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Regulatory Matters (Tables) | 12 Months Ended
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Dec. 31, 2018
Regulated Operations [Abstract] |
Public Utilities General Disclosures [Table Text Block] |
| Exelon |  | ComEd(a) |  | PECO |  | BGE(b) |  | PHI |  | Pepco(c) |  | DPL(c) |  | ACE
December 31, 2018 | $ | 65 |  |  | $ | 8 |  |  | $ | — |  |  | $ | 49 |  |  | $ | 8 |  |  | $ | 5 |  |  | $ | 3 |  |  | $ | — |
December 31, 2017 | $ | 69 |  |  | $ | 6 |  |  | $ | — |  |  | $ | 53 |  |  | $ | 10 |  |  | $ | 6 |  |  | $ | 4 |  |  | $ | — |
__________
(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.
Schedule of Regulatory Asset Impairments [Table Text Block] |
| For the year ended December 31, 2017
Exelon | $ | 35 |
ComEd | 3 |
BGE | 5 |
PHI | 27 |
Pepco | 14 |
DPL | 6 |
ACE | 7 |
On December 18, 2017, BGE filed for clarification and rehearing of FERC’s order, still seeking full recovery of its existing transmission-related income tax regulatory asset amounts, including those amounts that would have been previously amortized and recovered through rates had the transmission formula rate provided for such recovery. On February 27, 2018 (and updated on March 26, 2018), BGE submitted a letter to FERC advising that the lower federal corporate income tax rate effective January 1, 2018 provided for in the TCJA will be reflected in BGE’s annual formula rate update effective June 1, 2018, but that the deferred income tax benefits will not be passed back to customers unless BGE’s formula rate is revised to provide for pass back and recovery of transmission-related income tax-related regulatory liabilities and assets. 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 facilitate passing back to customers ongoing annual TCJA tax savings and 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, again 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. The orders did not address the remittance of TCJA transmission-related income tax regulatory liabilities, but rather referenced FERC’s separate Notice of Inquiry of such amounts issued on March 15, 2018. On October 1, 2018, ComEd, BGE, Pepco, DPL, and ACE submitted new 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. FERC issued deficiency letters requesting additional information on November 21, 2018 and January 28, 2019. ComEd, BGE, Pepco, DPL, and ACE responded to the November 21, 2018 deficiency letter on November 29, 2018 but cannot predict the outcome of these FERC 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 $76 million, $51 million, $15 million, $10 million, $3 million, $5 million and $2 million, respectively, as of December 31, 2018. On October 9, 2018, ComEd, Pepco, DPL, and ACE sought rehearing of FERC's September 7, 2018 order, still seeking full recovery of their existing transmission-related income tax regulatory asset amounts, including those amounts that would have been previously amortized and recovered through rates had the transmission formula rate provided for such recovery. ComEd, Pepco, DPL, and ACE cannot predict the outcome of this rehearing request. 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. PJM Transmission Rate Design (All Registrants). On June 15, 2016, several parties, including the Utility Registrants, filed a proposed settlement with FERC to resolve outstanding issues related to cost responsibility for charges to transmission customers for certain transmission facilities that operate at or above 500 kV. The settlement included provisions for monthly credits or charges related to the periods prior to January 1, 2016 that are expected to be refunded or recovered through PJM wholesale transmission rates through December 2025. On May 31, 2018, FERC issued an order approving the settlement and directed PJM to adjust wholesale transmission rates within 30 days. Pursuant to the order, similar charges for the period January 1, 2016 through June 30, 2018 will also be refunded or recovered through PJM wholesale transmission rates over the subsequent 12-month period. PJM commenced billing the refunds and charges associated with this settlement in August 2018. The Utility Registrants expect to refund or recover these settlement amounts through prospective electric distribution customer rates. On July 2, 2018, several parties filed petitions for rehearing or clarification. Pursuant to the FERC approval of the settlement and the expected refund or recovery of the associated amounts from electric distribution customers, in the second quarter of 2018 and as adjusted in the third quarter of 2018, the Utility Registrants recorded the following payables to/receivables from PJM and related regulatory assets/liabilities. Generation recorded a $41 million net payable to PJM and a pre-tax charge within Purchased power and fuel expense in Exelon's and Generation's Consolidated Statements of Operations and Comprehensive Income.
| PJM Receivable | PJM Payable | Regulatory Asset | Regulatory Liability
Exelon | $ | 220 |  | $ | 176 |  | $ | 136 |  | $ | 221 |
Generation(a) | — |  | 41 |  | — |  | — |
ComEd | 122 |  | — |  | — |  | 122 |
PECO | 85 |  | — |  | — |  | 85 |
BGE | — |  | 51 |  | 51 |  | — |
PHI | 13 |  | 84 |  | 85 |  | 14 |
Pepco | — |  | 84 |  | 84 |  | — |
DPL | 10 |  | — |  | — |  | 10 |
ACE | 3 |  | — |  | 1 |  | 4 |
__________
(a) |
Schedule of Regulatory Assets | The following tables provide information about the regulatory assets and liabilities of Exelon, ComEd, PECO, BGE, PHI, Pepco, DPL and ACE as of December 31, 2018 and December 31, 2017:
December 31, 2018 | Exelon |  | ComEd |  | PECO |  | BGE |  | PHI |  | Pepco |  | DPL |  | ACE
Regulatory assets |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Pension and other postretirement benefits | $ | 2,553 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |
Pension and other postretirement benefits - Merger related | 1,266 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Deferred income taxes | 414 |  |  | — |  |  | 404 |  |  | — |  |  | 10 |  |  | 10 |  |  | — |  |  | — |
AMI programs - Deployment Costs | 202 |  |  | — |  |  | — |  |  | 113 |  |  | 89 |  |  | 50 |  |  | 39 |  |  | — |
AMI programs - Legacy Meters | 328 |  |  | 136 |  |  | 24 |  |  | 48 |  |  | 120 |  |  | 90 |  |  | 30 |  |  | — |
AMI programs - Post-test year costs | 32 |  |  | — |  |  | — |  |  | 32 |  |  | — |  |  | — |  |  | — |  |  | — |
Electric distribution formula rate annual reconciliations | 158 |  |  | 158 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Electric distribution formula rate significant one-time events | 81 |  |  | 81 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Energy efficiency costs | 472 |  |  | 472 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Fair value of long-term debt | 702 |  |  | — |  |  | — |  |  | — |  |  | 569 |  |  | — |  |  | — |  |  | — |
Fair value of PHI's unamortized energy contracts | 561 |  |  | — |  |  | — |  |  | — |  |  | 561 |  |  | — |  |  | — |  |  | — |
Asset retirement obligations | 118 |  |  | 79 |  |  | 22 |  |  | 16 |  |  | 1 |  |  | 1 |  |  | — |  |  | — |
MGP remediation costs | 326 |  |  | 309 |  |  | 17 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Renewable energy | 249 |  |  | 249 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Electric Energy and Natural Gas Costs | 193 |  |  | — |  |  | 49 |  |  | 51 |  |  | 93 |  |  | 84 |  |  | — |  |  | 9 |
Transmission formula rate annual reconciliations | 41 |  |  | 6 |  |  | — |  |  | 4 |  |  | 31 |  |  | 10 |  |  | 14 |  |  | 7 |
Energy efficiency and demand response programs | 545 |  |  | — |  |  | 1 |  |  | 289 |  |  | 255 |  |  | 188 |  |  | 67 |  |  | — |
Merger integration costs | 42 |  |  | — |  |  | — |  |  | 3 |  |  | 39 |  |  | 18 |  |  | 11 |  |  | 10 |
Under-recovered revenue decoupling | 59 |  |  | — |  |  | — |  |  | 2 |  |  | 57 |  |  | 57 |  |  | — |  |  | — |
Securitized stranded costs | 50 |  |  | — |  |  | — |  |  | — |  |  | 50 |  |  | — |  |  | — |  |  | 50 |
Removal costs | 564 |  |  | — |  |  | — |  |  | — |  |  | 564 |  |  | 158 |  |  | 97 |  |  | 309 |
DC PLUG charge | 159 |  |  | — |  |  | — |  |  | — |  |  | 159 |  |  | 159 |  |  | — |  |  | — |
Deferred storm costs | 41 |  |  | — |  |  | — |  |  | — |  |  | 41 |  |  | 9 |  |  | 4 |  |  | 28 |
Other | 303 |  |  | 110 |  |  | 24 |  |  | 17 |  |  | 162 |  |  | 79 |  |  | 28 |  |  | 13 |
Total regulatory assets | 9,459 |  |  | 1,600 |  |  | 541 |  |  | 575 |  |  | 2,801 |  |  | 913 |  |  | 290 |  |  | 426 |
Less: current portion | 1,222 |  |  | 293 |  |  | 81 |  |  | 177 |  |  | 489 |  |  | 270 |  |  | 59 |  |  | 40 |
Total noncurrent regulatory assets | $ | 8,237 |  |  | $ | 1,307 |  |  | $ | 460 |  |  | $ | 398 |  |  | $ | 2,312 |  |  | $ | 643 |  |  | $ | 231 |  |  | $ | 386 |
December 31, 2017 | Exelon |  | ComEd |  | PECO |  | BGE |  | PHI |  | Pepco |  | DPL |  | ACE
Regulatory assets |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Pension and other postretirement benefits | $ | 2,455 |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |  |  | $ | — |
Pension and other postretirement benefits - Merger related | 1,393 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Deferred income taxes | 306 |  |  | — |  |  | 297 |  |  | — |  |  | 9 |  |  | 9 |  |  | — |  |  | — |
AMI programs - Deployment costs | 385 |  |  | — |  |  | — |  |  | 129 |  |  | 101 |  |  | 58 |  |  | 43 |  |  | — |
AMI programs - Legacy meters | 223 |  |  | 155 |  |  | 36 |  |  | 53 |  |  | 134 |  |  | 100 |  |  | 34 |  |  | — |
AMI programs - Post-test year costs | 32 |  |  | — |  |  | — |  |  | 32 |  |  | — |  |  | — |  |  | — |  |  | — |
Electric distribution formula rate annual reconciliations | 186 |  |  | 186 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Electric distribution formula rate significant one-time events | 58 |  |  | 58 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Energy efficiency costs | 166 |  |  | 166 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Fair value of long-term debt | 758 |  |  | — |  |  | — |  |  | — |  |  | 619 |  |  | — |  |  | — |  |  | — |
Fair value of PHI's unamortized energy contracts | 750 |  |  | — |  |  | — |  |  | — |  |  | 750 |  |  | — |  |  | — |  |  | — |
Asset retirement obligations | 109 |  |  | 73 |  |  | 22 |  |  | 14 |  |  | — |  |  | — |  |  | — |  |  | — |
MGP remediation costs | 295 |  |  | 273 |  |  | 22 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Renewable energy | 258 |  |  | 256 |  |  | — |  |  | — |  |  | 2 |  |  | — |  |  | 1 |  |  | 1 |
Electric energy and natural gas costs | 47 |  |  | — |  |  | 1 |  |  | 16 |  |  | 30 |  |  | 8 |  |  | 7 |  |  | 15 |
Transmission formula rate annual reconciliations | 35 |  |  | 6 |  |  | — |  |  | 7 |  |  | 22 |  |  | 3 |  |  | 8 |  |  | 11 |
Energy efficiency and demand response programs | 596 |  |  | — |  |  | 1 |  |  | 285 |  |  | 310 |  |  | 229 |  |  | 81 |  |  | — |
Merger integration costs | 45 |  |  | — |  |  | — |  |  | 6 |  |  | 39 |  |  | 20 |  |  | 10 |  |  | 9 |
Under-recovered revenue decoupling | 55 |  |  | — |  |  | — |  |  | 14 |  |  | 41 |  |  | 38 |  |  | 3 |  |  | — |
Securitized stranded costs | 79 |  |  | — |  |  | — |  |  | — |  |  | 79 |  |  | — |  |  | — |  |  | 79 |
Removal costs | 529 |  |  | — |  |  | — |  |  | — |  |  | 529 |  |  | 150 |  |  | 93 |  |  | 286 |
DC PLUG charge | 190 |  |  | — |  |  | — |  |  | — |  |  | 190 |  |  | 190 |  |  | — |  |  | — |
Deferred storm costs | 27 |  |  | — |  |  | — |  |  | — |  |  | 27 |  |  | 7 |  |  | 5 |  |  | 15 |
Other | 311 |  |  | 106 |  |  | 31 |  |  | 15 |  |  | 165 |  |  | 79 |  |  | 29 |  |  | 14 |
Total regulatory assets | 9,288 |  |  | 1,279 |  |  | 410 |  |  | 571 |  |  | 3,047 |  |  | 891 |  |  | 314 |  |  | 430 |
Less: current portion | 1,267 |  |  | 225 |  |  | 29 |  |  | 174 |  |  | 554 |  |  | 213 |  |  | 69 |  |  | 71 |
Total noncurrent regulatory assets | $ | 8,021 |  |  | $ | 1,054 |  |  | $ | 381 |  |  | $ | 397 |  |  | $ | 2,493 |  |  | $ | 678 |  |  | $ | 245 |  |  | $ | 359 |
December 31, 2017 | Exelon |  | ComEd |  | PECO |  | BGE |  | PHI |  | Pepco |  | DPL |  | ACE
Regulatory liabilities |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Deferred income taxes | $ | 5,241 |  |  | $ | 2,479 |  |  | $ | — |  |  | $ | 1,032 |  |  | $ | 1,730 |  |  | $ | 809 |  |  | $ | 510 |  |  | $ | 411 |
Nuclear decommissioning | 3,064 |  |  | 2,528 |  |  | 536 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Removal costs | 1,573 |  |  | 1,338 |  |  | — |  |  | 105 |  |  | 130 |  |  | 20 |  |  | 110 |  |  | — |
Electric Energy and Natural Gas Costs | 111 |  |  | 47 |  |  | 60 |  |  | — |  |  | 4 |  |  | — |  |  | 1 |  |  | 3 |
Other | 399 |  |  | 185 |  |  | 94 |  |  | 26 |  |  | 64 |  |  | 3 |  |  | 14 |  |  | 8 |
Total regulatory liabilities | 10,388 |  |  | 6,577 |  |  | 690 |  |  | 1,163 |  |  | 1,928 |  |  | 832 |  |  | 635 |  |  | 422 |
Less: current portion | 523 |  |  | 249 |  |  | 141 |  |  | 62 |  |  | 56 |  |  | 3 |  |  | 42 |  |  | 11 |
Total noncurrent regulatory liabilities | $ | 9,865 |  |  | $ | 6,328 |  |  | $ | 549 |  |  | $ | 1,101 |  |  | $ | 1,872 |  |  | $ | 829 |  |  | $ | 593 |  |  | $ | 411 |
Schedule of Regulatory Liabilities |
December 31, 2017 | Exelon |  | ComEd |  | PECO |  | BGE |  | PHI |  | Pepco |  | DPL |  | ACE
Regulatory liabilities |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Deferred income taxes | $ | 5,241 |  |  | $ | 2,479 |  |  | $ | — |  |  | $ | 1,032 |  |  | $ | 1,730 |  |  | $ | 809 |  |  | $ | 510 |  |  | $ | 411 |
Nuclear decommissioning | 3,064 |  |  | 2,528 |  |  | 536 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Removal costs | 1,573 |  |  | 1,338 |  |  | — |  |  | 105 |  |  | 130 |  |  | 20 |  |  | 110 |  |  | — |
Electric Energy and Natural Gas Costs | 111 |  |  | 47 |  |  | 60 |  |  | — |  |  | 4 |  |  | — |  |  | 1 |  |  | 3 |
Other | 399 |  |  | 185 |  |  | 94 |  |  | 26 |  |  | 64 |  |  | 3 |  |  | 14 |  |  | 8 |
Total regulatory liabilities | 10,388 |  |  | 6,577 |  |  | 690 |  |  | 1,163 |  |  | 1,928 |  |  | 832 |  |  | 635 |  |  | 422 |
Less: current portion | 523 |  |  | 249 |  |  | 141 |  |  | 62 |  |  | 56 |  |  | 3 |  |  | 42 |  |  | 11 |
Total noncurrent regulatory liabilities | $ | 9,865 |  |  | $ | 6,328 |  |  | $ | 549 |  |  | $ | 1,101 |  |  | $ | 1,872 |  |  | $ | 829 |  |  | $ | 593 |  |  | $ | 411 |
December 31, 2018 | Exelon |  | ComEd |  | PECO |  | BGE |  | PHI |  | Pepco |  | DPL |  | ACE
Regulatory liabilities |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Deferred income taxes | $ | 5,228 |  |  | $ | 2,394 |  |  | $ | — |  |  | $ | 1,132 |  |  | $ | 1,702 |  |  | $ | 798 |  |  | $ | 510 |  |  | $ | 394 |
Nuclear decommissioning | 2,606 |  |  | 2,217 |  |  | 389 |  |  | — |  |  | — |  |  | — |  |  | — |  |  | — |
Removal costs | 1,547 |  |  | 1,368 |  |  | — |  |  | 52 |  |  | 127 |  |  | 20 |  |  | 107 |  |  | — |
Electric Energy and Natural Gas Costs | 294 |  |  | 137 |  |  | 132 |  |  | 6 |  |  | 19 |  |  | — |  |  | 18 |  |  | 1 |
Other | 528 |  |  | 227 |  |  | 75 |  |  | 79 |  |  | 100 |  |  | 11 |  |  | 30 |  |  | 25 |
Total regulatory liabilities | 10,203 |  |  | 6,343 |  |  | 596 |  |  | 1,269 |  |  | 1,948 |  |  | 829 |  |  | 665 |  |  | 420 |
Less: current portion | 644 |  |  | 293 |  |  | 175 |  |  | 77 |  |  | 84 |  |  | 7 |  |  | 59 |  |  | 18 |
Total noncurrent regulatory liabilities | $ | 9,559 |  |  | $ | 6,050 |  |  | $ | 421 |  |  | $ | 1,192 |  |  | $ | 1,864 |  |  | $ | 822 |  |  | $ | 606 |  |  | $ | 402 |

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