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Utility Rate Regulation | 12 Months Ended
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Dec. 31, 2020
Utility Rate Regulation [Line Items] |
Utility Rate Regulation | 7. Utility Rate Regulation Regulatory Assets and Liabilities (All Registrants) PPL, PPL Electric, LKE, LG&E and KU reflect the effects of regulatory actions in the financial statements for their cost-based rate-regulated utility operations. Regulatory assets and liabilities are classified as current if, upon initial recognition, the entire amount related to an item will be recovered or refunded within a year of the balance sheet date. (PPL) WPD is not subject to accounting for the effects of certain types of regulation as prescribed by GAAP and does not record regulatory assets and liabilities. See Note 1 for additional information. (PPL, LKE, LG&E and KU) LG&E is subject to the jurisdiction of the KPSC and FERC, and KU is subject to the jurisdiction of the KPSC, FERC and VSCC. LG&E's and KU's Kentucky base rates are calculated based on a return on capitalization (common equity, long-term debt and short-term debt) including adjustments for certain net investments and costs recovered separately through other means. As such, LG&E and KU generally earn a return on regulatory assets. (PPL, LKE and KU) KU's Virginia base rates are calculated based on a return on rate base (net utility plant plus working capital less accumulated deferred income taxes and miscellaneous deductions). As all regulatory assets and liabilities, except for regulatory assets and liabilities related to the levelized fuel factor, pension and postretirement benefits, and AROs related to certain CCR impoundments, are excluded from the return on rate base utilized in the calculation of Virginia base rates, no return is earned on the related assets. KU's rates to municipal customers for wholesale power requirements are calculated based on annual updates to a formula rate that utilizes a return on rate base (net utility plant plus working capital less accumulated deferred income taxes and miscellaneous deductions). As all regulatory assets and liabilities are excluded from the return on rate base utilized in the development of municipal rates, no return is earned on the related assets. (PPL and PPL Electric) PPL Electric's distribution base rates are calculated based on recovery of costs as well as a return on distribution rate base (net utility plant plus a working capital allowance less plant-related deferred taxes and other miscellaneous additions and deductions). PPL Electric's transmission revenues are billed in accordance with a FERC tariff that allows for recovery of transmission costs incurred, a return on transmission-related rate base (net utility plant plus a working capital allowance less plant-related deferred taxes and other miscellaneous additions and deductions) and an automatic annual update. See "Transmission Formula Rate" below for additional information on this tariff. All regulatory assets and liabilities are excluded from distribution and transmission return on investment calculations; therefore, generally no return is earned on PPL Electric's regulatory assets. (All Registrants) The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations at December 31:
| PPL |  | PPL Electric
| 2020 |  | 2019 |  | 2020 |  | 2019
Current Regulatory Assets: |  |  |  |  |  |  |
Plant outage costs | $ | 46 |  |  | $ | 32 |  |  | $ | — |  |  | $ | — |
Gas supply clause | 4 |  |  | 8 |  |  | — |  |  | — |
Smart meter rider | 17 |  |  | 13 |  |  | 17 |  |  | 13 |
Storm costs | 7 |  |  | — |  |  | 7 |  |  | — |
Transmission formula rate | 15 |  |  | 3 |  |  | 15 |  |  | 3 |
Transmission service charge | — |  |  | 10 |  |  | — |  |  | 10 |
Other | 10 |  |  | 1 |  |  | 1 |  |  | — |
Total current regulatory assets (a) | $ | 99 |  |  | $ | 67 |  |  | $ | 40 |  |  | $ | 26 |
Noncurrent Regulatory Assets: |  |  |  |  |  |  |
Defined benefit plans | $ | 570 |  |  | $ | 800 |  |  | $ | 290 |  |  | $ | 467 |
Storm costs | 17 |  |  | 39 |  |  | — |  |  | 15 |
Unamortized loss on debt | 30 |  |  | 41 |  |  | 8 |  |  | 18 |
Interest rate swaps | 23 |  |  | 22 |  |  | — |  |  | — |
Terminated interest rate swaps | 75 |  |  | 81 |  |  | — |  |  | — |
Accumulated cost of removal of utility plant | 240 |  |  | 220 |  |  | 240 |  |  | 220 |
AROs | 300 |  |  | 279 |  |  | — |  |  | — |
Act 129 compliance rider | — |  |  | 6 |  |  | — |  |  | 6 |
Other | 7 |  |  | 4 |  |  | 3 |  |  | — |
Total noncurrent regulatory assets | $ | 1,262 |  |  | $ | 1,492 |  |  | $ | 541 |  |  | $ | 726 |
| PPL |  | PPL Electric
| 2020 |  | 2019 |  | 2020 |  | 2019
Current Regulatory Liabilities: |  |  |  |  |  |  |
Generation supply charge | $ | 21 |  |  | $ | 23 |  |  | $ | 21 |  |  | $ | 23 |
Environmental cost recovery | 4 |  |  | 5 |  |  | — |  |  | — |
Universal service rider | 22 |  |  | 9 |  |  | 22 |  |  | 9 |
Fuel adjustment clause | 5 |  |  | 8 |  |  | — |  |  | — |
TCJA customer refund | 11 |  |  | 61 |  |  | 11 |  |  | 59 |
Storm damage expense rider | 6 |  |  | 5 |  |  | 6 |  |  | 5 |
Act 129 compliance rider | 7 |  |  | — |  |  | 7 |  |  | — |
Other | 3 |  |  | 4 |  |  | 1 |  |  | — |
Total current regulatory liabilities | $ | 79 |  |  | $ | 115 |  |  | $ | 68 |  |  | $ | 96 |
Noncurrent Regulatory Liabilities: |  |  |  |  |  |  |
Accumulated cost of removal of utility plant | $ | 653 |  |  | $ | 640 |  |  | $ | — |  |  | $ | — |
Power purchase agreement - OVEC | 43 |  |  | 51 |  |  | — |  |  | — |
Net deferred taxes | 1,690 |  |  | 1,756 |  |  | 560 |  |  | 588 |
Defined benefit plans | 60 |  |  | 51 |  |  | 18 |  |  | 11 |
Terminated interest rate swaps | 66 |  |  | 68 |  |  | — |  |  | — |
Other | 18 |  |  | 6 |  |  | — |  |  | — |
Total noncurrent regulatory liabilities | $ | 2,530 |  |  | $ | 2,572 |  |  | $ | 578 |  |  | $ | 599 |
| LKE |  | LG&E |  | KU
| 2020 |  | 2019 |  | 2020 |  | 2019 |  | 2020 |  | 2019
Current Regulatory Assets: |  |  |  |  |  |  |  |  |  |  |
Plant outage costs | $ | 46 |  |  | $ | 32 |  |  | $ | 12 |  |  | $ | 16 |  |  | $ | 34 |  |  | $ | 16 |
Gas supply clause | 4 |  |  | 8 |  |  | 4 |  |  | 8 |  |  | — |  |  | — |
Other | 9 |  |  | 1 |  |  | 7 |  |  | 1 |  |  | 2 |  |  | — |
Total current regulatory assets | $ | 59 |  |  | $ | 41 |  |  | $ | 23 |  |  | $ | 25 |  |  | $ | 36 |  |  | $ | 16 |
Noncurrent Regulatory Assets: |  |  |  |  |  |  |  |  |  |  |
Defined benefit plans | $ | 280 |  |  | $ | 333 |  |  | $ | 174 |  |  | $ | 206 |  |  | $ | 106 |  |  | $ | 127 |
Storm costs | 17 |  |  | 24 |  |  | 11 |  |  | 14 |  |  | 6 |  |  | 10 |
Unamortized loss on debt | 22 |  |  | 23 |  |  | 13 |  |  | 14 |  |  | 9 |  |  | 9 |
Interest rate swaps | 23 |  |  | 22 |  |  | 23 |  |  | 22 |  |  | — |  |  | — |
Terminated interest rate swaps | 75 |  |  | 81 |  |  | 44 |  |  | 47 |  |  | 31 |  |  | 34 |
AROs | 300 |  |  | 279 |  |  | 85 |  |  | 76 |  |  | 215 |  |  | 203 |
Other | 4 |  |  | 4 |  |  | 1 |  |  | 1 |  |  | 3 |  |  | 3 |
Total noncurrent regulatory assets | $ | 721 |  |  | $ | 766 |  |  | $ | 351 |  |  | $ | 380 |  |  | $ | 370 |  |  | $ | 386 |
| LKE |  | LG&E |  | KU
| 2020 |  | 2019 |  | 2020 |  | 2019 |  | 2020 |  | 2019
Current Regulatory Liabilities: |  |  |  |  |  |  |  |  |  |  |
Environmental cost recovery | $ | 4 |  |  | $ | 5 |  |  | $ | — |  |  | $ | 1 |  |  | $ | 4 |  |  | $ | 4 |
Fuel adjustment clauses | 5 |  |  | 8 |  |  | — |  |  | — |  |  | 5 |  |  | 8 |
Other | 2 |  |  | 6 |  |  | — |  |  | 1 |  |  | 2 |  |  | 5 |
Total current regulatory liabilities | $ | 11 |  |  | $ | 19 |  |  | $ | — |  |  | $ | 2 |  |  | $ | 11 |  |  | $ | 17 |
Noncurrent Regulatory Liabilities: |  |  |  |  |  |  |  |  |  |  |
Accumulated cost of removal of utility plant | $ | 653 |  |  | $ | 640 |  |  | $ | 274 |  |  | $ | 266 |  |  | $ | 379 |  |  | $ | 374 |
Power purchase agreement - OVEC | 43 |  |  | 51 |  |  | 30 |  |  | 35 |  |  | 13 |  |  | 16 |
Net deferred taxes | 1,130 |  |  | 1,168 |  |  | 528 |  |  | 544 |  |  | 602 |  |  | 624 |
Defined benefit plans | 42 |  |  | 40 |  |  | — |  |  | — |  |  | 42 |  |  | 40 |
Terminated interest rate swaps | 66 |  |  | 68 |  |  | 33 |  |  | 34 |  |  | 33 |  |  | 34 |
Other | 18 |  |  | 6 |  |  | 17 |  |  | 4 |  |  | 1 |  |  | 2 |
Total noncurrent regulatory liabilities | $ | 1,952 |  |  | $ | 1,973 |  |  | $ | 882 |  |  | $ | 883 |  |  | $ | 1,070 |  |  | $ | 1,090 |
(a)For PPL, these amounts are included in "Other current assets" on the Balance Sheets. Following is an overview of selected regulatory assets and liabilities detailed in the preceding tables. Specific developments with respect to certain of these regulatory assets and liabilities are discussed in "Regulatory Matters." Defined Benefit Plans (All Registrants) Defined benefit plan regulatory assets and liabilities represent prior service cost and net actuarial gains and losses that will be recovered in defined benefit plans expense through future base rates based upon established regulatory practices and, generally, are amortized over the average remaining service lives of plan participants. These regulatory assets and liabilities are adjusted at least annually or whenever the funded status of defined benefit plans is remeasured. (PPL, LKE, LG&E and KU) As a result of the 2014 Kentucky rate case settlement that became effective July 1, 2015, the difference between pension cost calculated in accordance with LG&E's and KU's pension accounting policy and pension cost calculated using a 15-year amortization period for actuarial gains and losses is recorded as a regulatory asset. As of December 31, 2020, the balances were $79 million for PPL and LKE, $44 million for LG&E and $35 million for KU. As of December 31, 2019, the balances were $51 million for PPL and LKE, $29 million for LG&E and $22 million for KU. (All Registrants) Storm Costs PPL Electric, LG&E and KU have the ability to request from the PUC, KPSC and VSCC, as applicable, the authority to treat expenses related to specific extraordinary storms as a regulatory asset and defer such costs for regulatory accounting and reporting purposes. Once such authority is granted, LG&E and KU can request recovery of those expenses in a base rate case and begin amortizing the costs when recovery starts. PPL Electric can recover qualifying expenses caused by major storm events, as defined in its retail tariff, over three years through the Storm Damage Expense Rider commencing in the application year after the storm occurred. PPL Electric's regulatory assets for storm costs are being amortized through 2021. LG&E's and KU's regulatory assets for storm costs are being amortized through various dates ending in 2029. Unamortized Loss on Debt Unamortized loss on reacquired debt represents losses on long-term debt reacquired or redeemed that have been deferred and will be amortized and recovered over either the original life of the extinguished debt or the life of the replacement debt (in the case of refinancing). Such costs are being amortized through 2029 for PPL Electric, through 2042 for KU, and through 2044 for LG&E. Accumulated Cost of Removal of Utility Plant LG&E and KU charge costs of removal through depreciation expense with an offsetting credit to a regulatory liability. The regulatory liability is relieved as costs are incurred. PPL Electric does not accrue for costs of removal. When costs of removal are incurred, PPL Electric records the costs as a regulatory asset. Such deferral is included in rates and amortized over the subsequent five-year period. Net Deferred Taxes Regulatory liabilities associated with net deferred taxes represent the future revenue impact from the adjustment of deferred income taxes required primarily for excess deferred taxes and unamortized investment tax credits, largely a result of the TCJA enacted in 2017. (PPL and PPL Electric) Generation Supply Charge (GSC) The GSC is a cost recovery mechanism that permits PPL Electric to recover costs incurred to provide generation supply to PLR customers who receive basic generation supply service. The recovery includes charges for generation supply, as well as administration of the acquisition process. In addition, the GSC contains a reconciliation mechanism whereby any over- or under-recovery from prior periods is refunded to, or recovered from, customers through the adjustment factor determined for the subsequent rate filing period. Transmission Service Charge (TSC) PPL Electric is charged by PJM for transmission service-related costs applicable to its PLR customers. PPL Electric passes these costs on to customers, who receive basic generation supply service through the PUC-approved TSC cost recovery mechanism. The TSC contains a reconciliation mechanism whereby any over- or under-recovery from customers is either refunded to, or recovered from, customers through the adjustment factor determined for the subsequent year. Transmission Formula Rate PPL Electric's transmission revenues are billed in accordance with a FERC-approved Open Access Transmission Tariff that utilizes a formula-based rate recovery mechanism. Under this formula, rates are put into effect in June of each year based upon prior year actual expenditures and current year forecasted capital additions. Rates are then adjusted the following year to reflect actual annual expenses and capital additions, as reported in PPL Electric's annual FERC Form 1, filed under the FERC's Uniform System of Accounts. Any difference between the revenue requirement in effect for the prior year and actual expenditures incurred for that year is recorded as a regulatory asset or regulatory liability. Storm Damage Expense Rider (SDER) The SDER is a reconcilable automatic adjustment clause under which PPL Electric annually will compare actual storm costs to storm costs allowed in base rates and refund or recover any differences from customers. In the 2015 rate case settlement approved by the PUC in November 2015, it was determined that reportable storm damage expenses to be recovered annually through base rates will be set at $20 million. The SDER will recover from or refund to customers, as appropriate, only applicable expenses from reportable storms that are greater than or less than $20 million recovered annually through base rates. Storm costs incurred in PPL Electric's territory from a March 2018 storm are being amortized through 2021. Act 129 Compliance Rider In compliance with Pennsylvania's Act 129 of 2008 and implementing regulations, PPL Electric is currently in Phase III of the energy efficiency and conservation plan which was approved in June 2016. Phase III allows PPL Electric to recover the maximum $313 million over the five-year period, June 1, 2016 through May 31, 2021. The plan includes programs intended to reduce electricity consumption. The recoverable costs include direct and indirect charges, including design and development costs, general and administrative costs and applicable state evaluator costs. The rates are applied to customers who receive distribution service through the Act 129 Compliance Rider. The actual Phase III program costs are reconcilable after each 12 month period, and any over- or under-recovery from customers will be refunded or recovered over the next rate filing period. Smart Meter Rider (SMR) Act 129 requires each electric distribution company (EDC) with more than 100,000 customers to have a PUC approved Smart Meter Technology Procurement and Installation Plan (SMP). As of December 31, 2019, PPL Electric replaced substantially all of its old meters with meters that meet the Act 129 requirements under its SMP. In accordance with Act 129, EDCs are able to recover the costs and earn a return on capital of providing smart metering technology. PPL Electric uses the SMR to recover the costs to implement its SMP. The SMR is a reconciliation mechanism whereby any over- or under-recovery from prior years is refunded to, or recovered from, customers through the adjustment factor determined for the subsequent quarters. Universal Service Rider (USR) The USR provides for recovery of costs associated with universal service programs, OnTrack and Winter Relief Assistance Program (WRAP), provided by PPL Electric to residential customers. OnTrack is a special payment program for low-income households and WRAP provides low-income customers a means to reduce electric bills through energy saving methods. The USR rate is applied to residential customers who receive distribution service. The actual program costs are reconcilable, and any over- or under-recovery from customers will be refunded or recovered annually in the subsequent year. TCJA Customer Refund As a result of the reduced U.S federal corporate income tax rate as enacted by the TCJA, the PUC ruled that these tax benefits should be refunded to customers. Timing differences between the recognition of these tax benefits and the refund of the benefit to the customer creates a regulatory liability. PPL Electric's liability related to the period of July 1, 2018 through December 31, 2020 is being credited back to distribution customers through a negative surcharge. The liability related to the period of January 1, 2018 through June 30, 2018 was $43 million and was credited back to customers over the period of January 1, 2020 through December 31, 2020 utilizing the same negative surcharge mechanism referred to above, as approved by the PUC in November 2019. (PPL, LKE, LG&E and KU) Environmental Cost Recovery Kentucky law permits LG&E and KU to recover the costs, including a return of operating expenses and a return of and on capital invested, of complying with the Clean Air Act and those federal, state or local environmental requirements, which apply to coal combustion wastes and by-products from coal-fired electricity generating facilities. The KPSC requires reviews of the past operations of the environmental surcharge for six-month and two-year billing periods to evaluate the related charges, credits and rates of return, as well as to provide for the roll-in of ECR amounts to base rates each two-year period. The KPSC has authorized returns on equity of 9.2% and 9.725% for existing approved ECR projects. The ECR regulatory asset or liability represents the amount that has been under- or over-recovered due to timing or adjustments to the mechanism and is typically recovered or refunded within 12 months. Fuel Adjustment Clauses LG&E's and KU's retail electric rates contain a fuel adjustment clause, whereby variances in the cost of fuel to generate electricity, including transportation costs, from the costs embedded in base rates are adjusted in LG&E's and KU's rates. The KPSC requires formal reviews at six-month intervals to examine past fuel adjustments and at two-year intervals to review past operations of the fuel adjustment clause and, to the extent appropriate, may conduct public hearings and reestablish the fuel charge included in base rates. The regulatory assets or liabilities represent the amounts that have been under- or over-recovered due to timing or adjustments to the mechanism and are typically recovered within 12 months. KU also employs a levelized fuel factor mechanism for Virginia customers using an average fuel cost factor based primarily on projected fuel costs and load for the fuel year (12 months ending March 31). The Virginia levelized fuel factor allows fuel recovery based on projected fuel costs for the fuel year plus an adjustment for any under- or over-recovery of fuel expenses from the prior fuel year. The regulatory assets or liabilities represent the amounts that have been under- or over-recovered due to timing or adjustments to the mechanism and are typically recovered or refunded within 12 months. AROs As discussed in Note 1, for LKE, LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, at the time of retirement, the related ARO regulatory asset is offset against the associated cost of removal regulatory liability, PP&E and ARO liability. Power Purchase Agreement - OVEC As a result of purchase accounting associated with PPL's acquisition of LKE, the fair values of the OVEC power purchase agreement were recorded on the balance sheets of LKE, LG&E and KU with offsets to regulatory liabilities. The regulatory liabilities are being amortized using the units-of-production method until March 2026, the expiration date of the agreement at the date of the acquisition. LG&E's and KU's customer rates continue to reflect the original contracts. See Notes 14 and 19 for additional discussion of the power purchase agreement. Interest Rate Swaps LG&E's unrealized gains and losses are recorded as regulatory assets or regulatory liabilities until they are realized as interest expense. Interest expense from existing swaps is realized and recovered over the terms of the associated debt, which matures through 2033. Terminated Interest Rate Swaps Net realized gains and losses on all interest rate swaps are probable of recovery through regulated rates. As such, any gains and losses on these derivatives are included in regulatory assets or liabilities and are primarily recognized in "Interest Expense" on the Statements of Income over the life of the associated debt. Plant Outage Costs Since July 1, 2017, plant outage costs in Kentucky have been normalized for ratemaking purposes based on an average level of expenses. Plant outage expenses that are greater or less than the average are collected from or returned to customers, through future base rates. Effective May 1, 2019 plant outage costs are normalized based on a five-year average of historical expenses with over or under recoveries collected or returned over an eight-year period. Gas Supply Clause (PPL, LKE and LG&E) LG&E's natural gas rates contain a gas supply clause, whereby the expected cost of natural gas supply and variances between actual and expected costs from prior periods are adjusted quarterly in LG&E's rates, subject to approval by the KPSC. The gas supply clause also includes a separate natural gas procurement incentive mechanism, which allows LG&E's rates to be adjusted annually to share savings between the actual cost of gas purchases and market indices, with the shareholders and the customers during each performance-based rate year (12 months ending October 31). LG&E currently has a proceeding pending with the KPSC in which LG&E proposed renewal of and modification to its natural gas procurement incentive mechanism, which is currently approved through September 1, 2021. LG&E cannot predict the outcome of this proceeding. The regulatory assets or liabilities represent the total amounts that have been under- or over-recovered due to timing or adjustments to the mechanisms and are typically recovered or refunded within 18 months. Generation Formula Rate (PPL, LKE and KU) KU provides wholesale requirements service to its municipal customers and bills for this service pursuant to a FERC approved generation formula rate. Under this formula, rates are put into effect each July utilizing a return on rate base calculation and actual expenses from the preceding year. The regulatory asset or liability represents the difference between the revenue requirement in effect for the current year and actual expenditures incurred for the current year. Amounts are included in other current regulatory assets for 2020 and other current regulatory liabilities for 2019 in the table above. Regulatory Matters Kentucky Activities (PPL, LKE, LG&E and KU) Rate Case Proceedings On November 25, 2020, LG&E and KU filed requests with the KPSC for an increase in annual electricity and gas revenues of approximately $331 million ($131 million and $170 million in electricity revenues at LG&E and KU and $30 million in gas revenues at LG&E). The revenue increases would be an increase of 11.6% and 10.4% in electricity revenues at LG&E and KU, and an increase of 8.3% in gas revenues at LG&E. LG&E and KU are also requesting approval of a one-year billing credit which will credit customers approximately $53 million ($41 million at LG&E and $12 million at KU). The billing credit represents the return to customers of certain regulatory liabilities on LG&E’s and KU’s balance sheets and serves to partially mitigate the rate increases during the first year in which the new rates are in effect. LG&E’s and KU’s applications also include a request for a CPCN to deploy Advanced Metering Infrastructure across LG&E’s and KU’s service territories in Kentucky. The applications are based on a forecasted test year of July 1, 2021 through June 30, 2022 and request an authorized return on equity of 10.0%. Subject to KPSC approval, the requested rates, decreased by the amount of the billing credit, are expected to become effective July 1, 2021. Certain counterparties have intervened in the proceedings. Data discovery and the filing of written testimony will continue through April 2021 and a hearing is expected to occur during the second quarter of 2021. PPL, LKE, LG&E and KU cannot predict the outcome of these proceedings. ECR Filings On March 31, 2020, LG&E and KU submitted applications to the KPSC for ECR rate treatment regarding upcoming environmental construction projects relating to the EPA's regulations addressing ELGs. The construction projects are expected to begin in 2021 and continue through 2024 and are estimated to cost approximately $405 million ($153 million at LG&E and $252 million at KU). The applications requested an authorized 9.725% return on equity with respect to these projects consistent with the authorized return on equity approved for the 2018 Kentucky rate cases in April 2019. On September 29, 2020, the KPSC issued orders approving the ECR applications, permitting an authorized return on equity of 9.2% for the applicable projects. Pennsylvania Activities (PPL and PPL Electric) Act 129 Act 129 requires Pennsylvania Electric Distribution Companies (EDCs) to meet, by specified dates, specified goals for reduction in customer electricity usage and peak demand. EDCs not meeting the requirements of Act 129 are subject to significant penalties. PPL Electric filed with the PUC its Act 129 Phase IV Energy Efficiency and Conservation Plan on November 30, 2020, for the five-year period starting June 1, 2021 and ending on May 31, 2026. Hearings were held February 8, 2021. This proceeding remains pending before the PUC. PPL Electric cannot predict the outcome of this proceeding. Act 129 also requires EDCs to act as a default service provider (DSP), which provides electricity generation supply service to customers pursuant to a PUC-approved default service procurement plan. A DSP is able to recover the costs associated with its default service procurement plan. In March 2020, PPL Electric filed a Petition for Approval of a new default service program and procurement plan with the PUC for the period June 1, 2021 through May 31, 2025. Hearings were held in August 2020. PPL Electric received a Recommended Decision from the Administrative Law Judge on October 13, 2020. Several parties filed Exceptions and Reply Exceptions on October 26, 2020 and November 2, 2020, respectively. On December 17, 2020, the PUC issued a final Order approving the partial settlement reached by parties, including the PPL Electric default service plan for the period of June 2021 through May 2025, and ruling on the issues reserved for litigation. This matter is not expected to have a significant impact on the financial condition of PPL Electric. Federal Matters Challenge to PPL Electric Transmission Formula Rate Return on Equity (PPL and PPL Electric) On May 21, 2020, PP&L Industrial Customer Alliance (PPLICA) filed a complaint with the FERC alleging that PPL Electric's base return on equity (ROE) of 11.18% used to determine PPL Electric's formula transmission rate is unjust and unreasonable, and proposing an alternative ROE of 8.00% based on its interpretation of FERC Opinion No. 569. However, also on May 21, 2020, the FERC issued Opinion No. 569-A in response to numerous requests for rehearing of Opinion No. 569, which revised the method for analyzing base ROE. On June 10, 2020, PPLICA filed a Motion to Supplement the May 21, 2020 complaint in which PPLICA continued to allege that PPL Electric’s base ROE is unjust and unreasonable, but revised its analysis of PPL Electric's base ROE to reflect the guidance provided in Opinion No. 569-A. The amended complaint proposed an updated alternative ROE of 8.50% and also requested that the FERC preserve the original refund effective date as established by the filing of the original complaint on May 21, 2020. Several parties have filed motions to intervene, including one party who filed Comments in Support of the original complaint. On July 10, 2020, PPL Electric filed its Answer and supporting Testimony to the PPLICA filings arguing that the FERC should deny the original and amended complaints as they are without merit and fail to demonstrate the existing base ROE is unjust and unreasonable. In addition, PPL Electric contended any refund effective date should be set for no earlier than June 10, 2020 and PPLICA's proposed replacement ROE should be rejected. On October 15, 2020, the FERC issued an order on the PPLICA complaints which established hearing and settlement procedures, set a refund effective date of May 21, 2020 and granted the motions to intervene. On November 16, 2020, PPL Electric filed a request for rehearing of the portion of the October 15, 2020 Order that set the May 21, 2020 refund effective date. On December 17, 2020, the FERC issued a Notice of Denial of Rehearing by Operation of Law and Providing for Further Consideration. On February 16, 2021, PPL Electric filed a Petition for Review with the United States Court of Appeals for the District of Columbia Circuit of the portion of the October 15, 2020 Order that set the May 21, 2020 refund effective date. PPL Electric continues to believe its ROE is just and reasonable and that it has meritorious defenses against the original and amended complaints. At this time, PPL Electric cannot predict the outcome of this matter or the range of possible losses, if any, that may be incurred. However, revenue earned from May 21, 2020 through the settlement of this matter may be subject to refund. A change of 50 basis points to the base ROE would impact PPL Electric's net income by approximately $12 million on an annual basis. (PPL, LKE, LG&E and KU) FERC Transmission Rate Filing In 2018, LG&E and KU applied to the FERC requesting elimination of certain on-going credits to a sub-set of transmission customers relating to the 1998 merger of LG&E's and KU's parent entities and the 2006 withdrawal of LG&E and KU from the Midcontinent Independent System Operator, Inc. (MISO), a regional transmission operator and energy market. The application sought termination of LG&E's and KU's commitment to provide certain Kentucky municipalities mitigation for certain horizontal market power concerns arising out of the 1998 LG&E and KU merger and 2006 MISO withdrawal. The amounts at issue are generally waivers or credits granted to a limited number of Kentucky municipalities for either certain LG&E and KU or MISO transmission charges incurred for transmission service received. Due to the development of robust, accessible energy markets over time, LG&E and KU believe the mitigation commitments are no longer relevant or appropriate. In March 2019, the FERC granted LG&E's and KU's request to remove the ongoing credits, conditioned upon the implementation by LG&E and KU of a transition mechanism for certain existing power supply arrangements, subject to FERC review and approval. In July 2019, LG&E and KU proposed their transition mechanism to the FERC and in September 2019, the FERC rejected the proposed transition mechanism and issued a separate order providing clarifications of certain aspects of the March order. In October 2019, LG&E and KU filed requests for rehearing and clarification on the two September orders. In September 2020, the FERC issued its orders in the rehearing process that modified the discussion in, and set aside portions of, the September 2019 orders including adjusting factors impacting the proposed transition mechanism. In October 2020, both LG&E and KU and other parties filed separate motions for rehearing and clarification regarding FERC’s September 2020 orders. In November 2020, the FERC denied the parties’ rehearing requests. In November 2020 and January 2021, LG&E and KU and other parties filed for appeal of the September 2020 and November 2020 orders with the D.C. Circuit Court of Appeals, where certain additional prior petitions for review relating to the proceedings are also pending. On January 15, 2021, LG&E and KU made a filing seeking FERC acceptance of a new proposal for a transition mechanism. LG&E and KU cannot predict the outcome of these proceedings. LG&E and KU currently receive recovery of the waivers and credits provided through other rate mechanisms. (All Registrants) TCJA Impact on FERC Rates In November 2019, the FERC published Final Rules providing that public utility transmission providers include mechanisms in their formula rates to deduct excess ADIT from, or add deficient ADIT to, rate base and adjust their income tax allowances by amortized excess or deficient ADIT, and to make a related compliance filing. In February 2019, PPL Electric filed with the FERC proposed revisions to its transmission formula rate template pursuant to Section 205 of the Federal Power Act and Section 35.13 of the FERC Rules and Regulations. Specifically, PPL Electric proposed to modify its formula rate to permit the return or recovery of excess or deficient ADIT resulting from the TCJA and permit PPL Electric to prospectively account for the income tax expense associated with the depreciation of the equity component of the AFUDC. In April 2019, the FERC accepted the proposed revisions to the formula rate template, which were effective June 1, 2019, as well as the proposed adjustments to ADIT, effective January 1, 2018. In February 2019, in connection with the requirements of the TCJA and Kentucky HB 487, LG&E and KU filed a request with the FERC to amend their transmission formula rates resulting from the laws’ reductions to corporate income tax rates. The FERC approved this request effective June 1, 2019. In 2020, LG&E and KU submitted a compliance filing addressing excess and deficient ADIT. LG&E and KU do not anticipate the impact of the TCJA and Kentucky HB 487 related to their FERC-jurisdictional rates to be significant. Other Purchase of Receivables Program (PPL and PPL Electric) In accordance with a PUC-approved purchase of accounts receivable program, PPL Electric purchases certain accounts receivable from alternative electricity suppliers at a discount, which reflects a provision for uncollectible accounts. The alternative electricity suppliers have no continuing involvement or interest in the purchased accounts receivable. Accounts receivable that are acquired are initially recorded at fair value on the date of acquisition. During 2020, 2019 and 2018, PPL Electric purchased $1.1 billion, $1.2 billion and $1.3 billion of accounts receivable from alternative suppliers.

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- Definition The entire disclosure for public utilities. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Publisher FASB -Name Accounting Standards Codification -Topic 980 -URI http://asc.fasb.org/topic&trid=2156578 + Details
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