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Utility Rate Regulation | 12 Months Ended
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Dec. 31, 2021
Utility Rate Regulation [Line Items] |
Utility Rate Regulation | 7. Utility Rate Regulation Regulatory Assets and Liabilities (All Registrants) PPL, PPL Electric, 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, 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 recovery of costs as well as 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 and KU) KU's Virginia base rates are calculated based on recovery of costs as well as 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, accumulated deferred income taxes, 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, except accumulated deferred income taxes, 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
| 2021 |  | 2020 |  | 2021 |  | 2020
Current Regulatory Assets: |  |  |  |  |  |  |
Plant outage costs | $ | — |  |  | $ | 46 |  |  | $ | — |  |  | $ | — |
Gas supply clause | 21 |  |  | 4 |  |  | — |  |  | — |
Smart meter rider | 11 |  |  | 17 |  |  | 11 |  |  | 17 |
Transmission formula rate | 6 |  |  | 15 |  |  | 6 |  |  | 15 |
Storm costs | — |  |  | 7 |  |  | — |  |  | 7 |
Fuel adjustment clause | 11 |  |  | — |  |  | — |  |  | — |
Other | 15 |  |  | 10 |  |  | 5 |  |  | 1 |
Total current regulatory assets (a) | $ | 64 |  |  | $ | 99 |  |  | $ | 22 |  |  | $ | 40 |
Noncurrent Regulatory Assets: |  |  |  |  |  |  |
Defined benefit plans | $ | 523 |  |  | $ | 570 |  |  | $ | 256 |  |  | $ | 290 |
Plant outage cost | 54 |  |  | — |  |  | — |  |  | — |
Storm costs | 11 |  |  | 17 |  |  | — |  |  | — |
Unamortized loss on debt | 24 |  |  | 30 |  |  | 4 |  |  | 8 |
Interest rate swaps | 18 |  |  | 23 |  |  | — |  |  | — |
Terminated interest rate swaps | 70 |  |  | 75 |  |  | — |  |  | — |
Accumulated cost of removal of utility plant | 228 |  |  | 240 |  |  | 228 |  |  | 240 |
AROs | 302 |  |  | 300 |  |  | — |  |  | — |
Other | 6 |  |  | 7 |  |  | — |  |  | 3 |
Total noncurrent regulatory assets | $ | 1,236 |  |  | $ | 1,262 |  |  | $ | 488 |  |  | $ | 541 |
| PPL |  | PPL Electric
| 2021 |  | 2020 |  | 2021 |  | 2020
Current Regulatory Liabilities: |  |  |  |  |  |  |
Generation supply charge | $ | 10 |  |  | $ | 21 |  |  | $ | 10 |  |  | $ | 21 |
Transmission service charge | 21 |  |  | 1 |  |  | 21 |  |  | 1 |
Universal service rider | 17 |  |  | 22 |  |  | 17 |  |  | 22 |
TCJA customer refund | 22 |  |  | 11 |  |  | 22 |  |  | 11 |
Act 129 compliance rider | 10 |  |  | 7 |  |  | 10 |  |  | 7 |
Transmission formula rate return on equity (b) | 73 |  |  | — |  |  | 73 |  |  | — |
Economic relief billing rate | 27 |  |  | — |  |  | — |  |  | — |
Other | 2 |  |  | 17 |  |  | — |  |  | 6 |
Total current regulatory liabilities | $ | 182 |  |  | $ | 79 |  |  | $ | 153 |  |  | $ | 68 |
Noncurrent Regulatory Liabilities: |  |  |  |  |  |  |
Accumulated cost of removal of utility plant | $ | 639 |  |  | $ | 653 |  |  | $ | — |  |  | $ | — |
Power purchase agreement - OVEC | 35 |  |  | 43 |  |  | — |  |  | — |
Net deferred taxes | 1,591 |  |  | 1,690 |  |  | 531 |  |  | 560 |
Defined benefit plans | 95 |  |  | 60 |  |  | 28 |  |  | 18 |
Terminated interest rate swaps | 62 |  |  | 66 |  |  | — |  |  | — |
Other | — |  |  | 18 |  |  | — |  |  | — |
Total noncurrent regulatory liabilities | $ | 2,422 |  |  | $ | 2,530 |  |  | $ | 559 |  |  | $ | 578 |
| LG&E |  | KU
| 2021 |  | 2020 |  | 2021 |  | 2020
Current Regulatory Assets: |  |  |  |  |  |  |
Gas supply clause | $ | 21 |  |  | $ | 4 |  |  | $ | — |  |  | $ | — |
Fuel adjustment clause | 4 |  |  | — |  |  | 7 |  |  | — |
Gas line tracker | 3 |  |  | 4 |  |  | — |  |  | — |
Generation formula rate | — |  |  | — |  |  | 2 |  |  | 2 |
Plant outage costs | — |  |  | 12 |  |  | — |  |  | 34 |
Other | 5 |  |  | 3 |  |  | — |  |  | — |
Total current regulatory assets | $ | 33 |  |  | $ | 23 |  |  | $ | 9 |  |  | $ | 36 |
Noncurrent Regulatory Assets: |  |  |  |  |  |  |
Defined benefit plans | $ | 164 |  |  | $ | 174 |  |  | $ | 103 |  |  | $ | 106 |
Storm costs | 8 |  |  | 11 |  |  | 3 |  |  | 6 |
Unamortized loss on debt | 12 |  |  | 13 |  |  | 8 |  |  | 9 |
Interest rate swaps | 18 |  |  | 23 |  |  | — |  |  | — |
Terminated interest rate swaps | 41 |  |  | 44 |  |  | 29 |  |  | 31 |
AROs | 75 |  |  | 85 |  |  | 227 |  |  | 215 |
Plant outage costs | 15 |  |  | — |  |  | 39 |  |  | — |
Other | 4 |  |  | 1 |  |  | 2 |  |  | 3 |
Total noncurrent regulatory assets | $ | 337 |  |  | $ | 351 |  |  | $ | 411 |  |  | $ | 370 |
| LG&E |  | KU
| 2021 |  | 2020 |  | 2021 |  | 2020
Current Regulatory Liabilities: |  |  |  |  |  |  |
Economic relief billing credit | $ | 21 |  |  | $ | — |  |  | $ | 6 |  |  | $ | — |
Fuel adjustment clauses | — |  |  | — |  |  | — |  |  | 5 |
Environmental cost recovery | — |  |  | — |  |  | — |  |  | 4 |
Other | — |  |  | — |  |  | 2 |  |  | 2 |
Total current regulatory liabilities | $ | 21 |  |  | $ | — |  |  | $ | 8 |  |  | $ | 11 |
Noncurrent Regulatory Liabilities: |  |  |  |  |  |  |
Accumulated cost of removal of utility plant | $ | 262 |  |  | $ | 274 |  |  | $ | 377 |  |  | $ | 379 |
Power purchase agreement - OVEC | 24 |  |  | 30 |  |  | 11 |  |  | 13 |
Net deferred taxes | 491 |  |  | 528 |  |  | 569 |  |  | 602 |
Defined benefit plans | 10 |  |  | — |  |  | 57 |  |  | 42 |
Terminated interest rate swaps | 31 |  |  | 33 |  |  | 31 |  |  | 33 |
Other | — |  |  | 17 |  |  | — |  |  | 1 |
Total noncurrent regulatory liabilities | $ | 818 |  |  | $ | 882 |  |  | $ | 1,045 |  |  | $ | 1,070 |
(a)For PPL, these amounts are included in "Other current assets" on the Balance Sheets. (b)See “Regulatory Matters - Federal Matters - PPL Electric Transmission Formula Rate Return on Equity” below for additional information. 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, LG&E and KU) As a result of previous rate case settlements and orders, 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 and settlements are recorded as a regulatory asset. As of December 31, 2021, the balances were $98 million for PPL, $54 million for LG&E and $44 million for KU. As of December 31, 2020, the balances were $79 million for PPL, $44 million for LG&E and $35 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. Storm costs incurred in PPL Electric's territory from a March 2018 storm were amortized through 2021. LG&E's and KU's regulatory assets for storm costs are being amortized through various dates ending in 2031. Unamortized Loss on Debt Unamortized loss on reacquired debt represents losses on long-term debt refinanced, 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 the applicable expenses from reportable storms as compared to the $20 million recovered annually through base rates. Act 129 Compliance Rider In compliance with Pennsylvania's Act 129 of 2008 and implementing regulations, PPL Electric is currently in Phase IV of the energy efficiency and conservation plan which was approved in March 2021. Phase IV allows PPL Electric to recover the maximum $313 million over the five-year period, June 1, 2021 through May 31, 2026. 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 IV 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. PPL Electric's Act 129 Phase III plan ended May 31, 2021 and any over-or under-recovery from customers related to Phase III 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 is being credited back to distribution customers through a temporary negative surcharge and remains in place until PPL Electric files and the PUC approves new base rates. The TCJA is reconcilable, and any over- or under-recovery from customers will be refunded or recovered annually in the subsequent year. (PPL, 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 return on equity of 9.35% 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 power purchases and 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. Economic Relief Billing Credit The Economic Relief Billing Credit represents regulatory liabilities to be returned to customers through June 30, 2022, as agreed to in the Kentucky rate case in recognition of the economic impact of COVID-19. See "Regulatory Matters - Kentucky Activities - Rate Case Proceedings" below for additional information. AROs As discussed in Note 1, for LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal. Power Purchase Agreement - OVEC As a result of purchase accounting associated with PPL's acquisition of LG&E and KU, the fair values of the OVEC power purchase agreement were recorded on the balance sheets of 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 in 2033. Terminated Interest Rate Swaps Net realized gains and losses on all interest rate swaps are recovered 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 From July 1, 2017 through June 30, 2021, plant outage costs in Kentucky were normalized for ratemaking purposes based on an average level of expenses. Plant outage expenses that were greater or less than the average will be collected from or returned to customers, through future base rates. Effective July 1, 2021 under-recovered plant outage costs are being amortized through 2029 for LG&E and KU. Gas Supply Clause (PPL 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 and customer usage 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). 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. Regulatory Matters Kentucky Activities (PPL, 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 represented 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. In recognition of the economic impact of COVID-19, LG&E and KU requested 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 included a request for a CPCN to deploy Advanced Metering Infrastructure across LG&E’s and KU’s service territories in Kentucky. The applications were based on a forecasted test year of July 1, 2021 through June 30, 2022 and requested an authorized return on equity of 10.0%. On April 19, 2021, LG&E and KU entered into an agreement with all intervening parties to the proceedings resolving all matters in their applications, with the explicit exception of LG&E's and KU's net metering proposals. On June 30, 2021 and December 6, 2021, the KPSC issued orders approving the proposed agreement filed in April 2021, with certain modifications. The orders provided for increases in annual revenues of $207 million ($74 million and $110 million in electricity revenues at LG&E and KU and $23 million in gas revenues at LG&E) based on an authorized return on equity of 9.425%. The orders grant an authorized 9.35% return on equity for the ECR and GLT mechanisms and do not modify the requested one-year billing credit. The orders approved the CPCN to deploy Advanced Metering Infrastructure and provide regulatory asset treatment for the remaining net book value of legacy meters upon full implementation of the Advanced Metering Infrastructure program. The orders also approved the establishment of a Retired Asset Recovery (RAR) rider to provide for recovery of and return on the remaining investment in certain electric generating units upon their retirement over a ten-year period following retirement. In respect of the RAR rider, LG&E and KU continue to use currently approved depreciation rates for Mill Creek Units 1 and 2 and Brown Unit 3. The orders also approved a four-year "stay out" commitment from LG&E and KU to refrain from effective base rate increases before July 1, 2025, subject to certain exceptions. On September 24, 2021, the KPSC issued orders providing adjustments to previous net metering proposals. These adjustments did not impact the annual revenue increases. 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. PPL Electric's Phase IV Act 129 Plan was approved by the PUC at its March 25, 2021, public meeting. 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. Federal Matters 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 was unjust and unreasonable. On August 20, 2021, PPL Electric entered into a settlement agreement (the Settlement) with PPLICA and all other parties, including intervenors, with respect to the complaint filed by PPLICA on May 21, 2020. The key aspects of the Settlement include: •changes to PPL Electric’s base ROE: ◦beginning as of May 21, 2020 and continuing through May 31, 2022, the ROE shall be 9.90%; ◦beginning on June 1, 2022 and continuing through May 31, 2023, the ROE shall be 9.95%; ◦beginning on June 1, 2023, the ROE shall be 10.00%, which shall continue in effect unless and until changed as permitted by the terms of the Settlement; •changes the equity component of PPL Electric’s capital structure to be the lower of (i) PPL Electric’s actual equity component, calculated in accordance with the formula rate template, or (ii) 56.00%; •allows modification of the current rate year of June 1 to May 31 to a calendar year of January 1 to December 31; and •allows modification of the current formula rate based on a historic test year to a projected test year. In 2021, PPL Electric recorded a revenue reduction of $78 million ($55 million after-tax), of which $73 million ($52 million after-tax) represents revenue subject to refund for the period May 21, 2020 through November 30, 2021. The reduction recorded includes $28 million ($20 million after-tax) related to the period from May 21, 2020 to December 31, 2020. The $73 million of revenue to be refunded will be returned to customers from January 1, 2022 through May 31, 2022 and is based on the difference between charges that were calculated using the ROE in effect at the time and charges calculated using the revised ROE provided for the Settlement, plus interest at the FERC interest rate. The FERC approved the Settlement on November 5, 2021. Interim rates reflecting the agreed-to-base ROE in the Settlement were effective December 1, 2021. (PPL, 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. In 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, which was subsequently filed, modified, and approved by the FERC in 2020 and 2021. In 2020, LG&E and KU and other parties filed appeals with the D.C. Circuit Court of Appeals regarding FERC's orders on the elimination of the mitigation and required transition mechanism. Oral arguments in the appellate proceeding occurred on February 14, 2022. LG&E and KU cannot predict the outcome of the respective appellate and FERC proceedings. LG&E and KU currently receive recovery of the waivers and credits provided through other rate mechanisms and such rate recovery would be anticipated to be adjusted consistent with potential changes or terminations of the waivers and credits, as such become effective. 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 2021, 2020 and 2019, PPL Electric purchased $1.2 billion, $1.1 billion and $1.2 billion of accounts receivable from alternative suppliers.

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