37 | 37 |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 13 | 15 |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 24 | 22 |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 0 |
Assets, Fair Value Disclosure | 40 | 38 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | 0 | 0 |
Fair Value, Net Asset (Liability) | 40 | 38 |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 40 | 38 |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 40 | 38 |
Potomac Electric Power Company [Member] | Cash and Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 18 | 15 |
Potomac Electric Power Company [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 34 | 38 |
Assets, Fair Value Disclosure | 144 | 143 |
Deferred Compensation Liability, Current and Noncurrent | (2) | (3) |
Total Liabilities | (2) | (3) |
Fair Value, Net Asset (Liability) | 142 | 140 |
Potomac Electric Power Company [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 110 | 105 |
Potomac Electric Power Company [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 43 | 41 |
Potomac Electric Power Company [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 3 | 5 |
Potomac Electric Power Company [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 64 | 59 |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 34 | 38 |
Assets, Fair Value Disclosure | 77 | 79 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | 0 | 0 |
Fair Value, Net Asset (Liability) | 77 | 79 |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 43 | 41 |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 43 | 41 |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 0 |
Assets, Fair Value Disclosure | 27 | 27 |
Deferred Compensation Liability, Current and Noncurrent | (2) | (3) |
Total Liabilities | (2) | (3) |
Fair Value, Net Asset (Liability) | 25 | 24 |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 27 | 27 |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 3 | 5 |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 24 | 22 |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 0 |
Assets, Fair Value Disclosure | 40 | 37 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | 0 | 0 |
Fair Value, Net Asset (Liability) | 40 | 37 |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 40 | 37 |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 40 | 37 |
Delmarva Power and Light Company [Member] | Cash and Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 11 | 8 |
Delmarva Power and Light Company [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 16 |
Assets, Fair Value Disclosure | 0 | 16 |
Deferred Compensation Liability, Current and Noncurrent | 0 | (1) |
Total Liabilities | 0 | (1) |
Fair Value, Net Asset (Liability) | 0 | 15 |
Delmarva Power and Light Company [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Delmarva Power and Light Company [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Delmarva Power and Light Company [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Delmarva Power and Light Company [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 16 |
Assets, Fair Value Disclosure | 0 | 16 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | 0 | 0 |
Fair Value, Net Asset (Liability) | 0 | 16 |
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 0 |
Assets, Fair Value Disclosure | 0 | 0 |
Deferred Compensation Liability, Current and Noncurrent | 0 | (1) |
Total Liabilities | 0 | (1) |
Fair Value, Net Asset (Liability) | 0 | (1) |
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 0 |
Assets, Fair Value Disclosure | 0 | 0 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | 0 | 0 |
Fair Value, Net Asset (Liability) | 0 | 0 |
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Atlantic City Electric Company [Member] | Cash and Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 13 | 7 |
Atlantic City Electric Company [Member] | Other Assets [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 15 | 19 |
Atlantic City Electric Company [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 18 | 23 |
Assets, Fair Value Disclosure | 18 | 23 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | 0 | 0 |
Fair Value, Net Asset (Liability) | 18 | 23 |
Atlantic City Electric Company [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Atlantic City Electric Company [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Atlantic City Electric Company [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Atlantic City Electric Company [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 18 | 23 |
Assets, Fair Value Disclosure | 18 | 23 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | 0 | 0 |
Fair Value, Net Asset (Liability) | 18 | 23 |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 0 |
Assets, Fair Value Disclosure | 0 | 0 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | 0 | 0 |
Fair Value, Net Asset (Liability) | 0 | 0 |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Cash equivalents | 0 | 0 |
Assets, Fair Value Disclosure | 0 | 0 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 |
Total Liabilities | 0 | 0 |
Fair Value, Net Asset (Liability) | 0 | 0 |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Investments, Fair Value Disclosure | 0 | 0 |
Maturity Less than 30 Days [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative, Collateral, Right to Reclaim Cash | 85 | 50 |
Maturity Less than 30 Days [Member] | Exelon Generation Co L L C [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | ||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | ||
Derivative, Collateral, Right to Reclaim Cash | $ 85 | $ 50 |
Fair Value of Financial Asset_6
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 | 9 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2019 | Sep. 30, 2018 | |
Fair Value, Inputs, Level 3 [Member] | ||||
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Line Items] | ||||
Beginning Balance | $ 1,179 | $ 1,106 | $ 907 | $ 966 |
Total realized / unrealized gains (losses) | ||||
Included in net income | (171) | (259) | (125) | (186) |
Included in noncurrent payables to affiliates | 0 | 0 | 0 | |
Included in regulatory assets | 4 | (11) | 1 | (3) |
Change in collateral | 41 | (44) | 227 | 14 |
Purchases, sales, issuances and settlements | ||||
Purchases | 53 | 96 | 163 | 215 |
Sales | (22) | (23) | (3) | |
Settlements | (18) | (29) | (88) | (103) |
Transfers into Level 3 | 1 | 3 | 5 | (21) |
Transfers out of Level 3 | (11) | (6) | (11) | (23) |
Ending Balance | 1,056 | 856 | 1,056 | 856 |
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss) | (18) | (105) | 173 | 154 |
Fair Value, Inputs, Level 3 [Member] | Consolidation, Eliminations [Member] | ||||
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Line Items] | ||||
Beginning Balance | 0 | 0 | 0 | 0 |
Total realized / unrealized gains (losses) | ||||
Included in net income | 0 | 0 | 0 | 0 |
Included in noncurrent payables to affiliates | (11) | 4 | (32) | |
Included in regulatory assets | 11 | (4) | 32 | 0 |
Change in collateral | 0 | 0 | 0 | |
Purchases, sales, issuances and settlements | ||||
Purchases | 0 | 0 | 0 | 0 |
Sales | 0 | 0 | 0 | |
Settlements | 0 | 0 | 0 | 0 |
Transfers into Level 3 | 0 | 0 | 0 | 0 |
Transfers out of Level 3 | 0 | 0 | 0 | 0 |
Ending Balance | 0 | 0 | 0 | 0 |
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss) | 0 | 0 | 0 | 0 |
Exelon Generation Co L L C [Member] | ||||
Footnotes To Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Abstract] | ||||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings | 153 | 155 | 298 | 347 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | ||||
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Line Items] | ||||
Beginning Balance | 1,412 | 1,322 | 1,118 | 1,200 |
Total realized / unrealized gains (losses) | ||||
Included in net income | (171) | (260) | (127) | (189) |
Included in noncurrent payables to affiliates | 11 | (4) | 32 | |
Included in regulatory assets | 0 | 0 | 0 | 0 |
Change in collateral | 41 | (44) | 227 | 14 |
Purchases, sales, issuances and settlements | ||||
Purchases | 53 | 96 | 163 | 215 |
Sales | (22) | (23) | (3) | |
Settlements | (18) | (29) | (88) | (115) |
Transfers into Level 3 | 1 | 3 | 5 | (21) |
Transfers out of Level 3 | (11) | (6) | (11) | (23) |
Ending Balance | 1,296 | 1,078 | 1,296 | 1,078 |
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss) | (18) | (105) | 171 | 154 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | ||||
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Line Items] | ||||
Beginning Balance | 539 | 585 | 543 | 648 |
Total realized / unrealized gains (losses) | ||||
Included in net income | 2 | (1) | 5 | (1) |
Included in noncurrent payables to affiliates | 11 | (4) | 32 | |
Included in regulatory assets | 0 | 0 | 0 | 0 |
Change in collateral | 0 | 0 | 0 | 0 |
Purchases, sales, issuances and settlements | ||||
Purchases | 1 | 15 | 43 | 34 |
Sales | (21) | (21) | 0 | |
Settlements | (18) | (29) | (88) | (115) |
Transfers into Level 3 | 0 | 0 | 0 | 0 |
Transfers out of Level 3 | 0 | 0 | 0 | 0 |
Ending Balance | 514 | 566 | 514 | 566 |
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss) | 2 | (1) | 5 | (5) |
Exelon Generation Co L L C [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 | 873 | 737 | 575 | 552 |
Total realized / unrealized gains (losses) | ||||
Included in net income | (173) | (259) | (132) | (188) |
Included in noncurrent payables to affiliates | 0 | 0 | 0 | |
Included in regulatory assets | 0 | 0 | 0 | |
Change in collateral | 41 | (44) | 227 | 14 |
Purchases, sales, issuances and settlements | ||||
Purchases | 52 | 81 | 120 | 181 |
Sales | (1) | (2) | (3) | |
Settlements | 0 | 0 | 0 | 0 |
Transfers into Level 3 | 1 | 3 | 5 | (21) |
Transfers out of Level 3 | (11) | (6) | (11) | (23) |
Ending Balance | 782 | 512 | 782 | 512 |
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss) | (20) | (104) | 166 | 159 |
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) | 4 | 3 | 17 | 12 |
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 | (273) | (252) | (249) | (256) |
Total realized / unrealized gains (losses) | ||||
Included in net income | 0 | 0 | 0 | 0 |
Included in noncurrent payables to affiliates | 0 | 0 | 0 | |
Included in regulatory assets | (7) | (7) | (31) | (3) |
Change in collateral | 0 | 0 | 0 | 0 |
Purchases, sales, issuances and settlements | ||||
Purchases | 0 | 0 | 0 | 0 |
Sales | 0 | 0 | 0 | |
Settlements | 0 | 0 | 0 | 0 |
Transfers into Level 3 | 0 | 0 | 0 | 0 |
Transfers out of Level 3 | 0 | 0 | 0 | 0 |
Ending Balance | (280) | (259) | (280) | (259) |
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss) | 0 | 0 | 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) | (7) | 4 | (31) | (9) |
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 | 40 | 36 | 38 | 22 |
Total realized / unrealized gains (losses) | ||||
Included in net income | 0 | 1 | 2 | 3 |
Included in noncurrent payables to affiliates | 0 | 0 | 0 | |
Included in regulatory assets | 0 | 0 | 0 | 0 |
Change in collateral | 0 | 0 | 0 | 0 |
Purchases, sales, issuances and settlements | ||||
Purchases | 0 | 0 | 0 | 0 |
Sales | 0 | 0 | 0 | |
Settlements | 0 | 0 | 0 | 12 |
Transfers into Level 3 | 0 | 0 | 0 | 0 |
Transfers out of Level 3 | 0 | 0 | 0 | 0 |
Ending Balance | 40 | 37 | 40 | 37 |
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss) | 0 | 0 | 2 | 0 |
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 | 40 | 36 | 38 | 22 |
Total realized / unrealized gains (losses) | ||||
Included in net income | 0 | 1 | 2 | 3 |
Included in noncurrent payables to affiliates | 0 | 0 | 0 | 0 |
Included in regulatory assets | 0 | 0 | 0 | 0 |
Change in collateral | 0 | 0 | 0 | 0 |
Purchases, sales, issuances and settlements | ||||
Purchases | 0 | 0 | 0 | 0 |
Sales | 0 | 0 | 0 | 0 |
Settlements | 0 | 0 | 0 | 12 |
Transfers into Level 3 | 0 | 0 | 0 | 0 |
Transfers out of Level 3 | 0 | 0 | 0 | |
Ending Balance | 40 | 37 | 40 | 37 |
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss) | $ 0 | $ 0 | $ 2 | $ 0 |
Fair Value of Financial Asset_7
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 | 9 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2019 | Sep. 30, 2018 | |
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 | $ 171 | $ 259 | $ 125 | $ 186 |
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss) | (18) | (105) | 173 | 154 |
Operating Revenue [Member] | ||||
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 | (25) | (176) | 122 | (32) |
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss) | 99 | (64) | 368 | 174 |
Purchased Power And Fuel [Member] | ||||
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 | (148) | (83) | (254) | (156) |
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss) | (119) | (40) | (202) | (15) |
Operating and Maintenance [Member] | ||||
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 | 0 | 1 | 0 | 3 |
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss) | 0 | 0 | 2 | 0 |
Other, net [Member] | ||||
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 | 2 | (1) | 5 | (1) |
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss) | 2 | (1) | 5 | (5) |
Exelon Generation Co L L C [Member] | ||||
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 | 171 | 260 | 127 | 189 |
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss) | (18) | (105) | 171 | 154 |
Exelon Generation Co L L C [Member] | Operating Revenue [Member] | ||||
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 | (25) | (176) | 122 | (32) |
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss) | 99 | (64) | 368 | 174 |
Exelon Generation Co L L C [Member] | Purchased Power And Fuel [Member] | ||||
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 | (148) | (83) | (254) | (156) |
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss) | (119) | (40) | (202) | (15) |
Exelon Generation Co L L C [Member] | Other, net [Member] | ||||
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 | 2 | (1) | 5 | (1) |
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss) | 2 | (1) | 5 | (5) |
Pepco Holdings LLC [Member] | Operating and Maintenance [Member] | ||||
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 | 0 | 1 | 0 | 3 |
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss) | 0 | 0 | 2 | 0 |
Potomac Electric Power Company [Member] | Operating and Maintenance [Member] | ||||
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 | 0 | 1 | 0 | 3 |
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss) | $ 0 | $ 0 | $ 2 | $ 0 |
Fair Value of Financial Asset_8
Fair Value of Financial Assets and Liabilities - Fair Value Inputs Assets Quantitative Information (Details) | 9 Months Ended | 12 Months Ended |
Sep. 30, 2019USD ($) | Dec. 31, 2018USD ($) | |
Fair Value, Inputs, Level 3 [Member] | ||
Derivatives Fair Value Footnotes [Abstract] | ||
Cash Collateral Posted | $ 304,000,000 | $ 76,000,000 |
Fair Value, Inputs, Level 3 [Member] | Economic Hedges [Member] | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Asset, Fair Value, Amount Not Offset Against Collateral | 411,000,000 | 443,000,000 |
Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Liability, Fair Value, Amount Not Offset Against Collateral | $ (280,000,000) | $ (249,000,000) |
Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Minimum [Member] | ||
Fair Value Measurement Inputs and Valuation Techniques [Abstract] | ||
Forward power price assets | 11 | 12 |
Forward gas price assets | 1.36 | 0.78 |
Forward heat rate | 900.00% | 1000.00% |
Derivative Asset (Liability) Net, Measurement Input | 0.04 | 0.04 |
Fair Value Inputs Renewable Factor | 87.00% | 86.00% |
Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Maximum [Member] | ||
Fair Value Measurement Inputs and Valuation Techniques [Abstract] | ||
Forward power price assets | 167 | 174 |
Forward gas price assets | 10.82 | 12.38 |
Forward heat rate | 1000.00% | 1100.00% |
Derivative Asset (Liability) Net, Measurement Input | 0.07 | 0.08 |
Fair Value Inputs Renewable Factor | 119.00% | 120.00% |
Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Option Model Valuation Technique [Member] | Minimum [Member] | ||
Fair Value Measurement Inputs and Valuation Techniques [Abstract] | ||
Derivative Asset (Liability) Net, Measurement Input | 0.09 | 0.10 |
Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Option Model Valuation Technique [Member] | Maximum [Member] | ||
Fair Value Measurement Inputs and Valuation Techniques [Abstract] | ||
Derivative Asset (Liability) Net, Measurement Input | 2 | 2.77 |
Fair Value, Inputs, Level 3 [Member] | Proprietary Trading [Member] | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Asset, Fair Value, Amount Not Offset Against Collateral | $ 67,000,000 | $ 56,000,000 |
Fair Value, Inputs, Level 3 [Member] | Proprietary Trading [Member] | Discounted Cash Flow [Member] | Minimum [Member] | ||
Fair Value Measurement Inputs and Valuation Techniques [Abstract] | ||
Forward power price assets | 17 | 14 |
Fair Value, Inputs, Level 3 [Member] | Proprietary Trading [Member] | Discounted Cash Flow [Member] | Maximum [Member] | ||
Fair Value Measurement Inputs and Valuation Techniques [Abstract] | ||
Forward power price assets | 167 | 174 |
Exelon Generation Co L L C [Member] | ||
Derivatives Fair Value Footnotes [Abstract] | ||
Cash Collateral Posted | $ 18,000,000 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | ||
Derivatives Fair Value Footnotes [Abstract] | ||
Cash Collateral Posted | 304,000,000 | $ 76,000,000 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Economic Hedges [Member] | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Asset, Fair Value, Amount Not Offset Against Collateral | $ 411,000,000 | $ 443,000,000 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Minimum [Member] | ||
Fair Value Measurement Inputs and Valuation Techniques [Abstract] | ||
Forward power price assets | 11 | 12 |
Forward gas price assets | 1.36 | 0.78 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Maximum [Member] | ||
Fair Value Measurement Inputs and Valuation Techniques [Abstract] | ||
Forward power price assets | 167 | 174 |
Forward gas price assets | 10.82 | 12.38 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Option Model Valuation Technique [Member] | Minimum [Member] | ||
Fair Value Measurement Inputs and Valuation Techniques [Abstract] | ||
Derivative Asset (Liability) Net, Measurement Input | 0.09 | 0.10 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Option Model Valuation Technique [Member] | Maximum [Member] | ||
Fair Value Measurement Inputs and Valuation Techniques [Abstract] | ||
Derivative Asset (Liability) Net, Measurement Input | 2 | 2.77 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Proprietary Trading [Member] | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Asset, Fair Value, Amount Not Offset Against Collateral | $ 67,000,000 | $ 56,000,000 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Proprietary Trading [Member] | Discounted Cash Flow [Member] | Minimum [Member] | ||
Fair Value Measurement Inputs and Valuation Techniques [Abstract] | ||
Forward power price assets | 17 | 14 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Proprietary Trading [Member] | Discounted Cash Flow [Member] | Maximum [Member] | ||
Fair Value Measurement Inputs and Valuation Techniques [Abstract] | ||
Forward power price assets | 167 | 174 |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | ||
Derivatives, Fair Value [Line Items] | ||
Derivative Liability, Fair Value, Amount Not Offset Against Collateral | $ (280,000,000) | $ (249,000,000) |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Minimum [Member] | ||
Fair Value Measurement Inputs and Valuation Techniques [Abstract] | ||
Forward heat rate | 900.00% | 1000.00% |
Derivative Asset (Liability) Net, Measurement Input | 0.04 | 0.04 |
Fair Value Inputs Renewable Factor | 87.00% | 86.00% |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Maximum [Member] | ||
Fair Value Measurement Inputs and Valuation Techniques [Abstract] | ||
Forward heat rate | 1000.00% | 1100.00% |
Derivative Asset (Liability) Net, Measurement Input | 0.07 | 0.08 |
Fair Value Inputs Renewable Factor | 119.00% | 120.00% |
Derivative Financial Instrume_3
Derivative Financial Instruments - Summary of Derivative Fair Value Balances (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Dec. 31, 2018 |
Derivative [Line Items] | ||
Mark-to-market derivatives assets | $ 601 | $ 804 |
Derivative Asset, Noncurrent | 487 | 452 |
Derivative Liability, Current | (239) | (475) |
Derivative Liability, Noncurrent | (416) | (479) |
Commodity Contract [Member] | ||
Derivative [Line Items] | ||
Mark-to-market derivatives assets | 602 | 801 |
Derivative Asset, Noncurrent | 483 | 445 |
Total mark-to-market derivative assets | 1,085 | 1,246 |
Derivative Liability, Current | (224) | (473) |
Derivative Liability, Noncurrent | (394) | (474) |
Total mark-to-market derivative liabilities | (618) | (947) |
Total mark-to-market derivative net assets (liabilities) | 467 | 299 |
Exelon Generation Co L L C [Member] | ||
Derivative [Line Items] | ||
Mark-to-market derivatives assets | 602 | 804 |
Derivative Asset, Noncurrent | 483 | 452 |
Derivative Liability, Current | (212) | (449) |
Derivative Liability, Noncurrent | (163) | (252) |
Exelon Generation Co L L C [Member] | Commodity Contract [Member] | ||
Derivative [Line Items] | ||
Mark-to-market derivatives assets | 602 | 801 |
Derivative Asset, Noncurrent | 483 | 445 |
Total mark-to-market derivative assets | 1,085 | 1,246 |
Derivative Liability, Current | (197) | (447) |
Derivative Liability, Noncurrent | (141) | (251) |
Total mark-to-market derivative liabilities | (338) | (698) |
Total mark-to-market derivative net assets (liabilities) | 747 | 548 |
Commonwealth Edison Co [Member] | ||
Derivative [Line Items] | ||
Derivative Liability, Current | (27) | (26) |
Derivative Liability, Noncurrent | (253) | (223) |
Collateral [Member] | Exelon Generation Co L L C [Member] | Commodity Contract [Member] | ||
Derivative [Line Items] | ||
Mark-to-market derivatives assets | 212 | 121 |
Derivative Asset, Noncurrent | 104 | 51 |
Total mark-to-market derivative assets | 316 | 172 |
Derivative Liability, Current | 249 | 125 |
Derivative Liability, Noncurrent | 156 | 60 |
Total mark-to-market derivative liabilities | 405 | 185 |
Total mark-to-market derivative net assets (liabilities) | 721 | 357 |
Netting [Member] | Exelon Generation Co L L C [Member] | Commodity Contract [Member] | ||
Derivative [Line Items] | ||
Mark-to-market derivatives assets | (2,205) | (2,930) |
Derivative Asset, Noncurrent | (1,074) | (913) |
Total mark-to-market derivative assets | (3,279) | (3,843) |
Derivative Liability, Current | 2,205 | 2,931 |
Derivative Liability, Noncurrent | 1,074 | 912 |
Total mark-to-market derivative liabilities | 3,279 | 3,843 |
Total mark-to-market derivative net assets (liabilities) | 0 | 0 |
Not Designated as Hedging Instrument, Economic Hedge [Member] | Exelon Generation Co L L C [Member] | Commodity Contract [Member] | ||
Derivative [Line Items] | ||
Mark-to-market derivatives assets | 2,452 | 3,505 |
Derivative Asset, Noncurrent | 1,386 | 1,266 |
Total mark-to-market derivative assets | 3,838 | 4,771 |
Derivative Liability, Current | (2,550) | (3,429) |
Derivative Liability, Noncurrent | (1,324) | (1,203) |
Total mark-to-market derivative liabilities | (3,874) | (4,632) |
Total mark-to-market derivative net assets (liabilities) | (36) | 139 |
Not Designated as Hedging Instrument, Economic Hedge [Member] | Commonwealth Edison Co [Member] | Commodity Contract [Member] | ||
Derivative [Line Items] | ||
Mark-to-market derivatives assets | 0 | 0 |
Derivative Asset, Noncurrent | 0 | 0 |
Total mark-to-market derivative assets | 0 | 0 |
Derivative Liability, Current | (27) | (26) |
Derivative Liability, Noncurrent | (253) | (223) |
Total mark-to-market derivative liabilities | (280) | (249) |
Total mark-to-market derivative net assets (liabilities) | (280) | (249) |
Not Designated as Hedging Instrument [Member] | Exelon Generation Co L L C [Member] | Commodity Contract [Member] | ||
Derivative [Line Items] | ||
Mark-to-market derivatives assets | 143 | 105 |
Derivative Asset, Noncurrent | 67 | 41 |
Total mark-to-market derivative assets | 210 | 146 |
Derivative Liability, Current | (101) | (74) |
Derivative Liability, Noncurrent | (47) | (20) |
Total mark-to-market derivative liabilities | (148) | (94) |
Total mark-to-market derivative net assets (liabilities) | 62 | 52 |
Designated as Hedging Instrument [Member] | Exelon Generation Co L L C [Member] | Other Current Assets [Member] | ||
Derivative [Line Items] | ||
Derivative Liability, Fair Value, Amount Offset Against Collateral | $ 306 | $ (94) |
Derivative Financial Instrume_4
Derivative Financial Instruments - Summary of Economic Hedges (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2019 | Sep. 30, 2018 | |
Derivative [Line Items] | ||||
Unrealized Gain (Loss) on Derivatives | $ (96) | $ (67) | ||
Exelon Generation Co L L C [Member] | ||||
Derivative [Line Items] | ||||
Unrealized Gain (Loss) on Derivatives | (102) | (73) | ||
Not Designated as Hedging Instrument, Economic Hedge [Member] | Commodity Contract [Member] | Exelon Generation Co L L C [Member] | ||||
Derivative [Line Items] | ||||
Unrealized Gain (Loss) on Derivatives | $ 31 | $ 74 | (62) | (103) |
Not Designated as Hedging Instrument, Economic Hedge [Member] | Commodity Contract [Member] | Operating Revenue [Member] | Exelon Generation Co L L C [Member] | ||||
Derivative [Line Items] | ||||
Unrealized Gain (Loss) on Derivatives | 76 | 8 | 65 | (99) |
Not Designated as Hedging Instrument, Economic Hedge [Member] | Commodity Contract [Member] | Purchased Power And Fuel [Member] | Exelon Generation Co L L C [Member] | ||||
Derivative [Line Items] | ||||
Unrealized Gain (Loss) on Derivatives | $ (45) | $ 66 | $ (127) | $ (4) |
Derivative Financial Instrume_5
Derivative Financial Instruments - Summary of Credit Risk Exposure (Details) - Exelon Generation Co L L C [Member] $ in Millions | Sep. 30, 2019USD ($) |
Derivative [Line Items] | |
Cash Collateral Posted | $ 18 |
Financial institutions | 1 |
Investor-owned utilities, marketers and power producers | 875 |
Energy Cooperatives And Municipalities | 255 |
Other | 35 |
Letters Of Credit Posted | 55 |
Total Exposure Before Credit Collateral [Member] | |
Derivative [Line Items] | |
Investment grade | 693 |
Non-investment grade | 74 |
No external ratings - internally rated - investment grade | 297 |
No external ratings - internally rated - non-investment grade | 175 |
Total | 1,239 |
Credit Collateral [Member] | |
Derivative [Line Items] | |
Investment grade | 10 |
Non-investment grade | 38 |
No external ratings - internally rated - investment grade | 1 |
No external ratings - internally rated - non-investment grade | 24 |
Total | 73 |
Net Exposure [Member] | |
Derivative [Line Items] | |
Investment grade | 683 |
Non-investment grade | 36 |
No external ratings - internally rated - investment grade | 296 |
No external ratings - internally rated - non-investment grade | 151 |
Total | 1,166 |
Number Of Counterparties Greater Than Ten Percent Of Net Exposure [Member] | |
Derivative [Line Items] | |
Investment grade | 0 |
Non-investment grade | |
No external ratings - internally rated - investment grade | |
No external ratings - internally rated - non-investment grade | |
Total | 0 |
Net Exposure Of Counterparties Greater Than Ten Percent Of Net Exposure [Member] | |
Derivative [Line Items] | |
Investment grade | 0 |
Non-investment grade | |
No external ratings - internally rated - investment grade | |
No external ratings - internally rated - non-investment grade | |
Total | $ 0 |
Derivative Financial Instrume_6
Derivative Financial Instruments - Summary of Credit Risk Related Contingent Features (Details) - Exelon Generation Co L L C [Member] - USD ($) $ in Millions | Sep. 30, 2019 | Dec. 31, 2018 |
Derivative [Line Items] | ||
Aggregate fair value of derivatives with credit-risk-related contingent features | $ (1,249) | $ (1,723) |
Offsetting fair value of in-the-money contracts under master netting agreements | 947 | 1,105 |
Net liability position after contractual right of offset | $ (302) | $ (618) |
Derivative Financial Instrume_7
Derivative Financial Instruments - Narrative (Details) MWh in Millions, $ in Millions | 1 Months Ended | 9 Months Ended | |
Jun. 30, 2012MWh | Sep. 30, 2019USD ($) | Dec. 31, 2018USD ($) | |
Derivative [Line Items] | |||
Incremental Collateral For Loss Of Investment Grade Credit Rating | $ 1,481 | $ 2,104 | |
Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Incremental Collateral For Loss Of Investment Grade Credit Rating | 1,481 | 2,104 | |
Commonwealth Edison Co [Member] | |||
Derivative [Line Items] | |||
Long-term Purchase Commitment, Minimum Energy Volume Required | MWh | 1.3 | ||
Delmarva Power and Light Company [Member] | |||
Derivative [Line Items] | |||
Incremental Collateral For Loss Of Investment Grade Credit Rating | 11 | ||
Baltimore Gas and Electric Company [Member] | |||
Derivative [Line Items] | |||
Incremental Collateral For Loss Of Investment Grade Credit Rating | 26 | ||
PECO Energy Co [Member] | |||
Derivative [Line Items] | |||
Incremental Collateral For Loss Of Investment Grade Credit Rating | $ 28 | ||
Minimum [Member] | Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Expected Generation Hedged In Next Twelve Months | 96.00% | ||
Expected Generation Hedged In Year Two | 84.00% | ||
Expected generation Hedged In Year Three | 54.00% | ||
Maximum [Member] | Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Expected Generation Hedged In Next Twelve Months | 99.00% | ||
Expected Generation Hedged In Year Two | 87.00% | ||
Expected generation Hedged In Year Three | 57.00% | ||
Commonwealth Edison Co Affiliate [Member] | Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Net receivable from electric utility | $ 68 | ||
PECO Energy Co Affiliate [Member] | Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Net receivable from affiliated electric and gas utility | 30 | ||
Baltimore Gas And Electric Company Affiliate [Member] | Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Net receivable from affiliated electric and gas utility | 32 | ||
Potomac Electric Power Company [Member] | Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Net receivable from electric utility | 39 | ||
Delmarva Power and Light Company [Member] | Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Net receivable from electric utility | 15 | ||
Atlantic City Electric Company [Member] | Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Net receivable from electric utility | 8 | ||
Not Designated as Hedging Instrument, Economic Hedge [Member] | Interest Rate Swap [Member] | |||
Derivative [Line Items] | |||
Derivative, Notional Amount | 1,371 | 1,420 | |
Not Designated as Hedging Instrument, Economic Hedge [Member] | Interest Rate Swap [Member] | Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Derivative, Notional Amount | 571 | 620 | |
Not Designated as Hedging Instrument, Economic Hedge [Member] | Foreign Exchange Contract [Member] | Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Derivative, Notional Amount | $ 257 | $ 268 |
Derivative Financial Instrume_8
Derivative Financial Instruments Derivative Financial Instruments - Summary of Cash Collateral and Letters of Credit (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Dec. 31, 2018 |
Derivative Instruments, Gain (Loss) [Line Items] | ||
Derivative, Collateral, Right to Reclaim Cash | $ 787 | $ 418 |
Derivative, Collateral, Right to Reclaim Securities | 273 | 367 |
Derivative, Collateral, Obligation to Return Cash | 96 | 47 |
Derivative, Collateral, Obligation to Return Securities | 58 | 44 |
Incremental Collateral For Loss Of Investment Grade Credit Rating | 1,481 | 2,104 |
Exelon Generation Co L L C [Member] | ||
Derivative Instruments, Gain (Loss) [Line Items] | ||
Derivative, Collateral, Right to Reclaim Cash | 787 | 418 |
Derivative, Collateral, Right to Reclaim Securities | 273 | 367 |
Derivative, Collateral, Obligation to Return Cash | 96 | 47 |
Derivative, Collateral, Obligation to Return Securities | 58 | 44 |
Incremental Collateral For Loss Of Investment Grade Credit Rating | $ 1,481 | $ 2,104 |
Debt and Credit Agreements - Na
Debt and Credit Agreements - Narrative (Details) $ in Millions | 9 Months Ended |
Sep. 30, 2019USD ($) | |
Corporate, Non-Segment [Member] | |
Debt Instrument [Line Items] | |
Short-term Bank Loans and Notes Payable | $ 500 |
Debt Instrument, Interest Rate Terms | LIBOR plus 0.95% |
Exelon Generation Co L L C [Member] | Line of Credit [Member] | |
Debt Instrument [Line Items] | |
Line of Credit Facility, Maximum Borrowing Capacity | $ 100 |
DOE Project Financing, 2.82% January 5, 2037 [Member] | Non Recourse Debt [Member] | |
Debt Instrument [Line Items] | |
Long-term Line of Credit | 646 |
Non-Recourse Debt | 495 |
DOE Project Financing, 2.82% January 5, 2037 [Member] | Exelon Generation Co L L C [Member] | Non Recourse Debt [Member] | |
Debt Instrument [Line Items] | |
Long-term Line of Credit | 646 |
Non-Recourse Debt | 495 |
ExGenRenewablesIVNov2024 [Member] | Non Recourse Debt [Member] | |
Debt Instrument [Line Items] | |
Long-term Line of Credit | 850 |
Non-Recourse Debt | 796 |
ExGenRenewablesIVNov2024 [Member] | Exelon Generation Co L L C [Member] | Non Recourse Debt [Member] | |
Debt Instrument [Line Items] | |
Long-term Line of Credit | 850 |
Non-Recourse Debt | $ 796 |
Debt and Credit Agreements - Co
Debt and Credit Agreements - Commercial Paper Borrowings (Details) - Commercial Paper [Member] - USD ($) $ in Millions | Sep. 30, 2019 | Dec. 31, 2018 |
Short-term Debt [Line Items] | ||
Outstanding Commercial Paper | $ 519 | $ 89 |
Average Interest Rate on Commercial Paper Borrowings | 2.50% | 2.15% |
Exelon Generation Co L L C [Member] | ||
Short-term Debt [Line Items] | ||
Outstanding Commercial Paper | $ 0 | $ 0 |
Commonwealth Edison Co [Member] | ||
Short-term Debt [Line Items] | ||
Outstanding Commercial Paper | $ 387 | $ 0 |
Average Interest Rate on Commercial Paper Borrowings | 2.51% | 2.14% |
PECO Energy Co [Member] | ||
Short-term Debt [Line Items] | ||
Outstanding Commercial Paper | $ 0 | $ 0 |
Baltimore Gas and Electric Company [Member] | ||
Short-term Debt [Line Items] | ||
Outstanding Commercial Paper | $ 0 | $ 35 |
Average Interest Rate on Commercial Paper Borrowings | 2.49% | 2.18% |
Pepco Holdings LLC [Member] | ||
Short-term Debt [Line Items] | ||
Outstanding Commercial Paper | $ 132 | $ 54 |
Average Interest Rate on Commercial Paper Borrowings | 2.52% | 2.15% |
Potomac Electric Power Company [Member] | ||
Short-term Debt [Line Items] | ||
Outstanding Commercial Paper | $ 12 | $ 40 |
Average Interest Rate on Commercial Paper Borrowings | 2.61% | 2.24% |
Delmarva Power and Light Company [Member] | ||
Short-term Debt [Line Items] | ||
Outstanding Commercial Paper | $ 57 | $ 0 |
Average Interest Rate on Commercial Paper Borrowings | 2.42% | 2.07% |
Atlantic City Electric Company [Member] | ||
Short-term Debt [Line Items] | ||
Outstanding Commercial Paper | $ 63 | $ 14 |
Average Interest Rate on Commercial Paper Borrowings | 2.57% | 2.21% |
Debt and Credit Agreements - Is
Debt and Credit Agreements - Issuance of Long-Term Debt (Details) $ in Millions | Sep. 30, 2019USD ($) |
Exelon Generation Co L L C [Member] | EEPF395Aug2020 [Member] | Notes Payable, Other Payables [Member] | |
Debt Instrument [Line Items] | |
Interest Rate | 3.95% |
Debt Instrument, Face Amount | $ 4 |
Exelon Generation Co L L C [Member] | EEPF346May2020 [Member] | Notes Payable, Other Payables [Member] | |
Debt Instrument [Line Items] | |
Interest Rate | 3.46% |
Debt Instrument, Face Amount | $ 39 |
Commonwealth Edison Co [Member] | FMB400Mar2049 [Member] | First Mortgage Bonds [Member] | |
Debt Instrument [Line Items] | |
Interest Rate | 4.00% |
Debt Instrument, Face Amount | $ 400 |
PECO Energy Co [Member] | FRMB300Sep2049 [Member] | First Mortgage Bonds [Member] | |
Debt Instrument [Line Items] | |
Interest Rate | 3.00% |
Debt Instrument, Face Amount | $ 325 |
Baltimore Gas and Electric Company [Member] | SN320Sep2049 [Member] | Senior Notes [Member] | |
Debt Instrument [Line Items] | |
Interest Rate | 3.20% |
Debt Instrument, Face Amount | $ 400 |
Potomac Electric Power Company [Member] | FMB345Jun2029 [Member] | First Mortgage Bonds [Member] | |
Debt Instrument [Line Items] | |
Interest Rate | 3.45% |
Debt Instrument, Face Amount | $ 150 |
Potomac Electric Power Company [Member] | Medco170Sep2022 [Member] | Tax-exempt Money Market Funds [Member] | |
Debt Instrument [Line Items] | |
Interest Rate | 1.70% |
Debt Instrument, Face Amount | $ 110 |
Atlantic City Electric Company [Member] | FMB350May2029 [Member] | First Mortgage Bonds [Member] | |
Debt Instrument [Line Items] | |
Interest Rate | 3.50% |
Debt Instrument, Face Amount | $ 100 |
Atlantic City Electric Company [Member] | FMB414May2049 [Member] | First Mortgage Bonds [Member] | |
Debt Instrument [Line Items] | |
Interest Rate | 4.14% |
Debt Instrument, Face Amount | $ 50 |
Income Taxes - Narrative (Detai
Income Taxes - Narrative (Details) - USD ($) $ in Millions | Jun. 05, 2019 | Sep. 30, 2019 | Mar. 31, 2019 | Sep. 30, 2018 | Sep. 30, 2019 | Sep. 30, 2018 |
Income Tax Additional Narrative Information [Line Items] | ||||||
Unrecognized Tax Benefits, Period Increase (Decrease) | $ (33) | |||||
Effective income tax rate | 15.60% | 14.50% | 20.70% | 11.60% | ||
Exelon Generation Co L L C [Member] | ||||||
Income Tax Additional Narrative Information [Line Items] | ||||||
Effective income tax rate | 17.40% | 20.10% | 28.60% | 13.80% | ||
Commonwealth Edison Co [Member] | ||||||
Income Tax Additional Narrative Information [Line Items] | ||||||
Unrecognized Tax Benefits, Period Increase (Decrease) | $ (2) | |||||
Effective income tax rate | 18.40% | 21.20% | 19.30% | 21.10% | ||
PECO Energy Co [Member] | ||||||
Income Tax Additional Narrative Information [Line Items] | ||||||
Effective income tax rate | 9.10% | (1.60%) | 11.10% | (1.50%) | ||
Baltimore Gas and Electric Company [Member] | ||||||
Income Tax Additional Narrative Information [Line Items] | ||||||
Effective income tax rate | 17.90% | 22.20% | 18.40% | 19.60% | ||
Pepco Holdings LLC [Member] | ||||||
Income Tax Additional Narrative Information [Line Items] | ||||||
Effective income tax rate | 6.90% | 2.10% | 5.70% | 7.70% | ||
Potomac Electric Power Company [Member] | ||||||
Income Tax Additional Narrative Information [Line Items] | ||||||
Effective income tax rate | 4.90% | (2.30%) | 4.00% | 3.90% | ||
Delmarva Power and Light Company [Member] | ||||||
Income Tax Additional Narrative Information [Line Items] | ||||||
Effective income tax rate | 13.20% | 13.20% | 12.10% | 15.90% | ||
Atlantic City Electric Company [Member] | ||||||
Income Tax Additional Narrative Information [Line Items] | ||||||
Effective income tax rate | 3.10% | 11.60% | 2.20% | 13.60% | ||
ILLINOIS | ||||||
Income Tax Additional Narrative Information [Line Items] | ||||||
Effective income tax rate | 10.49% | 9.50% |
Income Taxes - Reconciliation t
Income Taxes - Reconciliation to Effective Tax Rate (Details) | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2019 | Sep. 30, 2018 | |
Effective Income Tax Rate Reconciliation, Percent [Abstract] | ||||
U.S. Federal statutory rate | 21.00% | 21.00% | 21.00% | 21.00% |
Increase (decrease) due to: | ||||
State income taxes, net of Federal income tax benefit | 6.40% | (1.20%) | 5.10% | 1.70% |
Qualified nuclear decommissioning trust fund income | 3.20% | 2.40% | 5.30% | 0.90% |
Amortization of investment tax credit, including deferred taxes on basis difference | (4.10%) | (0.60%) | (1.90%) | (0.90%) |
Plant basis differences | (1.70%) | (2.50%) | (1.60%) | (2.70%) |
Production tax credits and other credits | (1.20%) | (1.20%) | (1.00%) | (1.80%) |
Noncontrolling interests | (2.20%) | (1.10%) | (1.00%) | (1.10%) |
Excess deferred tax amortization | (6.50%) | (6.80%) | (6.00%) | (6.10%) |
Tax Cuts and Jobs Act of 2017 | 1.30% | 0.20% | ||
Other | 0.70% | 3.20% | 0.80% | 0.40% |
Effective income tax rate | 15.60% | 14.50% | 20.70% | 11.60% |
Exelon Generation Co L L C [Member] | ||||
Effective Income Tax Rate Reconciliation, Percent [Abstract] | ||||
U.S. Federal statutory rate | 21.00% | 21.00% | 21.00% | 21.00% |
Increase (decrease) due to: | ||||
State income taxes, net of Federal income tax benefit | 5.20% | (9.00%) | 4.20% | (2.60%) |
Qualified nuclear decommissioning trust fund income | 7.10% | 5.80% | 11.90% | 2.60% |
Amortization of investment tax credit, including deferred taxes on basis difference | (8.90%) | (1.10%) | (4.00%) | (2.20%) |
Plant basis differences | 0.00% | 0.00% | 0.00% | 0.00% |
Production tax credits and other credits | (2.70%) | (2.90%) | (2.10%) | (5.10%) |
Noncontrolling interests | (4.80%) | (2.80%) | (2.30%) | (3.20%) |
Excess deferred tax amortization | 0.00% | 0.00% | 0.00% | 0.00% |
Tax Cuts and Jobs Act of 2017 | 3.50% | 1.30% | ||
Other | 0.50% | 5.60% | (0.10%) | 2.00% |
Effective income tax rate | 17.40% | 20.10% | 28.60% | 13.80% |
Commonwealth Edison Co [Member] | ||||
Effective Income Tax Rate Reconciliation, Percent [Abstract] | ||||
U.S. Federal statutory rate | 21.00% | 21.00% | 21.00% | 21.00% |
Increase (decrease) due to: | ||||
State income taxes, net of Federal income tax benefit | 8.10% | 8.30% | 8.20% | 8.20% |
Qualified nuclear decommissioning trust fund income | 0.00% | 0.00% | 0.00% | 0.00% |
Amortization of investment tax credit, including deferred taxes on basis difference | (0.20%) | (0.20%) | (0.20%) | (0.20%) |
Plant basis differences | (1.00%) | (0.30%) | (0.70%) | (0.10%) |
Production tax credits and other credits | 0.00% | (0.10%) | 0.00% | (0.10%) |
Noncontrolling interests | 0.00% | 0.00% | 0.00% | 0.00% |
Excess deferred tax amortization | (9.90%) | (7.80%) | (9.20%) | (7.60%) |
Tax Cuts and Jobs Act of 2017 | 0.00% | (0.20%) | ||
Other | 0.40% | 0.30% | 0.20% | 0.10% |
Effective income tax rate | 18.40% | 21.20% | 19.30% | 21.10% |
PECO Energy Co [Member] | ||||
Effective Income Tax Rate Reconciliation, Percent [Abstract] | ||||
U.S. Federal statutory rate | 21.00% | 21.00% | 21.00% | 21.00% |
Increase (decrease) due to: | ||||
State income taxes, net of Federal income tax benefit | (0.30%) | (3.60%) | 0.00% | (3.60%) |
Qualified nuclear decommissioning trust fund income | 0.00% | 0.00% | 0.00% | 0.00% |
Amortization of investment tax credit, including deferred taxes on basis difference | 0.00% | (0.10%) | 0.00% | (0.10%) |
Plant basis differences | (7.50%) | (15.20%) | (6.80%) | (15.40%) |
Production tax credits and other credits | 0.00% | 0.00% | 0.00% | 0.00% |
Noncontrolling interests | 0.00% | 0.00% | 0.00% | 0.00% |
Excess deferred tax amortization | (3.60%) | (4.60%) | (2.90%) | (3.40%) |
Tax Cuts and Jobs Act of 2017 | 0.00% | 0.00% | ||
Other | (0.50%) | 0.90% | (0.20%) | 0.00% |
Effective income tax rate | 9.10% | (1.60%) | 11.10% | (1.50%) |
Baltimore Gas and Electric Company [Member] | ||||
Effective Income Tax Rate Reconciliation, Percent [Abstract] | ||||
U.S. Federal statutory rate | 21.00% | 21.00% | 21.00% | 21.00% |
Increase (decrease) due to: | ||||
State income taxes, net of Federal income tax benefit | 6.30% | 7.30% | 6.40% | 6.60% |
Qualified nuclear decommissioning trust fund income | 0.00% | 0.00% | 0.00% | 0.00% |
Amortization of investment tax credit, including deferred taxes on basis difference | (0.10%) | 0.00% | (0.10%) | (0.10%) |
Plant basis differences | (1.10%) | (0.80%) | (1.10%) | (0.70%) |
Production tax credits and other credits | 0.00% | 0.00% | 0.00% | 0.00% |
Noncontrolling interests | 0.00% | 0.00% | 0.00% | 0.00% |
Excess deferred tax amortization | (8.00%) | (7.90%) | (7.90%) | (8.10%) |
Tax Cuts and Jobs Act of 2017 | 0.00% | 0.00% | ||
Other | (0.20%) | 2.60% | 0.10% | 0.90% |
Effective income tax rate | 17.90% | 22.20% | 18.40% | 19.60% |
Pepco Holdings LLC [Member] | ||||
Effective Income Tax Rate Reconciliation, Percent [Abstract] | ||||
U.S. Federal statutory rate | 21.00% | 21.00% | 21.00% | 21.00% |
Increase (decrease) due to: | ||||
State income taxes, net of Federal income tax benefit | 4.80% | 0.20% | 4.80% | 2.70% |
Qualified nuclear decommissioning trust fund income | 0.00% | 0.00% | 0.00% | 0.00% |
Amortization of investment tax credit, including deferred taxes on basis difference | (0.20%) | (0.20%) | (0.20%) | (0.20%) |
Plant basis differences | (1.80%) | (2.00%) | (1.80%) | (1.90%) |
Production tax credits and other credits | 0.00% | 0.00% | 0.00% | 0.00% |
Noncontrolling interests | 0.00% | 0.00% | 0.00% | 0.00% |
Excess deferred tax amortization | (17.70%) | (17.70%) | (18.60%) | (14.50%) |
Tax Cuts and Jobs Act of 2017 | 0.20% | 0.30% | ||
Other | 0.80% | 0.60% | 0.50% | 0.30% |
Effective income tax rate | 6.90% | 2.10% | 5.70% | 7.70% |
Potomac Electric Power Company [Member] | ||||
Effective Income Tax Rate Reconciliation, Percent [Abstract] | ||||
U.S. Federal statutory rate | 21.00% | 21.00% | 21.00% | 21.00% |
Increase (decrease) due to: | ||||
State income taxes, net of Federal income tax benefit | 1.90% | 1.00% | 2.00% | 2.40% |
Qualified nuclear decommissioning trust fund income | 0.00% | 0.00% | 0.00% | 0.00% |
Amortization of investment tax credit, including deferred taxes on basis difference | (0.10%) | (0.10%) | (0.10%) | (0.10%) |
Plant basis differences | (2.60%) | (3.40%) | (2.30%) | (2.90%) |
Production tax credits and other credits | 0.00% | 0.00% | 0.00% | 0.00% |
Noncontrolling interests | 0.00% | 0.00% | 0.00% | 0.00% |
Excess deferred tax amortization | (16.30%) | (21.20%) | (17.30%) | (16.50%) |
Tax Cuts and Jobs Act of 2017 | 0.10% | 0.00% | ||
Other | 1.00% | 0.30% | 0.70% | 0.00% |
Effective income tax rate | 4.90% | (2.30%) | 4.00% | 3.90% |
Delmarva Power and Light Company [Member] | ||||
Effective Income Tax Rate Reconciliation, Percent [Abstract] | ||||
U.S. Federal statutory rate | 21.00% | 21.00% | 21.00% | 21.00% |
Increase (decrease) due to: | ||||
State income taxes, net of Federal income tax benefit | 6.60% | 6.60% | 6.70% | 6.50% |
Qualified nuclear decommissioning trust fund income | 0.00% | 0.00% | 0.00% | 0.00% |
Amortization of investment tax credit, including deferred taxes on basis difference | (0.20%) | (0.30%) | (0.20%) | (0.30%) |
Plant basis differences | (0.60%) | (0.70%) | (0.60%) | (0.70%) |
Production tax credits and other credits | 0.00% | 0.00% | 0.00% | 0.00% |
Noncontrolling interests | 0.00% | 0.00% | 0.00% | 0.00% |
Excess deferred tax amortization | (13.50%) | (14.00%) | (15.00%) | (11.00%) |
Tax Cuts and Jobs Act of 2017 | 0.00% | 0.00% | ||
Other | (0.10%) | 0.60% | 0.20% | 0.40% |
Effective income tax rate | 13.20% | 13.20% | 12.10% | 15.90% |
Atlantic City Electric Company [Member] | ||||
Effective Income Tax Rate Reconciliation, Percent [Abstract] | ||||
U.S. Federal statutory rate | 21.00% | 21.00% | 21.00% | 21.00% |
Increase (decrease) due to: | ||||
State income taxes, net of Federal income tax benefit | 6.90% | 7.30% | 6.90% | 7.30% |
Qualified nuclear decommissioning trust fund income | 0.00% | 0.00% | 0.00% | 0.00% |
Amortization of investment tax credit, including deferred taxes on basis difference | (0.30%) | (0.30%) | (0.30%) | (0.30%) |
Plant basis differences | (1.90%) | (1.30%) | (2.00%) | (1.30%) |
Production tax credits and other credits | 0.00% | 0.00% | 0.00% | 0.00% |
Noncontrolling interests | 0.00% | 0.00% | 0.00% | 0.00% |
Excess deferred tax amortization | (23.30%) | (15.40%) | (23.40%) | (14.00%) |
Tax Cuts and Jobs Act of 2017 | 0.00% | 0.00% | ||
Other | 0.70% | 0.30% | 0.00% | 0.90% |
Effective income tax rate | 3.10% | 11.60% | 2.20% | 13.60% |
Income Taxes - Accounting for U
Income Taxes - Accounting for Uncertainty in Income Taxes (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Dec. 31, 2018 |
Income Tax Contingency [Line Items] | ||
Unrecognized Tax Benefits | $ 448 | $ 477 |
Exelon Generation Co L L C [Member] | ||
Income Tax Contingency [Line Items] | ||
Unrecognized Tax Benefits | 411 | 408 |
Commonwealth Edison Co [Member] | ||
Income Tax Contingency [Line Items] | ||
Unrecognized Tax Benefits | 0 | 2 |
Pepco Holdings LLC [Member] | ||
Income Tax Contingency [Line Items] | ||
Unrecognized Tax Benefits | 45 | 45 |
Atlantic City Electric Company [Member] | ||
Income Tax Contingency [Line Items] | ||
Unrecognized Tax Benefits | $ 14 | $ 14 |
Income Taxes Income Taxes - Rea
Income Taxes Income Taxes - Reasonably possible the total amount of unrecognized tax benefits could significantly increase or decrease within 12 months after the reporting date (Details) $ in Millions | Sep. 30, 2019USD ($) |
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items] | |
Decrease in Unrecognized Tax Benefits is Reasonably Possible | $ 425 |
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 411 |
Exelon Generation Co L L C [Member] | |
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items] | |
Decrease in Unrecognized Tax Benefits is Reasonably Possible | 411 |
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 411 |
Pepco Holdings LLC [Member] | |
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items] | |
Decrease in Unrecognized Tax Benefits is Reasonably Possible | 14 |
Atlantic City Electric Company [Member] | |
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items] | |
Decrease in Unrecognized Tax Benefits is Reasonably Possible | $ 14 |
Income Taxes Income Taxes - Oth
Income Taxes Income Taxes - Other Income Tax Matters (Details) - State and Local Jurisdiction [Member] | 3 Months Ended |
Sep. 30, 2019USD ($) | |
Schedule of Components of Income Tax Expense (Benefit) [Line Items] | |
Increase (Decrease) in Deferred Income Taxes | $ 23 |
Increase (Decrease) in Income Taxes | 23 |
Exelon Generation Co L L C [Member] | |
Schedule of Components of Income Tax Expense (Benefit) [Line Items] | |
Increase (Decrease) in Deferred Income Taxes | 9 |
Increase (Decrease) in Income Taxes | $ 9 |
Nuclear Decommissioning - Narra
Nuclear Decommissioning - Narrative (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||
Sep. 30, 2019 | Mar. 31, 2019 | Sep. 30, 2019 | Sep. 30, 2018 | Dec. 31, 2018 | |
Nuclear Decommissioning Additional Narrative Information [Line Items] | |||||
Asset Retirement Obligation, Period Increase (Decrease) | $ 280 | $ (235) | |||
Asset Retirement Obligation, Revision of Estimate | (300) | $ 330 | $ 20 | ||
Decommissioning Fund Investments | 12,706 | 12,706 | $ 11,661 | ||
Assets held for sale | 18 | 18 | 904 | ||
Exelon Generation Co L L C [Member] | |||||
Nuclear Decommissioning Additional Narrative Information [Line Items] | |||||
Asset Retirement Obligation, Period Increase (Decrease) | 280 | (235) | |||
Asset Retirement Obligation, Revision of Estimate | (300) | 330 | 0 | ||
Decommissioning Fund Investments | 12,706 | 12,706 | 11,661 | ||
Assets held for sale | 18 | 18 | 904 | ||
Potomac Electric Power Company [Member] | |||||
Nuclear Decommissioning Additional Narrative Information [Line Items] | |||||
Asset Retirement Obligation, Revision of Estimate | $ 22 | ||||
Nuclear Decommissioning [Member] | |||||
Nuclear Decommissioning Additional Narrative Information [Line Items] | |||||
Asset Retirement Obligation, Revision of Estimate | 211 | ||||
Nuclear Decommissioning [Member] | Exelon Generation Co L L C [Member] | |||||
Nuclear Decommissioning Additional Narrative Information [Line Items] | |||||
Asset Retirement Obligation, Revision of Estimate | 211 | ||||
Three Mile Island [Member] | |||||
Nuclear Decommissioning Additional Narrative Information [Line Items] | |||||
Asset Retirement Obligation, Period Increase (Decrease) | (110) | ||||
Three Mile Island [Member] | Exelon Generation Co L L C [Member] | |||||
Nuclear Decommissioning Additional Narrative Information [Line Items] | |||||
Asset Retirement Obligation, Period Increase (Decrease) | (110) | ||||
Assets, Total [Member] | |||||
Nuclear Decommissioning Additional Narrative Information [Line Items] | |||||
Decommissioning Fund Investments | 12,862 | 12,862 | 12,695 | ||
Assets, Total [Member] | Exelon Generation Co L L C [Member] | |||||
Nuclear Decommissioning Additional Narrative Information [Line Items] | |||||
Decommissioning Fund Investments | 12,862 | 12,862 | 12,695 | ||
Nuclear Decommissioning Trust Fund Investments [Member] | Oyster Creek [Member] | |||||
Nuclear Decommissioning Additional Narrative Information [Line Items] | |||||
Assets held for sale | 890 | ||||
Nuclear Decommissioning Trust Fund Investments [Member] | Oyster Creek [Member] | Exelon Generation Co L L C [Member] | |||||
Nuclear Decommissioning Additional Narrative Information [Line Items] | |||||
Assets held for sale | 890 | ||||
Other Current Assets [Member] | |||||
Nuclear Decommissioning Additional Narrative Information [Line Items] | |||||
Decommissioning Fund Investments | 156 | 156 | 144 | ||
Other Current Assets [Member] | Exelon Generation Co L L C [Member] | |||||
Nuclear Decommissioning Additional Narrative Information [Line Items] | |||||
Decommissioning Fund Investments | 156 | $ 156 | $ 144 | ||
Operating Expense [Member] | |||||
Nuclear Decommissioning Additional Narrative Information [Line Items] | |||||
Asset Retirement Obligation, Revision of Estimate | (65) | ||||
Operating Expense [Member] | Exelon Generation Co L L C [Member] | |||||
Nuclear Decommissioning Additional Narrative Information [Line Items] | |||||
Asset Retirement Obligation, Revision of Estimate | $ (65) | ||||
Operating Expense [Member] | Three Mile Island [Member] | |||||
Nuclear Decommissioning Additional Narrative Information [Line Items] | |||||
Asset Retirement Obligation, Revision of Estimate | (85) | ||||
Operating Expense [Member] | Three Mile Island [Member] | Exelon Generation Co L L C [Member] | |||||
Nuclear Decommissioning Additional Narrative Information [Line Items] | |||||
Asset Retirement Obligation, Revision of Estimate | $ (85) |
Nuclear Decommissioning - Rollf
Nuclear Decommissioning - Rollforward of Nuclear Decommissioning ARO (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||
Sep. 30, 2019 | Mar. 31, 2019 | Sep. 30, 2019 | Sep. 30, 2018 | Dec. 31, 2018 | |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||
Accretion expense | $ 371 | $ 367 | |||
Asset Retirement Obligation, Revision of Estimate | $ (300) | $ 330 | 20 | ||
Liabilities held for sale | 11 | 11 | $ 777 | ||
Nuclear Decommissioning [Member] | |||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||
Nuclear decommissioning ARO, beginning balance | 10,005 | 10,005 | |||
Asset Retirement Obligation, Liabilities Settled | (755) | ||||
Accretion expense | 361 | ||||
Asset Retirement Obligation, Revision of Estimate | 211 | ||||
Costs incurred related to decommissioning plants | (52) | ||||
Nuclear decommissioning ARO, ending balance | 9,770 | 9,770 | |||
Current portion of ARO | 127 | 127 | 22 | ||
Exelon Generation Co L L C [Member] | |||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||
Accretion expense | 371 | 365 | |||
Asset Retirement Obligation, Revision of Estimate | (300) | 330 | $ 0 | ||
Liabilities held for sale | 11 | 11 | 777 | ||
Exelon Generation Co L L C [Member] | Nuclear Decommissioning [Member] | |||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||
Nuclear decommissioning ARO, beginning balance | 10,005 | 10,005 | |||
Asset Retirement Obligation, Liabilities Settled | (755) | ||||
Accretion expense | 361 | ||||
Asset Retirement Obligation, Revision of Estimate | 211 | ||||
Costs incurred related to decommissioning plants | (52) | ||||
Nuclear decommissioning ARO, ending balance | 9,770 | 9,770 | |||
Current portion of ARO | 127 | $ 127 | 22 | ||
Nuclear Decommissioning Asset Retirement Obligation [Member] | Oyster Creek [Member] | |||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||
Liabilities held for sale | 772 | ||||
Nuclear Decommissioning Asset Retirement Obligation [Member] | Exelon Generation Co L L C [Member] | Oyster Creek [Member] | |||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||
Liabilities held for sale | $ 772 | ||||
Operating Expense [Member] | |||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||
Asset Retirement Obligation, Revision of Estimate | (65) | ||||
Operating Expense [Member] | Three Mile Island [Member] | |||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||
Asset Retirement Obligation, Revision of Estimate | (85) | ||||
Operating Expense [Member] | Exelon Generation Co L L C [Member] | |||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||
Asset Retirement Obligation, Revision of Estimate | $ (65) | ||||
Operating Expense [Member] | Exelon Generation Co L L C [Member] | Three Mile Island [Member] | |||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||
Asset Retirement Obligation, Revision of Estimate | $ (85) |
Retirement Benefits - Narrative
Retirement Benefits - Narrative (Details) $ in Millions | 3 Months Ended | 9 Months Ended |
Sep. 30, 2019USD ($) | Sep. 30, 2019USD ($) | |
Defined Benefit Plan Disclosure [Line Items] | ||
Increase (Decrease) in Obligation, Pension Benefits | $ 75 | |
Increase (Decrease) in Obligation, Other Postretirement Benefits | 36 | |
Accumulated Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), after Tax | (39) | $ (39) |
Defined Benefit Plan Amounts Recognized In Regulatory Assets Before Tax | 53 | |
Defined Benefit Plan Amounts Recognized In Regulatory Liabilities Before Tax | $ (5) | |
Pension Plan, Defined Benefit [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Expected return on assets | 7.00% | |
Discount rate | 4.31% | |
Other Postretirement Benefit Plan, Defined Benefit [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Expected return on assets | 6.67% | |
Discount rate | 4.30% |
Retirement Benefits - Calculati
Retirement Benefits - Calculation of Net Periodic Benefit Cost (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2019 | Sep. 30, 2018 | |
Amortization of: | ||||
Net periodic benefit cost | $ 2 | $ 12 | $ (8) | $ 33 |
Pension Plan, Defined Benefit [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Service cost | 89 | 100 | 267 | 303 |
Interest cost | 221 | 201 | 663 | 602 |
Expected return on assets | (306) | (312) | (918) | (939) |
Amortization of: | ||||
Prior service cost (benefit) | 0 | 0 | 0 | 1 |
Actuarial loss | 104 | 158 | 310 | 472 |
Settlement charges | 7 | 0 | 7 | 1 |
Contractual Termination Benefits | 1 | 0 | 1 | 0 |
Net periodic benefit cost | 116 | 147 | 330 | 440 |
Other Postretirement Benefit Plan, Defined Benefit [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Service cost | 23 | 28 | 70 | 84 |
Interest cost | 47 | 43 | 141 | 131 |
Expected return on assets | (38) | (43) | (115) | (130) |
Amortization of: | ||||
Prior service cost (benefit) | (45) | (47) | (134) | (140) |
Actuarial loss | 11 | 18 | 34 | 50 |
Settlement charges | 0 | 0 | 0 | 0 |
Contractual Termination Benefits | 0 | 0 | 0 | 0 |
Net periodic benefit cost | $ (2) | $ (1) | $ (4) | $ (5) |
Retirement Benefits - Allocated
Retirement Benefits - Allocated Portion of Pension and Postretirement Benefit Plan Costs (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2019 | Sep. 30, 2018 | |
Defined Benefit Plan Disclosure [Line Items] | ||||
Pension and Other Postretirement Benefits Cost (Reversal of Cost) | $ 324 | $ 435 | ||
Pension and other post retirement benefit [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Pension and Other Postretirement Benefits Cost (Reversal of Cost) | $ 114 | $ 145 | 326 | 435 |
Exelon Generation Co L L C [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Pension and Other Postretirement Benefits Cost (Reversal of Cost) | 98 | 151 | ||
Exelon Generation Co L L C [Member] | Pension and other post retirement benefit [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Pension and Other Postretirement Benefits Cost (Reversal of Cost) | 37 | 50 | 100 | 151 |
Commonwealth Edison Co [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Pension and Other Postretirement Benefits Cost (Reversal of Cost) | 70 | 133 | ||
Commonwealth Edison Co [Member] | Pension and other post retirement benefit [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Pension and Other Postretirement Benefits Cost (Reversal of Cost) | 23 | 45 | 70 | 133 |
PECO Energy Co [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Pension and Other Postretirement Benefits Cost (Reversal of Cost) | 9 | 14 | ||
PECO Energy Co [Member] | Pension and other post retirement benefit [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Pension and Other Postretirement Benefits Cost (Reversal of Cost) | 4 | 5 | 9 | 14 |
Baltimore Gas and Electric Company [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Pension and Other Postretirement Benefits Cost (Reversal of Cost) | 45 | 43 | ||
Baltimore Gas and Electric Company [Member] | Pension and other post retirement benefit [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Pension and Other Postretirement Benefits Cost (Reversal of Cost) | 16 | 15 | 47 | 44 |
Pepco Holdings LLC [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Pension and Other Postretirement Benefits Cost (Reversal of Cost) | 71 | 51 | ||
Pepco Holdings LLC [Member] | Pension and other post retirement benefit [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Pension and Other Postretirement Benefits Cost (Reversal of Cost) | 23 | 17 | 71 | 51 |
Potomac Electric Power Company [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Pension and Other Postretirement Benefits Cost (Reversal of Cost) | 19 | 10 | ||
Potomac Electric Power Company [Member] | Pension and other post retirement benefit [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Pension and Other Postretirement Benefits Cost (Reversal of Cost) | 6 | 3 | 19 | 10 |
Delmarva Power and Light Company [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Pension and Other Postretirement Benefits Cost (Reversal of Cost) | 11 | 5 | ||
Delmarva Power and Light Company [Member] | Pension and other post retirement benefit [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Pension and Other Postretirement Benefits Cost (Reversal of Cost) | 4 | 2 | 11 | 5 |
Atlantic City Electric Company [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Pension and Other Postretirement Benefits Cost (Reversal of Cost) | 12 | 10 | ||
Atlantic City Electric Company [Member] | Pension and other post retirement benefit [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Pension and Other Postretirement Benefits Cost (Reversal of Cost) | $ 4 | $ 3 | $ 12 | $ 10 |
Retirement Benefits - Defined C
Retirement Benefits - Defined Contribution Savings Plans (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2019 | Sep. 30, 2018 | |
Defined Benefit Plan Disclosure [Line Items] | ||||
Savings Plan Matching Contributions | $ 36 | $ 44 | $ 101 | $ 126 |
Exelon Generation Co L L C [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Savings Plan Matching Contributions | 14 | 23 | 41 | 65 |
Commonwealth Edison Co [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Savings Plan Matching Contributions | 9 | 8 | 26 | 23 |
PECO Energy Co [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Savings Plan Matching Contributions | 2 | 2 | 7 | 7 |
Baltimore Gas and Electric Company [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Savings Plan Matching Contributions | 4 | 2 | 9 | 5 |
Pepco Holdings LLC [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Savings Plan Matching Contributions | 4 | 4 | 8 | 10 |
Potomac Electric Power Company [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Savings Plan Matching Contributions | 1 | 1 | 2 | 2 |
Delmarva Power and Light Company [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Savings Plan Matching Contributions | 1 | 1 | 2 | 2 |
Atlantic City Electric Company [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Savings Plan Matching Contributions | $ 1 | $ 1 | $ 1 | $ 2 |
Changes in Accumulated Other _3
Changes in Accumulated Other Comprehensive Income - Schedule of Changes in AOCI (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||||||
Sep. 30, 2019 | Jun. 30, 2019 | Mar. 31, 2019 | Sep. 30, 2018 | Jun. 30, 2018 | Mar. 31, 2018 | Sep. 30, 2019 | Sep. 30, 2018 | |
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||||
Beginning balance | $ 33,907 | $ 33,704 | $ 33,070 | $ 32,839 | $ 32,565 | $ 32,187 | $ 33,070 | $ 32,187 |
Beginning Balance | 30,764 | 30,764 | ||||||
Other comprehensive income | 30 | 52 | 33 | 169 | ||||
Ending balance | 34,352 | 33,907 | 33,704 | 33,388 | 32,839 | 32,565 | 34,352 | 33,388 |
Ending Balance | 32,023 | 32,023 | ||||||
Gains (Losses) on Cash Flow Hedges | ||||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||||
Beginning balance | (2) | (2) | (2) | (14) | (2) | (14) | ||
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | 0 | 0 | 0 | 11 | ||||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 0 | 0 | 0 | 1 | ||||
Other comprehensive income | 0 | 0 | 0 | 12 | ||||
Ending balance | (2) | (2) | (2) | (2) | (2) | (2) | ||
Gains (Losses) on Cash Flow Hedges | Accounting Standards Update 2016-01 [Member] | ||||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard(c) | 0 | |||||||
Unrealized Gains (Losses) on Marketable Securities | ||||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||||
Beginning balance | 10 | 10 | ||||||
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | 0 | |||||||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 0 | |||||||
Other comprehensive income | 0 | |||||||
Ending balance | 0 | 0 | ||||||
Unrealized Gains (Losses) on Marketable Securities | Accounting Standards Update 2016-01 [Member] | ||||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard(c) | (10) | |||||||
Pension and Non-Pension Postretirement Benefit Plan Items | ||||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||||
Beginning balance | (2,957) | (2,960) | (2,890) | (2,998) | (2,960) | (2,998) | ||
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | 6 | 5 | (32) | 22 | ||||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 21 | 45 | 62 | 136 | ||||
Other comprehensive income | 27 | 50 | 30 | 158 | ||||
Ending balance | (2,930) | (2,957) | (2,840) | (2,890) | (2,930) | (2,840) | ||
Pension and Non-Pension Postretirement Benefit Plan Items | Accounting Standards Update 2016-01 [Member] | ||||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard(c) | 0 | |||||||
Foreign Currency Items | ||||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||||
Beginning balance | (29) | (33) | (29) | (23) | (33) | (23) | ||
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | (2) | 2 | 2 | (4) | ||||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 0 | 0 | 0 | 0 | ||||
Other comprehensive income | (2) | 2 | 2 | (4) | ||||
Ending balance | (31) | (29) | (27) | (29) | (31) | (27) | ||
Foreign Currency Items | Accounting Standards Update 2016-01 [Member] | ||||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard(c) | 0 | |||||||
AOCI of Investments in Unconsolidated Affiliates | ||||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||||
Beginning balance | (2) | 0 | 0 | (1) | 0 | (1) | ||
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | 0 | 0 | (2) | 1 | ||||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 2 | 0 | 2 | 0 | ||||
Other comprehensive income | 2 | 0 | 0 | 1 | ||||
Ending balance | 0 | (2) | 0 | 0 | 0 | 0 | ||
AOCI of Investments in Unconsolidated Affiliates | Accounting Standards Update 2016-01 [Member] | ||||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard(c) | 0 | |||||||
Total | ||||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||||
Beginning balance | (2,990) | (3,012) | (2,995) | (2,921) | (2,965) | (3,026) | (2,995) | (3,026) |
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | 4 | 7 | (32) | 30 | ||||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 23 | 45 | 64 | 137 | ||||
Other comprehensive income | 27 | 22 | (17) | 52 | 44 | 71 | 32 | 167 |
Ending balance | $ (2,963) | $ (2,990) | $ (3,012) | $ (2,869) | $ (2,921) | $ (2,965) | $ (2,963) | (2,869) |
Total | Accounting Standards Update 2016-01 [Member] | ||||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard(c) | $ (10) |
Changes in Accumulated Other _4
Changes in Accumulated Other Comprehensive Income - Components of Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2019 | Sep. 30, 2018 | |
Prior service costs | ||||
Accumulated Other Comprehensive Income (Loss) [Line Items] | ||||
Other Comprehensive Income (Loss), Tax | $ 6 | $ 6 | $ 18 | $ 18 |
Actuarial losses | ||||
Accumulated Other Comprehensive Income (Loss) [Line Items] | ||||
Other Comprehensive Income (Loss), Tax | (13) | (21) | (39) | (65) |
Pension and Non-Pension Postretirement Benefit Plan Items | ||||
Accumulated Other Comprehensive Income (Loss) [Line Items] | ||||
Other Comprehensive Income (Loss), Tax | $ 0 | $ (2) | $ 14 | $ (8) |
Commitments and Contingencies -
Commitments and Contingencies - Narrative (Details) $ in Millions | Mar. 23, 2016USD ($)MW | Sep. 30, 2019USD ($)MGPSiteOpen_claimMW | Dec. 31, 2022MW | Dec. 31, 2018USD ($)MW | Dec. 31, 2017MW |
Commitments And Contingencies Additional Narrative Information [Line Items] | |||||
Other Commitment | $ 3,113 | ||||
Accrual for Environmental Loss Contingencies, Gross | 507 | $ 496 | |||
Exelon Generation Co L L C [Member] | |||||
Commitments And Contingencies Additional Narrative Information [Line Items] | |||||
Other Commitment | 2,476 | ||||
Accrual for Environmental Loss Contingencies, Gross | 107 | 108 | |||
Liability for Asbestos and Environmental Claims, Gross | 83 | 79 | |||
Commonwealth Edison Co [Member] | |||||
Commitments And Contingencies Additional Narrative Information [Line Items] | |||||
Other Commitment | $ 257 | ||||
Mgp Site Contingency Monitoring Count | MGPSite | 21 | ||||
Accrual for Environmental Loss Contingencies, Gross | $ 328 | 329 | |||
PECO Energy Co [Member] | |||||
Commitments And Contingencies Additional Narrative Information [Line Items] | |||||
Other Commitment | $ 187 | ||||
Mgp Site Contingency Monitoring Count | MGPSite | 8 | ||||
Accrual for Environmental Loss Contingencies, Gross | $ 20 | 27 | |||
Baltimore Gas and Electric Company [Member] | |||||
Commitments And Contingencies Additional Narrative Information [Line Items] | |||||
Other Commitment | $ 25 | ||||
Mgp Site Contingency Monitoring Count | MGPSite | 4 | ||||
Accrual for Environmental Loss Contingencies, Gross | $ 3 | 5 | |||
Pepco Holdings LLC [Member] | |||||
Commitments And Contingencies Additional Narrative Information [Line Items] | |||||
Other Commitment | 61 | ||||
Accrual for Environmental Loss Contingencies, Gross | 49 | 27 | |||
Potomac Electric Power Company [Member] | |||||
Commitments And Contingencies Additional Narrative Information [Line Items] | |||||
Other Commitment | 36 | ||||
Accrual for Environmental Loss Contingencies, Gross | 47 | 25 | |||
Delmarva Power and Light Company [Member] | |||||
Commitments And Contingencies Additional Narrative Information [Line Items] | |||||
Other Commitment | $ 16 | ||||
Mgp Site Contingency Count | MGPSite | 1 | ||||
Accrual for Environmental Loss Contingencies, Gross | $ 1 | $ 1 | |||
Open Claims [Member] | Exelon Generation Co L L C [Member] | |||||
Commitments And Contingencies Additional Narrative Information [Line Items] | |||||
Liability for Asbestos and Environmental Claims, Gross | $ 25 | ||||
Open Asbestos Related Personal Injury Claims | Open_claim | 257 | ||||
Estimated Future Claims [Member] | Exelon Generation Co L L C [Member] | |||||
Commitments And Contingencies Additional Narrative Information [Line Items] | |||||
Liability for Asbestos and Environmental Claims, Gross | $ 58 | ||||
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 | ||||
West Lake [Member] | |||||
Commitments And Contingencies Additional Narrative Information [Line Items] | |||||
Accrual for Environmental Loss Contingencies, Gross | 280 | ||||
West Lake [Member] | Exelon Generation Co L L C [Member] | |||||
Commitments And Contingencies Additional Narrative Information [Line Items] | |||||
Accrual for Environmental Loss Contingencies, Gross | 20 | ||||
Accrual for Environmental Loss Contingencies, Component Amount | 90 | ||||
Other Solar Projects [Member] | Pepco Holdings Inc [Member] | |||||
Commitments And Contingencies Additional Narrative Information [Line Items] | |||||
Business Acquisition, Expected New Generation Mwh | MW | 37 | ||||
Other Commitment | $ 127 | $ 107 | |||
Other Non-Financial Commitment | MW | 27 | ||||
Other Solar Projects [Member] | Pepco Holdings Inc [Member] | Exelon Generation Co L L C [Member] | |||||
Commitments And Contingencies Additional Narrative Information [Line Items] | |||||
Other Commitment | $ 107 | ||||
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 | ||
Subsequent Event [Member] | Wind Assets [Member] | Pepco Holdings Inc [Member] | Delmarva Power and Light Company [Member] | |||||
Commitments And Contingencies Additional Narrative Information [Line Items] | |||||
Purchase Commitment | MW | 40 |
Commitments and Contingencies_3
Commitments and Contingencies - Merger Commitment (Details) $ in Millions | Sep. 30, 2019USD ($) |
Other Commitments [Line Items] | |
Other Commitment | $ 3,113 |
Pepco Holdings LLC [Member] | |
Other Commitments [Line Items] | |
Other Commitment | 61 |
Potomac Electric Power Company [Member] | |
Other Commitments [Line Items] | |
Other Commitment | 36 |
Delmarva Power and Light Company [Member] | |
Other Commitments [Line Items] | |
Other Commitment | 16 |
Atlantic City Electric Company [Member] | |
Other Commitments [Line Items] | |
Other Commitment | 10 |
Pepco Holdings Inc [Member] | |
Other Commitments [Line Items] | |
Other Commitment | 513 |
Pepco Holdings Inc [Member] | Remaining commitment | |
Other Commitments [Line Items] | |
Other Commitment | 112 |
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 | 82 |
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 | 67 |
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 | 9 |
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 | $ 6 |
Commitments and Contingencies_4
Commitments and Contingencies - Schedule of Commercial Commitments (Details) $ in Millions | Sep. 30, 2019USD ($) |
Other Commitments [Line Items] | |
Other Commitment | $ 3,113 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 1,507 |
Other Commitment, Due in Second Year | 1,155 |
Other Commitment, Due in Third Year | 52 |
Other Commitment, Due in Fourth Year | 4 |
Other Commitment, Due in Fifth Year | 3 |
Other Commitment, Due after Fifth Year | 393 |
Guarantor Obligations, Maximum Exposure, Undiscounted | 68 |
Letters of Credit | |
Other Commitments [Line Items] | |
Other Commitment | 1,718 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 1,192 |
Other Commitment, Due in Second Year | 515 |
Other Commitment, Due in Third Year | 11 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 0 |
Surety Bonds | |
Other Commitments [Line Items] | |
Other Commitment | 991 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 315 |
Other Commitment, Due in Second Year | 638 |
Other Commitment, Due in Third Year | 38 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 0 |
Financing trust guarantees | |
Other Commitments [Line Items] | |
Other Commitment | 378 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 0 |
Other Commitment, Due in Second Year | 0 |
Other Commitment, Due in Third Year | 0 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 378 |
Guaranteed lease residual values | |
Other Commitments [Line Items] | |
Other Commitment | 26 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 0 |
Other Commitment, Due in Second Year | 2 |
Other Commitment, Due in Third Year | 3 |
Other Commitment, Due in Fourth Year | 4 |
Other Commitment, Due in Fifth Year | 3 |
Other Commitment, Due after Fifth Year | 15 |
Exelon Generation Co L L C [Member] | |
Other Commitments [Line Items] | |
Other Commitment | 2,476 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 1,477 |
Other Commitment, Due in Second Year | 988 |
Other Commitment, Due in Third Year | 11 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 0 |
Exelon Generation Co L L C [Member] | Letters of Credit | |
Other Commitments [Line Items] | |
Other Commitment | 1,686 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 1,179 |
Other Commitment, Due in Second Year | 496 |
Other Commitment, Due in Third Year | 11 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 0 |
Exelon Generation Co L L C [Member] | Surety Bonds | |
Other Commitments [Line Items] | |
Other Commitment | 790 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 298 |
Other Commitment, Due in Second Year | 492 |
Other Commitment, Due in Third Year | 0 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 0 |
Commonwealth Edison Co [Member] | |
Other Commitments [Line Items] | |
Other Commitment | 257 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 9 |
Other Commitment, Due in Second Year | 46 |
Other Commitment, Due in Third Year | 2 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 200 |
Commonwealth Edison Co [Member] | Letters of Credit | |
Other Commitments [Line Items] | |
Other Commitment | 7 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 4 |
Other Commitment, Due in Second Year | 3 |
Other Commitment, Due in Third Year | 0 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 0 |
Commonwealth Edison Co [Member] | Surety Bonds | |
Other Commitments [Line Items] | |
Other Commitment | 50 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 5 |
Other Commitment, Due in Second Year | 43 |
Other Commitment, Due in Third Year | 2 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 0 |
Commonwealth Edison Co [Member] | Financing trust guarantees | |
Other Commitments [Line Items] | |
Other Commitment | 200 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 0 |
Other Commitment, Due in Second Year | 0 |
Other Commitment, Due in Third Year | 0 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 200 |
PECO Energy Co [Member] | |
Other Commitments [Line Items] | |
Other Commitment | 187 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 1 |
Other Commitment, Due in Second Year | 8 |
Other Commitment, Due in Third Year | 0 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 178 |
PECO Energy Co [Member] | Surety Bonds | |
Other Commitments [Line Items] | |
Other Commitment | 9 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 1 |
Other Commitment, Due in Second Year | 8 |
Other Commitment, Due in Third Year | 0 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 0 |
PECO Energy Co [Member] | Financing trust guarantees | |
Other Commitments [Line Items] | |
Other Commitment | 178 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 0 |
Other Commitment, Due in Second Year | 0 |
Other Commitment, Due in Third Year | 0 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 178 |
Baltimore Gas and Electric Company [Member] | |
Other Commitments [Line Items] | |
Other Commitment | 25 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 4 |
Other Commitment, Due in Second Year | 21 |
Other Commitment, Due in Third Year | 0 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 0 |
Baltimore Gas and Electric Company [Member] | Letters of Credit | |
Other Commitments [Line Items] | |
Other Commitment | 8 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 2 |
Other Commitment, Due in Second Year | 6 |
Other Commitment, Due in Third Year | 0 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 0 |
Baltimore Gas and Electric Company [Member] | Surety Bonds | |
Other Commitments [Line Items] | |
Other Commitment | 17 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 2 |
Other Commitment, Due in Second Year | 15 |
Other Commitment, Due in Third Year | 0 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 0 |
Pepco Holdings LLC [Member] | |
Other Commitments [Line Items] | |
Other Commitment | 61 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 6 |
Other Commitment, Due in Second Year | 31 |
Other Commitment, Due in Third Year | 3 |
Other Commitment, Due in Fourth Year | 4 |
Other Commitment, Due in Fifth Year | 3 |
Other Commitment, Due after Fifth Year | 15 |
Guarantor Obligations, Maximum Exposure, Undiscounted | 68 |
Pepco Holdings LLC [Member] | Letters of Credit | |
Other Commitments [Line Items] | |
Other Commitment | 11 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 1 |
Other Commitment, Due in Second Year | 10 |
Other Commitment, Due in Third Year | 0 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 0 |
Pepco Holdings LLC [Member] | Surety Bonds | |
Other Commitments [Line Items] | |
Other Commitment | 24 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 5 |
Other Commitment, Due in Second Year | 19 |
Other Commitment, Due in Third Year | 0 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 0 |
Pepco Holdings LLC [Member] | Guaranteed lease residual values | |
Other Commitments [Line Items] | |
Other Commitment | 26 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 0 |
Other Commitment, Due in Second Year | 2 |
Other Commitment, Due in Third Year | 3 |
Other Commitment, Due in Fourth Year | 4 |
Other Commitment, Due in Fifth Year | 3 |
Other Commitment, Due after Fifth Year | 15 |
Potomac Electric Power Company [Member] | |
Other Commitments [Line Items] | |
Other Commitment | 36 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 2 |
Other Commitment, Due in Second Year | 25 |
Other Commitment, Due in Third Year | 1 |
Other Commitment, Due in Fourth Year | 1 |
Other Commitment, Due in Fifth Year | 1 |
Other Commitment, Due after Fifth Year | 6 |
Guarantor Obligations, Maximum Exposure, Undiscounted | 22 |
Potomac Electric Power Company [Member] | Letters of Credit | |
Other Commitments [Line Items] | |
Other Commitment | 10 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 0 |
Other Commitment, Due in Second Year | 10 |
Other Commitment, Due in Third Year | 0 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 0 |
Potomac Electric Power Company [Member] | Surety Bonds | |
Other Commitments [Line Items] | |
Other Commitment | 17 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 2 |
Other Commitment, Due in Second Year | 15 |
Other Commitment, Due in Third Year | 0 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 0 |
Potomac Electric Power Company [Member] | Guaranteed lease residual values | |
Other Commitments [Line Items] | |
Other Commitment | 9 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 0 |
Other Commitment, Due in Second Year | 0 |
Other Commitment, Due in Third Year | 1 |
Other Commitment, Due in Fourth Year | 1 |
Other Commitment, Due in Fifth Year | 1 |
Other Commitment, Due after Fifth Year | 6 |
Delmarva Power and Light Company [Member] | |
Other Commitments [Line Items] | |
Other Commitment | 16 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 3 |
Other Commitment, Due in Second Year | 3 |
Other Commitment, Due in Third Year | 1 |
Other Commitment, Due in Fourth Year | 2 |
Other Commitment, Due in Fifth Year | 1 |
Other Commitment, Due after Fifth Year | 6 |
Guarantor Obligations, Maximum Exposure, Undiscounted | 29 |
Delmarva Power and Light Company [Member] | Letters of Credit | |
Other Commitments [Line Items] | |
Other Commitment | 1 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 1 |
Other Commitment, Due in Second Year | 0 |
Other Commitment, Due in Third Year | 0 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 0 |
Delmarva Power and Light Company [Member] | Surety Bonds | |
Other Commitments [Line Items] | |
Other Commitment | 4 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 2 |
Other Commitment, Due in Second Year | 2 |
Other Commitment, Due in Third Year | 0 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 0 |
Delmarva Power and Light Company [Member] | Guaranteed lease residual values | |
Other Commitments [Line Items] | |
Other Commitment | 11 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 0 |
Other Commitment, Due in Second Year | 1 |
Other Commitment, Due in Third Year | 1 |
Other Commitment, Due in Fourth Year | 2 |
Other Commitment, Due in Fifth Year | 1 |
Other Commitment, Due after Fifth Year | 6 |
Atlantic City Electric Company [Member] | |
Other Commitments [Line Items] | |
Other Commitment | 10 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 1 |
Other Commitment, Due in Second Year | 3 |
Other Commitment, Due in Third Year | 1 |
Other Commitment, Due in Fourth Year | 1 |
Other Commitment, Due in Fifth Year | 1 |
Other Commitment, Due after Fifth Year | 3 |
Guarantor Obligations, Maximum Exposure, Undiscounted | 17 |
Atlantic City Electric Company [Member] | Surety Bonds | |
Other Commitments [Line Items] | |
Other Commitment | 3 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 1 |
Other Commitment, Due in Second Year | 2 |
Other Commitment, Due in Third Year | 0 |
Other Commitment, Due in Fourth Year | 0 |
Other Commitment, Due in Fifth Year | 0 |
Other Commitment, Due after Fifth Year | 0 |
Atlantic City Electric Company [Member] | Guaranteed lease residual values | |
Other Commitments [Line Items] | |
Other Commitment | 7 |
Other Commitments, Future Minimum Payments, Remainder of Fiscal Year | 0 |
Other Commitment, Due in Second Year | 1 |
Other Commitment, Due in Third Year | 1 |
Other Commitment, Due in Fourth Year | 1 |
Other Commitment, Due in Fifth Year | 1 |
Other Commitment, Due after Fifth Year | $ 3 |
Maximum [Member] | |
Other Commitments [Line Items] | |
Lessor, Operating Lease, Term of Contract | 84 years |
Maximum [Member] | Guaranteed lease residual values | |
Other Commitments [Line Items] | |
Lessor, Operating Lease, Term of Contract | 8 years |
Maximum [Member] | Exelon Generation Co L L C [Member] | |
Other Commitments [Line Items] | |
Lessor, Operating Lease, Term of Contract | 33 years |
Maximum [Member] | Commonwealth Edison Co [Member] | |
Other Commitments [Line Items] | |
Lessor, Operating Lease, Term of Contract | 18 years |
Maximum [Member] | PECO Energy Co [Member] | |
Other Commitments [Line Items] | |
Lessor, Operating Lease, Term of Contract | 84 years |
Maximum [Member] | Baltimore Gas and Electric Company [Member] | |
Other Commitments [Line Items] | |
Lessor, Operating Lease, Term of Contract | 24 years |
Maximum [Member] | Pepco Holdings LLC [Member] | |
Other Commitments [Line Items] | |
Lessor, Operating Lease, Term of Contract | 14 years |
Maximum [Member] | Potomac Electric Power Company [Member] | |
Other Commitments [Line Items] | |
Lessor, Operating Lease, Term of Contract | 7 years |
Maximum [Member] | Delmarva Power and Light Company [Member] | |
Other Commitments [Line Items] | |
Lessor, Operating Lease, Term of Contract | 14 years |
Maximum [Member] | Atlantic City Electric Company [Member] | |
Other Commitments [Line Items] | |
Lessor, Operating Lease, Term of Contract | 3 years |
Minimum [Member] | |
Other Commitments [Line Items] | |
Lessor, Operating Lease, Term of Contract | 1 year |
Minimum [Member] | Guaranteed lease residual values | |
Other Commitments [Line Items] | |
Lessor, Operating Lease, Term of Contract | 1 year |
Minimum [Member] | Exelon Generation Co L L C [Member] | |
Other Commitments [Line Items] | |
Lessor, Operating Lease, Term of Contract | 1 year |
Minimum [Member] | Commonwealth Edison Co [Member] | |
Other Commitments [Line Items] | |
Lessor, Operating Lease, Term of Contract | 1 year |
Minimum [Member] | PECO Energy Co [Member] | |
Other Commitments [Line Items] | |
Lessor, Operating Lease, Term of Contract | 1 year |
Minimum [Member] | Baltimore Gas and Electric Company [Member] | |
Other Commitments [Line Items] | |
Lessor, Operating Lease, Term of Contract | 24 years |
Minimum [Member] | Pepco Holdings LLC [Member] | |
Other Commitments [Line Items] | |
Lessor, Operating Lease, Term of Contract | 1 year |
Minimum [Member] | Potomac Electric Power Company [Member] | |
Other Commitments [Line Items] | |
Lessor, Operating Lease, Term of Contract | 2 years |
Minimum [Member] | Delmarva Power and Light Company [Member] | |
Other Commitments [Line Items] | |
Lessor, Operating Lease, Term of Contract | 13 years |
Minimum [Member] | Atlantic City Electric Company [Member] | |
Other Commitments [Line Items] | |
Lessor, Operating Lease, Term of Contract | 1 year |
Commitments and Contingencies_5
Commitments and Contingencies - Schedule of Accruals for Environmental Matters (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Dec. 31, 2018 |
Accrual For Environmental Loss Contingencies [Line Items] | ||
Total environmental investigation and remediation reserve | $ 507 | $ 496 |
Exelon Generation Co L L C [Member] | ||
Accrual For Environmental Loss Contingencies [Line Items] | ||
Total environmental investigation and remediation reserve | 107 | 108 |
Commonwealth Edison Co [Member] | ||
Accrual For Environmental Loss Contingencies [Line Items] | ||
Total environmental investigation and remediation reserve | 328 | 329 |
PECO Energy Co [Member] | ||
Accrual For Environmental Loss Contingencies [Line Items] | ||
Total environmental investigation and remediation reserve | 20 | 27 |
Baltimore Gas and Electric Company [Member] | ||
Accrual For Environmental Loss Contingencies [Line Items] | ||
Total environmental investigation and remediation reserve | 3 | 5 |
Pepco Holdings LLC [Member] | ||
Accrual For Environmental Loss Contingencies [Line Items] | ||
Total environmental investigation and remediation reserve | 49 | 27 |
Potomac Electric Power Company [Member] | ||
Accrual For Environmental Loss Contingencies [Line Items] | ||
Total environmental investigation and remediation reserve | 47 | 25 |
Delmarva Power and Light Company [Member] | ||
Accrual For Environmental Loss Contingencies [Line Items] | ||
Total environmental investigation and remediation reserve | 1 | 1 |
Atlantic City Electric Company [Member] | ||
Accrual For Environmental Loss Contingencies [Line Items] | ||
Total environmental investigation and remediation reserve | 1 | 1 |
Accrual For MGP Investigation And Remediation [Member] | ||
Accrual For Environmental Loss Contingencies [Line Items] | ||
Total environmental investigation and remediation reserve | 346 | 356 |
Accrual For MGP Investigation And Remediation [Member] | Exelon Generation Co L L C [Member] | ||
Accrual For Environmental Loss Contingencies [Line Items] | ||
Total environmental investigation and remediation reserve | 0 | 0 |
Accrual For MGP Investigation And Remediation [Member] | Commonwealth Edison Co [Member] | ||
Accrual For Environmental Loss Contingencies [Line Items] | ||
Total environmental investigation and remediation reserve | 327 | 327 |
Accrual For MGP Investigation And Remediation [Member] | PECO Energy Co [Member] | ||
Accrual For Environmental Loss Contingencies [Line Items] | ||
Total environmental investigation and remediation reserve | 18 | 25 |
Accrual For MGP Investigation And Remediation [Member] | Baltimore Gas and Electric Company [Member] | ||
Accrual For Environmental Loss Contingencies [Line Items] | ||
Total environmental investigation and remediation reserve | 1 | 4 |
Accrual For MGP Investigation And Remediation [Member] | Pepco Holdings LLC [Member] | ||
Accrual For Environmental Loss Contingencies [Line Items] | ||
Total environmental investigation and remediation reserve | 0 | 0 |
Accrual For MGP Investigation And Remediation [Member] | Potomac Electric Power Company [Member] | ||
Accrual For Environmental Loss Contingencies [Line Items] | ||
Total environmental investigation and remediation reserve | 0 | 0 |
Accrual For MGP Investigation And Remediation [Member] | Delmarva Power and Light Company [Member] | ||
Accrual For Environmental Loss Contingencies [Line Items] | ||
Total environmental investigation and remediation reserve | 0 | 0 |
Accrual For MGP Investigation And Remediation [Member] | Atlantic City Electric Company [Member] | ||
Accrual For Environmental Loss Contingencies [Line Items] | ||
Total environmental investigation and remediation reserve | $ 0 | $ 0 |
Supplemental Financial Inform_3
Supplemental Financial Information - Utility Taxes (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2019 | Sep. 30, 2018 | |
Supplemental Statement of Operations Information [Line Items] | ||||
Utility taxes | $ 241 | $ 253 | $ 672 | $ 705 |
Property | 148 | 145 | 444 | 416 |
Payroll | 57 | 58 | 185 | 191 |
Exelon Generation Co L L C [Member] | ||||
Supplemental Statement of Operations Information [Line Items] | ||||
Utility taxes | 29 | 32 | 87 | 92 |
Property | 66 | 70 | 205 | 204 |
Payroll | 28 | 31 | 92 | 99 |
Commonwealth Edison Co [Member] | ||||
Supplemental Statement of Operations Information [Line Items] | ||||
Utility taxes | 66 | 67 | 183 | 188 |
Property | 7 | 7 | 22 | 22 |
Payroll | 7 | 6 | 21 | 20 |
PECO Energy Co [Member] | ||||
Supplemental Statement of Operations Information [Line Items] | ||||
Utility taxes | 38 | 39 | 102 | 102 |
Property | 5 | 4 | 12 | 12 |
Payroll | 3 | 3 | 11 | 11 |
Baltimore Gas and Electric Company [Member] | ||||
Supplemental Statement of Operations Information [Line Items] | ||||
Utility taxes | 21 | 23 | 68 | 70 |
Property | 39 | 37 | 114 | 106 |
Payroll | 4 | 4 | 13 | 12 |
Pepco Holdings LLC [Member] | ||||
Supplemental Statement of Operations Information [Line Items] | ||||
Utility taxes | 86 | 92 | 231 | 253 |
Property | 31 | 26 | 91 | 71 |
Payroll | 6 | 5 | 20 | 19 |
Potomac Electric Power Company [Member] | ||||
Supplemental Statement of Operations Information [Line Items] | ||||
Utility taxes | 81 | 87 | 217 | 238 |
Property | 21 | 16 | 64 | 45 |
Payroll | 2 | 1 | 5 | 5 |
Delmarva Power and Light Company [Member] | ||||
Supplemental Statement of Operations Information [Line Items] | ||||
Utility taxes | 5 | 5 | 14 | 15 |
Property | 9 | 9 | 25 | 24 |
Payroll | 1 | 1 | 3 | 3 |
Atlantic City Electric Company [Member] | ||||
Supplemental Statement of Operations Information [Line Items] | ||||
Utility taxes | 0 | 0 | 0 | 0 |
Property | 0 | 0 | 2 | 2 |
Payroll | $ 1 | $ 1 | $ 2 | $ 2 |
Supplemental Financial Inform_4
Supplemental Financial Information - Operations (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2019 | Sep. 30, 2018 | |
Decommissioning-Related Activities [Abstract] | ||||
Net realized income on NDT funds - Regulatory agreement units | $ 67 | $ 214 | $ 197 | $ 476 |
Net realized income on NDT funds - Non-regulatory agreement units | 33 | 58 | 316 | 257 |
Net unrealized (losses) gains on NDT funds - Regulatory agreement units | 89 | (66) | 565 | (335) |
Net unrealized (losses) gains on NDT funds - Non-regulatory agreement units | 55 | 72 | 236 | (143) |
Regulatory offset to NDT fund-related activities | (125) | (110) | (611) | (110) |
Decommissioning-related activities | 119 | 168 | 703 | 145 |
AFUDC - Equity | 22 | 16 | 64 | 47 |
Non-service net periodic benefit cost | (2) | (12) | 8 | (33) |
Exelon Generation Co L L C [Member] | ||||
Decommissioning-Related Activities [Abstract] | ||||
Net realized income on NDT funds - Regulatory agreement units | 67 | 214 | 197 | 476 |
Net realized income on NDT funds - Non-regulatory agreement units | 33 | 58 | 316 | 257 |
Net unrealized (losses) gains on NDT funds - Regulatory agreement units | 89 | (66) | 565 | (335) |
Net unrealized (losses) gains on NDT funds - Non-regulatory agreement units | 55 | 72 | 236 | (143) |
Regulatory offset to NDT fund-related activities | (125) | (110) | (611) | (110) |
Decommissioning-related activities | 119 | 168 | 703 | 145 |
AFUDC - Equity | 0 | 0 | 0 | 0 |
Commonwealth Edison Co [Member] | ||||
Decommissioning-Related Activities [Abstract] | ||||
AFUDC - Equity | 4 | 4 | 13 | 12 |
PECO Energy Co [Member] | ||||
Decommissioning-Related Activities [Abstract] | ||||
AFUDC - Equity | 3 | 1 | 9 | 3 |
Baltimore Gas and Electric Company [Member] | ||||
Decommissioning-Related Activities [Abstract] | ||||
AFUDC - Equity | 6 | 5 | 16 | 13 |
Pepco Holdings LLC [Member] | ||||
Decommissioning-Related Activities [Abstract] | ||||
AFUDC - Equity | 9 | 6 | 26 | 19 |
Potomac Electric Power Company [Member] | ||||
Decommissioning-Related Activities [Abstract] | ||||
AFUDC - Equity | 7 | 6 | 18 | 17 |
Delmarva Power and Light Company [Member] | ||||
Decommissioning-Related Activities [Abstract] | ||||
AFUDC - Equity | 1 | 0 | 3 | 2 |
Atlantic City Electric Company [Member] | ||||
Decommissioning-Related Activities [Abstract] | ||||
AFUDC - Equity | $ 1 | $ 0 | $ 4 | $ 0 |
Supplemental Financial Inform_5
Supplemental Financial Information - Cash Flow (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2019 | Mar. 31, 2019 | Sep. 30, 2019 | Sep. 30, 2018 | |
Depreciation, Amortization and Accretion [Abstract] | ||||
Property, plant and equipment | $ 2,803 | $ 2,829 | ||
Amortization of regulatory assets | 390 | 412 | ||
Amortization of intangible assets, net | 44 | 43 | ||
Amortization of energy contract assets and liabilities | 14 | 8 | ||
Nuclear fuel | 771 | 852 | ||
ARO accretion | 371 | 367 | ||
Total depreciation, amortization and accretion | 4,393 | 4,511 | ||
Other Non-Cash Operating Activities [Abstract] | ||||
Pension and non-pension postretirement benefit costs | 324 | 435 | ||
Provision for uncollectible accounts | 89 | 133 | ||
Other decommissioning-related activity | (400) | (39) | ||
Energy-related options | 21 | 4 | ||
Amortization of rate stabilization deferral | (8) | 0 | ||
Discrete impacts from EIMA and FEJA | 80 | 27 | ||
Long-term incentive plan | 33 | 84 | ||
Amortization of operating ROU asset | 193 | |||
Change in environmental liabilities | 23 | |||
Asset retirement costs | $ (300) | $ 330 | 20 | |
Exelon Generation Co L L C [Member] | ||||
Depreciation, Amortization and Accretion [Abstract] | ||||
Property, plant and equipment | 1,184 | 1,347 | ||
Amortization of regulatory assets | 0 | 0 | ||
Amortization of intangible assets, net | 37 | 36 | ||
Amortization of energy contract assets and liabilities | 14 | 8 | ||
Nuclear fuel | 771 | 852 | ||
ARO accretion | 371 | 365 | ||
Total depreciation, amortization and accretion | 2,377 | 2,608 | ||
Other Non-Cash Operating Activities [Abstract] | ||||
Pension and non-pension postretirement benefit costs | 98 | 151 | ||
Provision for uncollectible accounts | 20 | 38 | ||
Other decommissioning-related activity | (400) | (39) | ||
Energy-related options | 21 | 4 | ||
Amortization of rate stabilization deferral | 0 | 0 | ||
Amortization of operating ROU asset | 138 | |||
Change in environmental liabilities | 0 | |||
Asset retirement costs | $ (300) | $ 330 | 0 | |
Commonwealth Edison Co [Member] | ||||
Depreciation, Amortization and Accretion [Abstract] | ||||
Property, plant and equipment | 661 | 613 | ||
Amortization of regulatory assets | 106 | 83 | ||
Amortization of intangible assets, net | 0 | 0 | ||
ARO accretion | 0 | 0 | ||
Total depreciation, amortization and accretion | 767 | 696 | ||
Other Non-Cash Operating Activities [Abstract] | ||||
Pension and non-pension postretirement benefit costs | 70 | 133 | ||
Provision for uncollectible accounts | 26 | 30 | ||
Amortization of rate stabilization deferral | 0 | 0 | ||
Discrete impacts from EIMA and FEJA | 80 | 27 | ||
Amortization of operating ROU asset | 2 | |||
Change in environmental liabilities | 0 | |||
Asset retirement costs | 0 | |||
PECO Energy Co [Member] | ||||
Depreciation, Amortization and Accretion [Abstract] | ||||
Property, plant and equipment | 225 | 204 | ||
Amortization of regulatory assets | 22 | 20 | ||
Amortization of intangible assets, net | 0 | 0 | ||
ARO accretion | 0 | 0 | ||
Total depreciation, amortization and accretion | 247 | 224 | ||
Other Non-Cash Operating Activities [Abstract] | ||||
Pension and non-pension postretirement benefit costs | 9 | 14 | ||
Provision for uncollectible accounts | 22 | 25 | ||
Amortization of rate stabilization deferral | 0 | 0 | ||
Amortization of operating ROU asset | 0 | |||
Change in environmental liabilities | 0 | |||
Asset retirement costs | 0 | |||
Baltimore Gas and Electric Company [Member] | ||||
Depreciation, Amortization and Accretion [Abstract] | ||||
Property, plant and equipment | 263 | 249 | ||
Amortization of regulatory assets | 105 | 109 | ||
Amortization of intangible assets, net | 0 | 0 | ||
ARO accretion | 0 | 0 | ||
Total depreciation, amortization and accretion | 368 | 358 | ||
Other Non-Cash Operating Activities [Abstract] | ||||
Pension and non-pension postretirement benefit costs | 45 | 43 | ||
Provision for uncollectible accounts | 5 | 6 | ||
Amortization of rate stabilization deferral | 0 | 0 | ||
Amortization of operating ROU asset | 23 | |||
Change in environmental liabilities | 0 | |||
Asset retirement costs | 0 | |||
Pepco Holdings LLC [Member] | ||||
Depreciation, Amortization and Accretion [Abstract] | ||||
Property, plant and equipment | 405 | 355 | ||
Amortization of regulatory assets | 157 | 200 | ||
Amortization of intangible assets, net | 0 | 0 | ||
ARO accretion | 0 | 0 | ||
Total depreciation, amortization and accretion | 562 | 555 | ||
Other Non-Cash Operating Activities [Abstract] | ||||
Pension and non-pension postretirement benefit costs | 71 | 51 | ||
Provision for uncollectible accounts | 16 | 32 | ||
Amortization of rate stabilization deferral | (8) | 0 | ||
Amortization of operating ROU asset | 26 | |||
Change in environmental liabilities | 23 | |||
Asset retirement costs | 20 | |||
Potomac Electric Power Company [Member] | ||||
Depreciation, Amortization and Accretion [Abstract] | ||||
Property, plant and equipment | 178 | 161 | ||
Amortization of regulatory assets | 103 | 125 | ||
Amortization of intangible assets, net | 0 | 0 | ||
ARO accretion | 0 | 0 | ||
Total depreciation, amortization and accretion | 281 | 286 | ||
Other Non-Cash Operating Activities [Abstract] | ||||
Pension and non-pension postretirement benefit costs | 19 | 10 | ||
Provision for uncollectible accounts | 7 | 12 | ||
Amortization of rate stabilization deferral | (9) | 0 | ||
Amortization of operating ROU asset | 6 | |||
Change in environmental liabilities | 23 | |||
Asset retirement costs | 22 | |||
Delmarva Power and Light Company [Member] | ||||
Depreciation, Amortization and Accretion [Abstract] | ||||
Property, plant and equipment | 109 | 97 | ||
Amortization of regulatory assets | 29 | 38 | ||
Amortization of intangible assets, net | 0 | 0 | ||
ARO accretion | 0 | 0 | ||
Total depreciation, amortization and accretion | 138 | 135 | ||
Other Non-Cash Operating Activities [Abstract] | ||||
Pension and non-pension postretirement benefit costs | 11 | 5 | ||
Provision for uncollectible accounts | 2 | 6 | ||
Amortization of rate stabilization deferral | 1 | 0 | ||
Amortization of operating ROU asset | 7 | |||
Change in environmental liabilities | 0 | |||
Asset retirement costs | (1) | |||
Atlantic City Electric Company [Member] | ||||
Depreciation, Amortization and Accretion [Abstract] | ||||
Property, plant and equipment | 89 | 70 | ||
Amortization of regulatory assets | 25 | 37 | ||
Amortization of intangible assets, net | 0 | 0 | ||
ARO accretion | 0 | 0 | ||
Total depreciation, amortization and accretion | 114 | 107 | ||
Other Non-Cash Operating Activities [Abstract] | ||||
Pension and non-pension postretirement benefit costs | 12 | 10 | ||
Provision for uncollectible accounts | 6 | 14 | ||
Amortization of rate stabilization deferral | 0 | 0 | ||
Amortization of operating ROU asset | 4 | |||
Change in environmental liabilities | $ 0 | |||
Asset retirement costs | $ (1) |
Supplemental Financial Inform_6
Supplemental Financial Information - Balance Sheet (Details) - USD ($) $ in Millions | Sep. 30, 2019 | Dec. 31, 2018 | Sep. 30, 2018 | Dec. 31, 2017 |
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract] | ||||
Cash and cash equivalents | $ 1,683 | $ 1,349 | $ 1,918 | $ 898 |
Restricted cash | 309 | 247 | 240 | 207 |
Restricted cash included in other long-term assets | 186 | 185 | 163 | 85 |
Total cash, cash equivalents and restricted cash | 2,178 | 1,781 | 2,321 | 1,190 |
Receivables [Abstract] | ||||
Unbilled customer revenues | 1,256 | 1,656 | ||
Accrued Expenses [Abstract] | ||||
Compensation-related accruals | 880 | 1,191 | ||
Taxes accrued | 431 | 412 | ||
Interest accrued | 421 | 334 | ||
Exelon Generation Co L L C [Member] | ||||
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract] | ||||
Cash and cash equivalents | 1,019 | 750 | 1,187 | 416 |
Restricted cash | 126 | 153 | 152 | 138 |
Restricted cash included in other long-term assets | 0 | 0 | 0 | 0 |
Total cash, cash equivalents and restricted cash | 1,145 | 903 | 1,339 | 554 |
Receivables [Abstract] | ||||
Unbilled customer revenues | 676 | 965 | ||
Accrued Expenses [Abstract] | ||||
Compensation-related accruals | 336 | 479 | ||
Taxes accrued | 247 | 226 | ||
Interest accrued | 106 | 77 | ||
Commonwealth Edison Co [Member] | ||||
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract] | ||||
Cash and cash equivalents | 76 | 135 | 124 | 76 |
Restricted cash | 124 | 29 | 12 | 5 |
Restricted cash included in other long-term assets | 171 | 166 | 144 | 63 |
Total cash, cash equivalents and restricted cash | 371 | 330 | 280 | 144 |
Receivables [Abstract] | ||||
Unbilled customer revenues | 212 | 223 | ||
Accrued Expenses [Abstract] | ||||
Compensation-related accruals | 133 | 187 | ||
Taxes accrued | 56 | 71 | ||
Interest accrued | 62 | 105 | ||
PECO Energy Co [Member] | ||||
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract] | ||||
Cash and cash equivalents | 224 | 130 | 102 | 271 |
Restricted cash | 6 | 5 | 5 | 4 |
Restricted cash included in other long-term assets | 0 | 0 | 0 | 0 |
Total cash, cash equivalents and restricted cash | 230 | 135 | 107 | 275 |
Receivables [Abstract] | ||||
Unbilled customer revenues | 102 | 114 | ||
Accrued Expenses [Abstract] | ||||
Compensation-related accruals | 48 | 49 | ||
Taxes accrued | 13 | 28 | ||
Interest accrued | 33 | 33 | ||
Baltimore Gas and Electric Company [Member] | ||||
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract] | ||||
Cash and cash equivalents | 130 | 7 | 113 | 17 |
Restricted cash | 1 | 6 | 3 | 1 |
Restricted cash included in other long-term assets | 0 | 0 | 0 | 0 |
Total cash, cash equivalents and restricted cash | 131 | 13 | 116 | 18 |
Receivables [Abstract] | ||||
Unbilled customer revenues | 103 | 168 | ||
Accrued Expenses [Abstract] | ||||
Compensation-related accruals | 63 | 68 | ||
Taxes accrued | 64 | 46 | ||
Interest accrued | 36 | 39 | ||
Pepco Holdings LLC [Member] | ||||
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract] | ||||
Cash and cash equivalents | 99 | 124 | 153 | 30 |
Restricted cash | 38 | 43 | 42 | 42 |
Restricted cash included in other long-term assets | 15 | 19 | 19 | 23 |
Total cash, cash equivalents and restricted cash | 152 | 186 | 214 | 95 |
Receivables [Abstract] | ||||
Unbilled customer revenues | 163 | 186 | ||
Accrued Expenses [Abstract] | ||||
Compensation-related accruals | 86 | 99 | ||
Taxes accrued | 80 | 74 | ||
Interest accrued | 78 | 50 | ||
Potomac Electric Power Company [Member] | ||||
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract] | ||||
Cash and cash equivalents | 18 | 16 | 12 | 5 |
Restricted cash | 34 | 37 | 35 | 35 |
Restricted cash included in other long-term assets | 0 | 0 | 0 | 0 |
Total cash, cash equivalents and restricted cash | 52 | 53 | 47 | 40 |
Receivables [Abstract] | ||||
Unbilled customer revenues | 91 | 97 | ||
Accrued Expenses [Abstract] | ||||
Compensation-related accruals | 26 | 29 | ||
Taxes accrued | 61 | 58 | ||
Interest accrued | 37 | 25 | ||
Delmarva Power and Light Company [Member] | ||||
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract] | ||||
Cash and cash equivalents | 11 | 23 | 110 | 2 |
Restricted cash | 0 | 1 | 0 | 0 |
Restricted cash included in other long-term assets | 0 | 0 | 0 | 0 |
Total cash, cash equivalents and restricted cash | 11 | 24 | 110 | 2 |
Receivables [Abstract] | ||||
Unbilled customer revenues | 38 | 59 | ||
Accrued Expenses [Abstract] | ||||
Compensation-related accruals | 17 | 19 | ||
Taxes accrued | 17 | 4 | ||
Interest accrued | 20 | 8 | ||
Atlantic City Electric Company [Member] | ||||
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract] | ||||
Cash and cash equivalents | 13 | 7 | 11 | 2 |
Restricted cash | 3 | 4 | 7 | 6 |
Restricted cash included in other long-term assets | 15 | 19 | 19 | 23 |
Total cash, cash equivalents and restricted cash | 31 | 30 | $ 37 | $ 31 |
Receivables [Abstract] | ||||
Unbilled customer revenues | 34 | 30 | ||
Accrued Expenses [Abstract] | ||||
Compensation-related accruals | 13 | 12 | ||
Taxes accrued | 3 | 5 | ||
Interest accrued | $ 19 | $ 12 |
Segment Information - Narrative
Segment Information - Narrative (Details) | 9 Months Ended |
Sep. 30, 2019Reportable_segment | |
Segment Reporting Information [Line Items] | |
Number of reportable segments | 11 |
Exelon Generation Co L L C [Member] | |
Segment Reporting Information [Line Items] | |
Number of reportable segments | 5 |
Pepco Holdings LLC [Member] | |
Segment Reporting Information [Line Items] | |
Number of reportable segments | 3 |
Segment Information - Reconcili
Segment Information - Reconciliation to Consolidated Financial Statements (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||||||||
Sep. 30, 2019 | Jun. 30, 2019 | Mar. 31, 2019 | Sep. 30, 2018 | Jun. 30, 2018 | Mar. 31, 2018 | Sep. 30, 2019 | Sep. 30, 2018 | Dec. 31, 2018 | ||
Segment Reporting Information [Line Items] | ||||||||||
Revenues | $ 8,929 | $ 9,403 | $ 26,096 | $ 27,170 | ||||||
Operating revenues from affiliates | 0 | 0 | 0 | 0 | ||||||
Depreciation, Depletion and Amortization | 1,083 | 1,105 | 3,237 | 3,284 | ||||||
Operating Expenses | 7,559 | 8,252 | 22,703 | 24,036 | ||||||
Interest Revenue (Expense), Net | 409 | 393 | 1,221 | 1,138 | ||||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | 1,102 | 947 | 3,028 | 2,263 | ||||||
Income taxes | 172 | 137 | 626 | 262 | ||||||
Net income (loss) | 760 | $ 494 | $ 966 | 800 | $ 542 | $ 636 | 2,220 | 1,979 | ||
Payments to Acquire Property, Plant, and Equipment | 1,687 | 1,690 | 5,259 | 5,497 | ||||||
Assets | [1] | 122,738 | 122,738 | $ 119,666 | ||||||
Pepco Holdings LLC [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenues | 1,380 | 1,361 | 3,700 | 3,688 | ||||||
Operating revenues from affiliates | 4 | 3 | 11 | 11 | ||||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | 203 | 191 | 436 | 363 | ||||||
Income taxes | 14 | 4 | 25 | 28 | ||||||
Net income (loss) | 189 | 106 | 117 | 187 | 84 | 65 | 412 | 336 | ||
Payments to Acquire Property, Plant, and Equipment | 1,006 | 988 | ||||||||
Assets | [2] | 22,576 | 22,576 | 21,984 | ||||||
Exelon Generation Co L L C [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenues | 4,774 | 5,278 | 14,280 | 15,368 | ||||||
Operating revenues from affiliates | 275 | 308 | 844 | 979 | ||||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | 501 | 389 | 1,355 | 800 | ||||||
Income taxes | 87 | 78 | 388 | 110 | ||||||
Net income (loss) | 244 | $ 118 | $ 422 | 300 | $ 181 | $ 186 | 784 | 667 | ||
Payments to Acquire Property, Plant, and Equipment | 1,282 | 1,660 | ||||||||
Assets | [3] | 47,984 | 47,984 | 47,556 | ||||||
Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Competitive businesses other revenues | 194 | 139 | 432 | 335 | ||||||
Revenues | 8,929 | 9,403 | 26,096 | 27,170 | ||||||
Net income (loss) | 760 | 800 | 2,220 | 1,979 | ||||||
Assets | 122,738 | 122,738 | 119,666 | |||||||
Operating Segments [Member] | Pepco Holdings LLC [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | (9) | (5) | 4 | 7 | ||||||
Intersegment Eliminations [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Competitive businesses other revenues | (1) | (1) | (4) | (4) | ||||||
Revenues | (763) | (780) | (2,296) | (2,436) | ||||||
Operating revenues from affiliates | (764) | (779) | (2,300) | (2,430) | ||||||
Depreciation, Depletion and Amortization | 0 | 0 | 0 | 0 | ||||||
Operating Expenses | (759) | (790) | (2,291) | (2,467) | ||||||
Interest Revenue (Expense), Net | 0 | 0 | 0 | 0 | ||||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | 0 | 0 | 0 | 0 | ||||||
Income taxes | 0 | 0 | 0 | 0 | ||||||
Net income (loss) | 0 | 0 | 0 | 0 | ||||||
Payments to Acquire Property, Plant, and Equipment | 0 | 0 | 0 | 0 | ||||||
Assets | (10,085) | (10,085) | (9,800) | |||||||
Intersegment Eliminations [Member] | Pepco Holdings LLC [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenues | (92) | (104) | (298) | (328) | ||||||
Operating revenues from affiliates | (93) | (105) | (298) | (327) | ||||||
Depreciation, Depletion and Amortization | 0 | 0 | 0 | 0 | ||||||
Operating Expenses | (94) | (104) | (298) | (324) | ||||||
Interest Revenue (Expense), Net | 0 | 0 | 0 | 0 | ||||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | (195) | (182) | (422) | (339) | ||||||
Income taxes | (1) | 1 | (1) | 0 | ||||||
Net income (loss) | 4 | 3 | 11 | 11 | ||||||
Payments to Acquire Property, Plant, and Equipment | 0 | 0 | 0 | 0 | ||||||
Assets | (5,738) | (5,738) | (5,421) | |||||||
Exelon Generation Co L L C [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Competitive businesses other revenues | 195 | 140 | 436 | 339 | ||||||
Revenues | 4,774 | 5,278 | 14,280 | 15,368 | ||||||
Depreciation, Depletion and Amortization | 407 | 468 | 1,221 | 1,383 | ||||||
Operating Expenses | 4,274 | 4,961 | 13,333 | 14,475 | ||||||
Interest Revenue (Expense), Net | 109 | 101 | 336 | 305 | ||||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | 501 | 389 | 1,355 | 800 | ||||||
Income taxes | 87 | 78 | 388 | 110 | ||||||
Net income (loss) | 244 | 300 | 784 | 667 | ||||||
Payments to Acquire Property, Plant, and Equipment | 392 | 362 | 1,282 | 1,660 | ||||||
Assets | 47,984 | 47,984 | 47,556 | |||||||
Exelon Generation Co L L C [Member] | Intersegment Eliminations [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Operating revenues from affiliates | 275 | 308 | 844 | 981 | ||||||
Commonwealth Edison Co [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Competitive businesses other revenues | 0 | 0 | 0 | 0 | ||||||
Revenues | 1,583 | 1,598 | 4,342 | 4,508 | ||||||
Depreciation, Depletion and Amortization | 259 | 237 | 767 | 696 | ||||||
Operating Expenses | 1,256 | 1,275 | 3,431 | 3,610 | ||||||
Interest Revenue (Expense), Net | 91 | 85 | 268 | 261 | ||||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | 245 | 245 | 674 | 663 | ||||||
Income taxes | 45 | 52 | 130 | 140 | ||||||
Net income (loss) | 200 | 193 | 544 | 523 | ||||||
Payments to Acquire Property, Plant, and Equipment | 452 | 514 | 1,413 | 1,540 | ||||||
Assets | 32,326 | 32,326 | 31,213 | |||||||
Commonwealth Edison Co [Member] | Intersegment Eliminations [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Operating revenues from affiliates | 4 | 4 | 13 | 23 | ||||||
PECO Energy Co [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Competitive businesses other revenues | 0 | 0 | 0 | 0 | ||||||
Revenues | 778 | 757 | 2,333 | 2,275 | ||||||
Depreciation, Depletion and Amortization | 83 | 75 | 247 | 224 | ||||||
Operating Expenses | 595 | 603 | 1,783 | 1,853 | ||||||
Interest Revenue (Expense), Net | 33 | 32 | 100 | 96 | ||||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | 154 | 124 | 461 | 331 | ||||||
Income taxes | 14 | (2) | 51 | (5) | ||||||
Net income (loss) | 140 | 126 | 410 | 336 | ||||||
Payments to Acquire Property, Plant, and Equipment | 228 | 204 | 675 | 615 | ||||||
Assets | 11,379 | 11,379 | 10,642 | |||||||
PECO Energy Co [Member] | Intersegment Eliminations [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Operating revenues from affiliates | 1 | 2 | 4 | 5 | ||||||
Baltimore Gas and Electric Company [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Competitive businesses other revenues | 0 | 0 | 0 | 0 | ||||||
Revenues | 703 | 731 | 2,327 | 2,369 | ||||||
Depreciation, Depletion and Amortization | 116 | 110 | 368 | 358 | ||||||
Operating Expenses | 612 | 628 | 1,936 | 2,005 | ||||||
Interest Revenue (Expense), Net | 31 | 27 | 89 | 78 | ||||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | 67 | 81 | 320 | 301 | ||||||
Income taxes | 12 | 18 | 59 | 59 | ||||||
Net income (loss) | 55 | 63 | 261 | 242 | ||||||
Payments to Acquire Property, Plant, and Equipment | 300 | 233 | 842 | 667 | ||||||
Assets | 10,304 | 10,304 | 9,716 | |||||||
Baltimore Gas and Electric Company [Member] | Intersegment Eliminations [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Operating revenues from affiliates | 6 | 6 | 18 | 18 | ||||||
Pepco Holdings LLC [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Competitive businesses other revenues | 0 | 0 | 0 | 0 | ||||||
Revenues | 1,380 | 1,361 | 3,700 | 3,688 | ||||||
Depreciation, Depletion and Amortization | 193 | 192 | 562 | 555 | ||||||
Operating Expenses | 1,124 | 1,116 | 3,106 | 3,165 | ||||||
Interest Revenue (Expense), Net | 66 | 65 | 197 | 193 | ||||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | 203 | 191 | 436 | 363 | ||||||
Income taxes | 14 | 4 | 25 | 28 | ||||||
Net income (loss) | 189 | 187 | 412 | 336 | ||||||
Payments to Acquire Property, Plant, and Equipment | 308 | 359 | 1,006 | 988 | ||||||
Assets | 22,576 | 22,576 | 21,984 | |||||||
Pepco Holdings LLC [Member] | Intersegment Eliminations [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Operating revenues from affiliates | 4 | 3 | 11 | 11 | ||||||
Potomac Electric Power Company [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenues | 642 | 628 | 1,748 | 1,708 | ||||||
Depreciation, Depletion and Amortization | 95 | 99 | 281 | 286 | ||||||
Operating Expenses | 515 | 516 | 1,444 | 1,454 | ||||||
Interest Revenue (Expense), Net | 33 | 32 | 100 | 96 | ||||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | 103 | 87 | 226 | 181 | ||||||
Income taxes | 5 | (2) | 9 | 7 | ||||||
Net income (loss) | 98 | 89 | 217 | 174 | ||||||
Payments to Acquire Property, Plant, and Equipment | 157 | 188 | 455 | 475 | ||||||
Assets | 8,603 | 8,603 | 8,299 | |||||||
Potomac Electric Power Company [Member] | Intersegment Eliminations [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Operating revenues from affiliates | 2 | 2 | 5 | 5 | ||||||
Delmarva Power and Light Company [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenues | 319 | 328 | 987 | 1,001 | ||||||
Depreciation, Depletion and Amortization | 46 | 47 | 138 | 135 | ||||||
Operating Expenses | 268 | 277 | 820 | 859 | ||||||
Interest Revenue (Expense), Net | 15 | 15 | 45 | 42 | ||||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | 38 | 38 | 132 | 107 | ||||||
Income taxes | 5 | 5 | 16 | 17 | ||||||
Net income (loss) | 33 | 33 | 116 | 90 | ||||||
Payments to Acquire Property, Plant, and Equipment | 85 | 88 | 245 | 254 | ||||||
Assets | 4,724 | 4,724 | 4,588 | |||||||
Delmarva Power and Light Company [Member] | Intersegment Eliminations [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Operating revenues from affiliates | 1 | 2 | 5 | 6 | ||||||
Atlantic City Electric Company [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenues | 419 | 406 | 966 | 981 | ||||||
Depreciation, Depletion and Amortization | 43 | 38 | 114 | 107 | ||||||
Operating Expenses | 340 | 322 | 838 | 847 | ||||||
Interest Revenue (Expense), Net | 15 | 16 | 44 | 48 | ||||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | 65 | 69 | 89 | 88 | ||||||
Income taxes | 2 | 8 | 2 | 12 | ||||||
Net income (loss) | 63 | 61 | 87 | 76 | ||||||
Payments to Acquire Property, Plant, and Equipment | 73 | 77 | 300 | 247 | ||||||
Assets | 3,916 | 3,916 | 3,699 | |||||||
Atlantic City Electric Company [Member] | Intersegment Eliminations [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Operating revenues from affiliates | 1 | 1 | 2 | 2 | ||||||
Corporate and Other [Member] | Corporate, Non-Segment [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Competitive businesses other revenues | 0 | 0 | 0 | 0 | ||||||
Revenues | 474 | 458 | 1,410 | 1,398 | ||||||
Depreciation, Depletion and Amortization | 25 | 23 | 72 | 68 | ||||||
Operating Expenses | 457 | 459 | 1,405 | 1,395 | ||||||
Interest Revenue (Expense), Net | 79 | 83 | 231 | 205 | ||||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | (68) | (83) | (218) | (195) | ||||||
Income taxes | 0 | (13) | (27) | (70) | ||||||
Net income (loss) | (68) | (69) | (191) | (125) | ||||||
Payments to Acquire Property, Plant, and Equipment | 7 | 18 | 41 | 27 | ||||||
Assets | 8,254 | 8,254 | 8,355 | |||||||
Corporate and Other [Member] | Corporate, Non-Segment [Member] | Pepco Holdings LLC [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenues | 92 | 103 | 297 | 326 | ||||||
Depreciation, Depletion and Amortization | 9 | 8 | 29 | 27 | ||||||
Operating Expenses | 95 | 105 | 302 | 329 | ||||||
Interest Revenue (Expense), Net | 3 | 2 | 8 | 7 | ||||||
Income (Loss) from Continuing Operations before Income Taxes, Noncontrolling Interest | 192 | 179 | 411 | 326 | ||||||
Income taxes | 3 | (8) | (1) | (8) | ||||||
Net income (loss) | (9) | 1 | (19) | (15) | ||||||
Payments to Acquire Property, Plant, and Equipment | (7) | 6 | 6 | 12 | ||||||
Assets | 11,071 | 11,071 | $ 10,819 | |||||||
Corporate and Other [Member] | Intersegment Eliminations [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Operating revenues from affiliates | 474 | 456 | 1,410 | 1,392 | ||||||
Corporate and Other [Member] | Intersegment Eliminations [Member] | Pepco Holdings LLC [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Operating revenues from affiliates | 93 | 103 | 297 | 325 | ||||||
Generation Mid Atlantic [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenues | 1,364 | 1,456 | 3,809 | 4,179 | ||||||
Generation Mid Atlantic [Member] | PECO Energy Co Affiliate [Member] | Exelon Generation Co L L C [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Operating revenues from affiliates | 43 | 35 | 123 | 97 | ||||||
Generation Mid Atlantic [Member] | Baltimore Gas And Electric Company Affiliate [Member] | Exelon Generation Co L L C [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Operating revenues from affiliates | 65 | 69 | 199 | 198 | ||||||
Generation Mid Atlantic [Member] | PotomacElectricPowerCompanyAffiliate [Member] | Exelon Generation Co L L C [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Operating revenues from affiliates | 65 | 46 | 188 | 143 | ||||||
Generation Mid Atlantic [Member] | DelmarvaPowerandLightCompanyAffiliate [Member] | Exelon Generation Co L L C [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Operating revenues from affiliates | 14 | 26 | 50 | 103 | ||||||
Generation Mid Atlantic [Member] | AtlanticCityElectricCompanyAffiliate [Member] | Exelon Generation Co L L C [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Operating revenues from affiliates | 3 | 10 | 16 | 21 | ||||||
Generation Mid Atlantic [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenues | 1,361 | 1,449 | 3,807 | 4,162 | ||||||
Generation Mid Atlantic [Member] | Intersegment Eliminations [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Operating revenues from affiliates | 3 | 7 | 2 | 17 | ||||||
Generation Midwest [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenues | 1,082 | 1,117 | 3,224 | 3,593 | ||||||
Generation Midwest [Member] | Commonwealth Edison Co Affiliate [Member] | Exelon Generation Co L L C [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Operating revenues from affiliates | 83 | 122 | 266 | 419 | ||||||
Generation Midwest [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenues | 1,099 | 1,121 | 3,255 | 3,601 | ||||||
Generation Midwest [Member] | Intersegment Eliminations [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Operating revenues from affiliates | (17) | (4) | (31) | (8) | ||||||
Oil and Gas, Purchased [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 266 | 397 | 1,479 | 1,831 | ||||||
Oil and Gas, Purchased [Member] | Intersegment Eliminations [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 1 | 0 | 0 | (8) | ||||||
Oil and Gas, Purchased [Member] | Exelon Generation Co L L C [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 265 | 397 | 1,479 | 1,839 | ||||||
Oil and Gas, Purchased [Member] | Commonwealth Edison Co [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Oil and Gas, Purchased [Member] | PECO Energy Co [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Oil and Gas, Purchased [Member] | Baltimore Gas and Electric Company [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Oil and Gas, Purchased [Member] | Pepco Holdings LLC [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Oil and Gas, Purchased [Member] | Corporate and Other [Member] | Corporate, Non-Segment [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Electricity, US Regulated | Pepco Holdings LLC [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 1,365 | 1,340 | 3,570 | 3,541 | ||||||
Electricity, US Regulated | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 4,268 | 4,270 | 11,609 | 11,766 | ||||||
Electricity, US Regulated | Intersegment Eliminations [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | (7) | (7) | (25) | (34) | ||||||
Electricity, US Regulated | Intersegment Eliminations [Member] | Pepco Holdings LLC [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | (3) | (4) | (10) | (12) | ||||||
Electricity, US Regulated | Exelon Generation Co L L C [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Electricity, US Regulated | Commonwealth Edison Co [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 1,583 | 1,598 | 4,342 | 4,508 | ||||||
Electricity, US Regulated | PECO Energy Co [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 716 | 700 | 1,901 | 1,893 | ||||||
Electricity, US Regulated | Baltimore Gas and Electric Company [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 619 | 645 | 1,817 | 1,850 | ||||||
Electricity, US Regulated | Pepco Holdings LLC [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 1,357 | 1,334 | 3,574 | 3,549 | ||||||
Electricity, US Regulated | Potomac Electric Power Company [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 642 | 628 | 1,748 | 1,708 | ||||||
Electricity, US Regulated | Delmarva Power and Light Company [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 299 | 304 | 871 | 872 | ||||||
Electricity, US Regulated | Atlantic City Electric Company [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 419 | 406 | 966 | 981 | ||||||
Electricity, US Regulated | Corporate and Other [Member] | Corporate, Non-Segment [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Electricity, US Regulated | 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 | (1) | 0 | ||||||
Electricity, Generation [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 4,039 | 4,435 | 11,525 | 12,221 | ||||||
Electricity, Generation [Member] | Intersegment Eliminations [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | (275) | (306) | (840) | (969) | ||||||
Electricity, Generation [Member] | Exelon Generation Co L L C [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 4,314 | 4,741 | 12,365 | 13,190 | ||||||
Electricity, Generation [Member] | Commonwealth Edison Co [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Electricity, Generation [Member] | PECO Energy Co [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Electricity, Generation [Member] | Baltimore Gas and Electric Company [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Electricity, Generation [Member] | Pepco Holdings LLC [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Electricity, Generation [Member] | Corporate and Other [Member] | Corporate, Non-Segment [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Natural Gas, US Regulated | Pepco Holdings LLC [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 20 | 23 | 115 | 129 | ||||||
Natural Gas, US Regulated | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 163 | 162 | 1,046 | 1,017 | ||||||
Natural Gas, US Regulated | Intersegment Eliminations [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | (3) | (5) | (12) | (13) | ||||||
Natural Gas, US Regulated | Intersegment Eliminations [Member] | Pepco Holdings LLC [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Natural Gas, US Regulated | Exelon Generation Co L L C [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Natural Gas, US Regulated | Commonwealth Edison Co [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Natural Gas, US Regulated | PECO Energy Co [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 62 | 57 | 432 | 382 | ||||||
Natural Gas, US Regulated | Baltimore Gas and Electric Company [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 84 | 86 | 510 | 519 | ||||||
Natural Gas, US Regulated | Pepco Holdings LLC [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 20 | 24 | 116 | 129 | ||||||
Natural Gas, US Regulated | Potomac Electric Power Company [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Natural Gas, US Regulated | Delmarva Power and Light Company [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 20 | 24 | 116 | 129 | ||||||
Natural Gas, US Regulated | Atlantic City Electric Company [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Natural Gas, US Regulated | Corporate and Other [Member] | Corporate, Non-Segment [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Natural Gas, US Regulated | 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 | 0 | 0 | ||||||
Service, Other [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | (1) | 0 | 5 | 0 | ||||||
Service, Other [Member] | Intersegment Eliminations [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | (478) | (461) | (1,415) | (1,408) | ||||||
Service, Other [Member] | Intersegment Eliminations [Member] | Pepco Holdings LLC [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | (89) | (100) | (288) | (316) | ||||||
Service, Other [Member] | Exelon Generation Co L L C [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Service, Other [Member] | Commonwealth Edison Co [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Service, Other [Member] | PECO Energy Co [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Service, Other [Member] | Baltimore Gas and Electric Company [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Service, Other [Member] | Pepco Holdings LLC [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 3 | 3 | 10 | 10 | ||||||
Service, Other [Member] | Potomac Electric Power Company [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Service, Other [Member] | Delmarva Power and Light Company [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Service, Other [Member] | Atlantic City Electric Company [Member] | Operating Segments [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 | ||||||
Service, Other [Member] | Corporate and Other [Member] | Corporate, Non-Segment [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 474 | 458 | 1,410 | 1,398 | ||||||
Service, Other [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 | $ 92 | $ 103 | $ 298 | $ 326 | ||||||
[1] | Exelon’s consolidated assets include $9,465 million and $9,667 million at September 30, 2019 and December 31, 2018 , respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Exelon’s consolidated liabilities include $3,517 million and $3,548 million at September 30, 2019 and December 31, 2018 , respectively, of certain VIEs for which the VIE creditors do not have recourse to Exelon. See Note 2 — Variable Interest Entities for additional information. | |||||||||
[2] | PHI’s consolidated total assets include $22 million and $33 million at September 30, 2019 and December 31, 2018 , respectively, of PHI's consolidated VIE that can only be used to settle the liabilities of the VIE. PHI’s consolidated total liabilities include $50 million and $69 million at September 30, 2019 and December 31, 2018 , respectively, of PHI's consolidated VIE for which the VIE creditors do not have recourse to PHI. See Note 2 — Variable Interest Entities for additional information. | |||||||||
[3] | Generation’s consolidated assets include $9,443 million and $9,634 million at September 30, 2019 and December 31, 2018 , respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Generation’s consolidated liabilities include $3,467 million and $3,480 million at September 30, 2019 and December 31, 2018 , respectively, of certain VIEs for which the VIE creditors do not have recourse to Generation. See Note 2 — Variable Interest Entities for additional information. |
Segment Information - Generatio
Segment Information - Generation Total Revenues (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2019 | Sep. 30, 2018 | |
Segment Reporting Information [Line Items] | ||||
Revenues | $ 8,929 | $ 9,403 | $ 26,096 | $ 27,170 |
Operating revenues from affiliates | 0 | 0 | 0 | 0 |
Generation Mid Atlantic [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 1,364 | 1,456 | 3,809 | 4,179 |
Generation Midwest [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 1,082 | 1,117 | 3,224 | 3,593 |
Generation New York [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 429 | 469 | 1,211 | 1,269 |
Generation ERCOT [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 365 | 444 | 805 | 930 |
Generation Other Regions [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 1,040 | 1,212 | 3,254 | 3,114 |
Generation Reportable Segments Total [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 4,280 | 4,698 | 12,303 | 13,085 |
Generation Natural Gas [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 299 | 440 | 1,541 | 1,944 |
Generation All Other Segments [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 195 | 140 | 436 | 339 |
Unrealized Gain (Loss) on Securities | 77 | 6 | 64 | 96 |
Generation Total Consolidated Group [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 4,774 | 5,278 | 14,280 | 15,368 |
Operating Segments [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 8,929 | 9,403 | 26,096 | 27,170 |
Operating Segments [Member] | Generation Mid Atlantic [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 1,361 | 1,449 | 3,807 | 4,162 |
Operating Segments [Member] | Generation Midwest [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 1,099 | 1,121 | 3,255 | 3,601 |
Operating Segments [Member] | Generation New York [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 429 | 469 | 1,211 | 1,268 |
Operating Segments [Member] | Generation ERCOT [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 360 | 445 | 792 | 929 |
Operating Segments [Member] | Generation Other Regions [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 1,065 | 1,257 | 3,300 | 3,230 |
Operating Segments [Member] | Generation Reportable Segments Total [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 4,314 | 4,741 | 12,365 | 13,190 |
Operating Segments [Member] | Generation Natural Gas [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 265 | 397 | 1,479 | 1,839 |
Operating Segments [Member] | Generation All Other Segments [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Unrealized Gain (Loss) on Securities | 17 | 71 | 84 | 104 |
Operating Segments [Member] | Generation Total Consolidated Group [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 4,774 | 5,278 | 14,280 | 15,368 |
Corporate, Non-Segment [Member] | Generation All Other Segments [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 195 | 140 | 436 | 339 |
Intersegment Eliminations [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | (763) | (780) | (2,296) | (2,436) |
Operating revenues from affiliates | (764) | (779) | (2,300) | (2,430) |
Intersegment Eliminations [Member] | Generation Mid Atlantic [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues from affiliates | 3 | 7 | 2 | 17 |
Intersegment Eliminations [Member] | Generation Midwest [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues from affiliates | (17) | (4) | (31) | (8) |
Intersegment Eliminations [Member] | Generation New York [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues from affiliates | 0 | 0 | 0 | 1 |
Intersegment Eliminations [Member] | Generation ERCOT [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues from affiliates | 5 | (1) | 13 | 1 |
Intersegment Eliminations [Member] | Generation Other Regions [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues from affiliates | (25) | (45) | (46) | (116) |
Intersegment Eliminations [Member] | Generation Reportable Segments Total [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues from affiliates | (34) | (43) | (62) | (105) |
Intersegment Eliminations [Member] | Generation Natural Gas [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues from affiliates | 34 | 43 | 62 | 105 |
Intersegment Eliminations [Member] | Generation All Other Segments [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues from affiliates | 0 | 0 | 0 | 0 |
Intersegment Eliminations [Member] | Generation Total Consolidated Group [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Operating revenues from affiliates | 0 | 0 | 0 | 0 |
Revenue from Contract with Customer [Member] | Operating Segments [Member] | Generation Mid Atlantic [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 1,351 | 1,397 | 3,798 | 3,971 |
Revenue from Contract with Customer [Member] | Operating Segments [Member] | Generation Midwest [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 1,052 | 1,095 | 3,083 | 3,432 |
Revenue from Contract with Customer [Member] | Operating Segments [Member] | Generation New York [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 414 | 475 | 1,195 | 1,305 |
Revenue from Contract with Customer [Member] | Operating Segments [Member] | Generation ERCOT [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 288 | 156 | 594 | 470 |
Revenue from Contract with Customer [Member] | Operating Segments [Member] | Generation Other Regions [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 873 | 959 | 2,849 | 2,656 |
Revenue from Contract with Customer [Member] | Operating Segments [Member] | Generation Reportable Segments Total [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 3,978 | 4,082 | 11,519 | 11,834 |
Revenue from Contract with Customer [Member] | Operating Segments [Member] | Generation Natural Gas [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 160 | 200 | 1,041 | 1,016 |
Revenue from Contract with Customer [Member] | Operating Segments [Member] | Generation Total Consolidated Group [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 4,250 | 4,412 | 12,903 | 13,235 |
Revenue from Contract with Customer [Member] | Corporate, Non-Segment [Member] | Generation All Other Segments [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 112 | 130 | 343 | 385 |
Other [Member] | Operating Segments [Member] | Generation Mid Atlantic [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 10 | 52 | 9 | 191 |
Other [Member] | Operating Segments [Member] | Generation Midwest [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 47 | 26 | 172 | 169 |
Other [Member] | Operating Segments [Member] | Generation New York [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 15 | (6) | 16 | (37) |
Other [Member] | Operating Segments [Member] | Generation ERCOT [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 72 | 289 | 198 | 459 |
Other [Member] | Operating Segments [Member] | Generation Other Regions [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 192 | 298 | 451 | 574 |
Other [Member] | Operating Segments [Member] | Generation Reportable Segments Total [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 336 | 659 | 846 | 1,356 |
Other [Member] | Operating Segments [Member] | Generation Natural Gas [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 105 | 197 | 438 | 823 |
Other [Member] | Operating Segments [Member] | Generation Total Consolidated Group [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | 524 | 866 | 1,377 | 2,133 |
Other [Member] | Corporate, Non-Segment [Member] | Generation All Other Segments [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenues | $ 83 | $ 10 | $ 93 | $ (46) |
Segment Information - Generat_2
Segment Information - Generation Total Revenues Net of Purchased Power and Fuel Expense (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2019 | Sep. 30, 2018 | |
Generation Mid Atlantic [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net of Purchase Power And Fuel | $ 689 | $ 763 | $ 2,023 | $ 2,348 |
Generation Midwest [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net of Purchase Power And Fuel | 747 | 768 | 2,247 | 2,400 |
Generation New York [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net of Purchase Power And Fuel | 291 | 292 | 810 | 841 |
Generation ERCOT [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net of Purchase Power And Fuel | 72 | 98 | 225 | 216 |
Generation Other Regions [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net of Purchase Power And Fuel | 184 | 180 | 478 | 607 |
Generation Reportable Segments Total [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net of Purchase Power And Fuel | 1,983 | 2,101 | 5,783 | 6,412 |
Generation All Other Segments [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net of Purchase Power And Fuel | 140 | 197 | 349 | 404 |
Unrealized Gain (Loss) on Securities | 77 | 6 | 64 | 96 |
Generation Total Consolidated Group [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net of Purchase Power And Fuel | 2,123 | 2,298 | 6,132 | 6,816 |
Operating Segments [Member] | Generation Mid Atlantic [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net Of Purchase Power And Fuel From External Customers | 684 | 746 | 2,007 | 2,303 |
Operating Segments [Member] | Generation Midwest [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net Of Purchase Power And Fuel From External Customers | 763 | 763 | 2,269 | 2,381 |
Operating Segments [Member] | Generation New York [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net Of Purchase Power And Fuel From External Customers | 288 | 290 | 800 | 832 |
Operating Segments [Member] | Generation ERCOT [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net Of Purchase Power And Fuel From External Customers | 76 | 161 | 252 | 396 |
Operating Segments [Member] | Generation Other Regions [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net Of Purchase Power And Fuel From External Customers | 212 | 226 | 542 | 740 |
Operating Segments [Member] | Generation Reportable Segments Total [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net Of Purchase Power And Fuel From External Customers | 2,023 | 2,186 | 5,870 | 6,652 |
Operating Segments [Member] | Generation All Other Segments [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net Of Purchase Power And Fuel From External Customers | 100 | 112 | 262 | 164 |
Unrealized Gain (Loss) on Securities | 17 | 71 | 84 | 104 |
Nuclear Fuel Amortization | 3 | 18 | 13 | 53 |
Operating Segments [Member] | Generation Total Consolidated Group [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net Of Purchase Power And Fuel From External Customers | 2,123 | 2,298 | 6,132 | 6,816 |
Intersegment Eliminations [Member] | Generation Mid Atlantic [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment Revenue Net Of Purchase Power And Fuel | 5 | 17 | 16 | 45 |
Intersegment Eliminations [Member] | Generation Midwest [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment Revenue Net Of Purchase Power And Fuel | (16) | 5 | (22) | 19 |
Intersegment Eliminations [Member] | Generation New York [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment Revenue Net Of Purchase Power And Fuel | 3 | 2 | 10 | 9 |
Intersegment Eliminations [Member] | Generation ERCOT [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment Revenue Net Of Purchase Power And Fuel | (4) | (63) | (27) | (180) |
Intersegment Eliminations [Member] | Generation Other Regions [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment Revenue Net Of Purchase Power And Fuel | (28) | (46) | (64) | (133) |
Intersegment Eliminations [Member] | Generation Reportable Segments Total [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment Revenue Net Of Purchase Power And Fuel | (40) | (85) | (87) | (240) |
Intersegment Eliminations [Member] | Generation All Other Segments [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment Revenue Net Of Purchase Power And Fuel | 40 | 85 | 87 | 240 |
Intersegment Eliminations [Member] | Generation Total Consolidated Group [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment Revenue Net Of Purchase Power And Fuel | $ 0 | $ 0 | $ 0 | $ 0 |
Segment Information - Electric
Segment Information - Electric and Gas Revenue by Customer Class (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2019 | Sep. 30, 2018 | Sep. 30, 2019 | Sep. 30, 2018 | |
Revenue, Major Customer [Line Items] | ||||
Revenue from Related Parties | $ 0 | $ 0 | $ 0 | $ 0 |
Revenues | 8,929 | 9,403 | 26,096 | 27,170 |
Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenues | 8,929 | 9,403 | 26,096 | 27,170 |
Commonwealth Edison Co [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Related Parties | 4 | 4 | 13 | 23 |
Revenues | 1,583 | 1,598 | 4,342 | 4,508 |
Commonwealth Edison Co [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | (56) | (15) | (98) | (27) |
Commonwealth Edison Co [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenues | 1,633 | 1,606 | 4,418 | 4,512 |
Commonwealth Edison Co [Member] | Other Regulated Revenue [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenues | (50) | (8) | (76) | (4) |
PECO Energy Co [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Related Parties | 1 | 2 | 4 | 5 |
Revenues | 778 | 757 | 2,333 | 2,275 |
PECO Energy Co [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | (11) | 1 | (16) | 2 |
PECO Energy Co [Member] | Rate-Regulated Electric Revenues [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Related Parties | 1 | 2 | 4 | 5 |
PECO Energy Co [Member] | Rate-Regulated Natural Gas Revenues [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Related Parties | 0 | 0 | 0 | 0 |
PECO Energy Co [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenues | 785 | 753 | 2,338 | 2,263 |
PECO Energy Co [Member] | Other Regulated Revenue [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenues | (7) | 4 | (5) | 12 |
Baltimore Gas and Electric Company [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Related Parties | 6 | 6 | 18 | 18 |
Revenues | 703 | 731 | 2,327 | 2,369 |
Baltimore Gas and Electric Company [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | (5) | (6) | 11 | (23) |
Baltimore Gas and Electric Company [Member] | Rate-Regulated Electric Revenues [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Related Parties | 2 | 1 | 5 | 5 |
Baltimore Gas and Electric Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Related Parties | 4 | 5 | 13 | 0 |
Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenues | 704 | 732 | 2,303 | 2,379 |
Baltimore Gas and Electric Company [Member] | Other Regulated Revenue [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenues | (1) | (1) | 24 | (10) |
Pepco Holdings LLC [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Related Parties | 4 | 3 | 11 | 11 |
Revenues | 1,380 | 1,361 | 3,700 | 3,688 |
Pepco Holdings LLC [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | (9) | (5) | 4 | 7 |
Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Related Parties | 3 | |||
Pepco Holdings LLC [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenues | 1,386 | 1,363 | 3,689 | 3,673 |
Pepco Holdings LLC [Member] | Other Regulated Revenue [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenues | (6) | (2) | 11 | 15 |
Potomac Electric Power Company [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Related Parties | 2 | 2 | 5 | 5 |
Revenues | 642 | 628 | 1,748 | 1,708 |
Potomac Electric Power Company [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | (3) | (4) | 10 | 6 |
Potomac Electric Power Company [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenues | 643 | 630 | 1,732 | 1,697 |
Potomac Electric Power Company [Member] | Other Regulated Revenue [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenues | (1) | (2) | 16 | 11 |
Delmarva Power and Light Company [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Related Parties | 1 | 2 | 5 | 6 |
Revenues | 319 | 328 | 987 | 1,001 |
Delmarva Power and Light Company [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | (6) | 0 | (6) | 5 |
Delmarva Power and Light Company [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenues | 325 | 327 | 991 | 993 |
Delmarva Power and Light Company [Member] | Other Regulated Revenue [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenues | (6) | 1 | (4) | 8 |
Atlantic City Electric Company [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Related Parties | 1 | 1 | 2 | 2 |
Revenues | 419 | 406 | 966 | 981 |
Atlantic City Electric Company [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 1 | (1) | 0 | (4) |
Atlantic City Electric Company [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenues | 418 | 407 | 966 | 985 |
Atlantic City Electric Company [Member] | Other Regulated Revenue [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenues | 1 | (1) | 0 | (4) |
Electricity, US Regulated | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 4,268 | 4,270 | 11,609 | 11,766 |
Electricity, US Regulated | Commonwealth Edison Co [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 1,635 | 1,609 | 4,427 | 4,512 |
Electricity, US Regulated | Commonwealth Edison Co [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 1,633 | 1,606 | 4,418 | 4,512 |
Electricity, US Regulated | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 6 | 7 | 22 | 23 |
Electricity, US Regulated | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Residential [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 865 | 861 | 2,221 | 2,277 |
Electricity, US Regulated | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 393 | 391 | 1,103 | 1,132 |
Electricity, US Regulated | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 141 | 131 | 399 | 411 |
Electricity, US Regulated | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Public Authorities & Electric Railroads [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 12 | 11 | 35 | 36 |
Electricity, US Regulated | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Other [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 222 | 212 | 660 | 656 |
Electricity, US Regulated | PECO Energy Co [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 726 | 697 | 1,914 | 1,886 |
Electricity, US Regulated | PECO Energy Co [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 723 | 696 | 1,907 | 1,881 |
Electricity, US Regulated | PECO Energy Co [Member] | Regulated Operation [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 4 | 3 | 10 | 10 |
Electricity, US Regulated | PECO Energy Co [Member] | Regulated Operation [Member] | Residential [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 479 | 458 | 1,231 | 1,199 |
Electricity, US Regulated | PECO Energy Co [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 109 | 108 | 304 | 306 |
Electricity, US Regulated | PECO Energy Co [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 63 | 64 | 163 | 174 |
Electricity, US Regulated | PECO Energy Co [Member] | Regulated Operation [Member] | Public Authorities & Electric Railroads [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 9 | 7 | 23 | 21 |
Electricity, US Regulated | PECO Energy Co [Member] | Regulated Operation [Member] | Other [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 63 | 59 | 186 | 181 |
Electricity, US Regulated | Baltimore Gas and Electric Company [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 623 | 652 | 1,814 | 1,847 |
Electricity, US Regulated | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 621 | 649 | 1,809 | 1,842 |
Electricity, US Regulated | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 3 | 4 | 10 | 10 |
Electricity, US Regulated | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Residential [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 352 | 366 | 1,019 | 1,054 |
Electricity, US Regulated | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 64 | 68 | 193 | 196 |
Electricity, US Regulated | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 116 | 117 | 335 | 325 |
Electricity, US Regulated | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Public Authorities & Electric Railroads [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 7 | 7 | 20 | 21 |
Electricity, US Regulated | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Other [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 82 | 91 | 242 | 246 |
Electricity, US Regulated | Pepco Holdings LLC [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 1,365 | 1,340 | 3,570 | 3,541 |
Electricity, US Regulated | Pepco Holdings LLC [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 1,366 | 1,339 | 3,574 | 3,544 |
Electricity, US Regulated | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 3 | 3 | 7 | 8 |
Electricity, US Regulated | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Residential [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 741 | 726 | 1,816 | 1,839 |
Electricity, US Regulated | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 147 | 140 | 387 | 370 |
Electricity, US Regulated | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 297 | 303 | 843 | 845 |
Electricity, US Regulated | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Public Authorities & Electric Railroads [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 17 | 14 | 47 | 44 |
Electricity, US Regulated | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Other [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 164 | 156 | 481 | 446 |
Electricity, US Regulated | Potomac Electric Power Company [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 643 | 630 | 1,733 | 1,697 |
Electricity, US Regulated | Potomac Electric Power Company [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 643 | 630 | 1,732 | 1,697 |
Electricity, US Regulated | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 2 | 2 | 6 | 5 |
Electricity, US Regulated | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Residential [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 311 | 306 | 792 | 792 |
Electricity, US Regulated | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 41 | 39 | 114 | 104 |
Electricity, US Regulated | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 222 | 230 | 633 | 632 |
Electricity, US Regulated | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Public Authorities & Electric Railroads [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 11 | 8 | 27 | 24 |
Electricity, US Regulated | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Other [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 58 | 47 | 166 | 145 |
Electricity, US Regulated | Delmarva Power and Light Company [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 304 | 302 | 872 | 861 |
Electricity, US Regulated | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 305 | 303 | 876 | 864 |
Electricity, US Regulated | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 1 | 1 | 3 |
Electricity, US Regulated | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Residential [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 178 | 180 | 499 | 513 |
Electricity, US Regulated | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 48 | 48 | 141 | 138 |
Electricity, US Regulated | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 26 | 25 | 75 | 74 |
Electricity, US Regulated | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Public Authorities & Electric Railroads [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 3 | 3 | 10 | 10 |
Electricity, US Regulated | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Other [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 50 | 47 | 151 | 129 |
Electricity, US Regulated | Atlantic City Electric Company [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 417 | 406 | 964 | 983 |
Electricity, US Regulated | Atlantic City Electric Company [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 418 | 407 | 966 | 985 |
Electricity, US Regulated | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Electricity, US Regulated | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Residential [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 252 | 240 | 525 | 534 |
Electricity, US Regulated | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 58 | 53 | 132 | 128 |
Electricity, US Regulated | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 49 | 48 | 135 | 139 |
Electricity, US Regulated | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Public Authorities & Electric Railroads [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 3 | 3 | 10 | 10 |
Electricity, US Regulated | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Other [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 56 | 63 | 164 | 174 |
Natural Gas, US Regulated | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 163 | 162 | 1,046 | 1,017 |
Natural Gas, US Regulated | Commonwealth Edison Co [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Residential [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Transportation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Other [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | PECO Energy Co [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 62 | 57 | 431 | 382 |
Natural Gas, US Regulated | PECO Energy Co [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 62 | 57 | 431 | 382 |
Natural Gas, US Regulated | PECO Energy Co [Member] | Regulated Operation [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 1 | 0 |
Natural Gas, US Regulated | PECO Energy Co [Member] | Regulated Operation [Member] | Residential [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 38 | 36 | 285 | 259 |
Natural Gas, US Regulated | PECO Energy Co [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 17 | 15 | 122 | 102 |
Natural Gas, US Regulated | PECO Energy Co [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 1 | 1 |
Natural Gas, US Regulated | PECO Energy Co [Member] | Regulated Operation [Member] | Transportation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 5 | 5 | 18 | 16 |
Natural Gas, US Regulated | PECO Energy Co [Member] | Regulated Operation [Member] | Other [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 2 | 1 | 5 | 4 |
Natural Gas, US Regulated | Baltimore Gas and Electric Company [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 79 | 79 | 484 | 527 |
Natural Gas, US Regulated | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 83 | 83 | 494 | 537 |
Natural Gas, US Regulated | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 1 | 1 | 3 | 3 |
Natural Gas, US Regulated | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Residential [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 49 | 46 | 327 | 345 |
Natural Gas, US Regulated | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 9 | 8 | 55 | 55 |
Natural Gas, US Regulated | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 20 | 17 | 93 | 88 |
Natural Gas, US Regulated | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Transportation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Other [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 5 | 12 | 19 | 49 |
Natural Gas, US Regulated | Pepco Holdings LLC [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 20 | 23 | 115 | 129 |
Natural Gas, US Regulated | Pepco Holdings LLC [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 20 | 24 | 115 | 129 |
Natural Gas, US Regulated | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Residential [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 9 | 8 | 64 | 68 |
Natural Gas, US Regulated | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 4 | 5 | 30 | 31 |
Natural Gas, US Regulated | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 1 | 2 | 4 | 7 |
Natural Gas, US Regulated | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Transportation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 4 | 3 | 11 | 12 |
Natural Gas, US Regulated | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Other [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 2 | 6 | 6 | 11 |
Natural Gas, US Regulated | Potomac Electric Power Company [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Residential [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Transportation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Other [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Delmarva Power and Light Company [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 20 | 24 | 116 | 129 |
Natural Gas, US Regulated | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 20 | 24 | 115 | 129 |
Natural Gas, US Regulated | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 1 | 0 |
Natural Gas, US Regulated | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Residential [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 9 | 8 | 64 | 68 |
Natural Gas, US Regulated | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 4 | 5 | 30 | 31 |
Natural Gas, US Regulated | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 1 | 2 | 4 | 7 |
Natural Gas, US Regulated | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Transportation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 4 | 3 | 11 | 12 |
Natural Gas, US Regulated | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Other [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 2 | 6 | 6 | 11 |
Natural Gas, US Regulated | Atlantic City Electric Company [Member] | Regulated Operation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Operating Segments [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Residential [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Transportation [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | 0 | 0 |
Natural Gas, US Regulated | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Other [Member] | ||||
Revenue, Major Customer [Line Items] | ||||
Revenue from Contract with Customer, Including Assessed Tax | $ 0 | $ 0 | $ 0 | $ 0 |