KENTUCKY UTILITIES CO

Regulatory Requirements

The Registrants cannot predict the impact that future regulatory requirements may have on their financial condition or results of operations.

Rate Case Proceedings

Rhode Island 2025 (PPL)

On November 26, 2025, RIE filed a request with the RIPUC for an increase in electric and natural gas base distribution rates, and approval of certain regulatory and accounting treatments. In its application, RIE seeks to implement a two-year rate plan. In the first year of the rate plan, RIE's proposed base distribution rates for electric and gas combined are designed to collect additional operating revenue of approximately $181 million ($66 million or 18.2% in electricity revenues and $115 million or 36.4% in gas revenues). In the second year of the rate plan, RIE's proposed base distribution rates for electric and gas combined are designed to collect the proposed base distribution rate increases for electric and gas in the first year of the rate plan and additional operating revenues of approximately $49 million ($17 million or 3.6% in electricity revenues and $32 million or 7.4% in gas revenues).

The application is based on a historical test year of September 1, 2024 through August 31, 2025 and requested an authorized ROE of 10.75%. Subject to RIPUC approval, new rates are expected to become effective on September 1, 2026. Certain counterparties have intervened in the proceeding, and on April 16, 2026, submitted testimony. A ruling from the RIPUC is anticipated during the third quarter of 2026. PPL cannot predict the outcome of the proceeding.

Pennsylvania 2025 (PPL and PPL Electric)

On September 30, 2025, PPL Electric filed a request with the PAPUC for an increase in distribution base rates of approximately $356 million, more than $50 million of which is already included in customer bills through rate recovery mechanisms, and approval of certain regulatory and accounting treatments. The proposed increase in distribution base rates would increase PPL Electric's total annual revenue by approximately 8.6%. The application is based on a fully projected future test year of July 1, 2026 through June 30, 2027 and requested an authorized ROE of 11.3%. Subject to PAPUC approval, new distribution base rates are expected to become effective on July 1, 2026.

On March 5, 2026, PPL Electric reached a non‑unanimous settlement in principle (the settlement) in its distribution rate case. On March 13, 2026, PPL Electric submitted a joint petition with the PAPUC reflecting the settlement to resolve all issues in PPL Electric's base rate proceeding.

The settlement proposed an annual electric base distribution revenue increase of approximately $275 million and does not stipulate a return on equity or capital structure. As part of the settlement, PPL Electric will not increase distribution base rates for two years from the effective date of the new rates. Additionally, the settlement:

•provides for DSIC eligible capital investment (and associated depreciation and tax effects) to be rolled into base rates, and for the DSIC to be reset to zero, capped at 5.0% of annual distribution revenues, upon implementation of new base rates.

•sets the expense from reportable storms recovered through base rates for the Storm Damage Expense Rider (SDER) at $32 million annually beginning July 1, 2026. To the extent eligible reportable storm expenses are above or below this level, over or under collections would be addressed through the SDER during the applicable recovery period.

•supports capitalization of Information Technology (IT) upgrades for planned system implementations and infrastructure costs for shared IT platforms. The total projected cost of these projects is expected to be $54 million, inclusive of AFUDC, through June 30, 2027.

•supports adoption of a new tariff schedule governing service to certain large load customers (including data centers). This new rate class would provide $11 million in support for PPL Electric's residential low-income program.

•provides for enhancements to Customer Assistance Program processes and customer notifications, an increase to the Low-Income Usage Reduction Program annual budget beginning January 1, 2027 of $1.5 million (to a total of $13.5 million) with a rollover mechanism for unspent amounts, and a waiver of reconnection fees for low-income customers beginning July 1, 2027.

The settlement also contains agreed positions regarding certain other tariff, rate, regulatory accounting and other issues raised in the proceedings, as well as recommending approval of all remaining matters as requested by PPL Electric's rate request.

On April 17, 2026, the Administrative Law Judges presiding over the case recommended the settlement be approved without modification. A ruling from the PAPUC is anticipated during the second quarter of 2026. PPL and PPL Electric cannot predict the outcome of the proceeding.

Kentucky 2025 (PPL, LG&E and KU)

On February 16, 2026, the KPSC issued orders approving portions of LG&E's and KU's October 2025 stipulation and recommendation, with modifications. See "Regulatory Matters - Kentucky Activities – Rate Case Proceedings" in Note 7 in PPL's, LG&E's and KU's 2025 Form 10-K for additional information on the filings made by LG&E and KU with the KPSC in 2025.

The KPSC orders provide for increases in annual electricity and gas revenues of $233 million ($59 million and $128 million in electricity revenues at LG&E and KU and $46 million in gas revenues at LG&E.) The orders include authorized returns on equity of 9.775% for base rate purposes and 9.675% for capital rate adjustment mechanisms.

The KPSC orders approve LG&E's and KU's requests for establishment of certain new rate adjustment mechanisms or tariffs, with modifications:

• a temporary Pilot Generation Recovery Adjustment Clause (PGR) to provide recovery of and return on investment of applicable costs of certain new generation and storage assets being built or anticipated to be built by LG&E and KU as authorized in the 2022 CPCN proceeding;

• the inclusion in the PGR of recovery of and return on investment of certain costs associated with a potential extension of the operating life of LG&E's Mill Creek Unit 2 beyond its original 2027 retirement date; and

• an Extremely High Load Factor Tariff for future applicable customers, such as data centers, which includes requirements such as long-term contracts, minimum revenue payments and collateral security structures that help protect the interests of LG&E, KU and of other ratepayers.

The PGR mechanism is similar to the Generation Cost Recovery Adjustment Clause proposed in the stipulation, but restructured by the KPSC to be a pilot adjustment mechanism with a term until the earlier of ten months following the submission of LG&E's and KU's next base rate proceeding or the effective date of new rates in such proceeding, with the expectation that the mechanism would be reviewed in such proceeding. The pilot mechanism will apply to the planned Mill Creek Unit 5, Brown Battery Energy Storage System, Mercer County Solar and Marion County Solar generation-related projects. The KPSC also included Mill Creek Unit 2's potential stay-open costs in the PGR in lieu of approving the stipulation's request for a stand-alone adjustment mechanism for such costs. Finally, the KPSC excluded from coverage under the PGR costs related to Mill Creek Unit 6 and Brown Unit 12 planned new generation assets due to their anticipated in-service dates falling outside of the estimated pilot mechanism's duration, but without prejudice to LG&E and KU seeking recovery of such costs in future proceedings.

The KPSC orders also approved, approved with modifications, or denied in some cases, other requested accounting and rate matters relating to regulatory assets or liabilities, depreciation rates, and other areas.

The rate changes have a retroactive effective date as of January 1, 2026. LG&E and KU applied refunds to customer accounts for amounts billed in excess of the rates approved by the KPSC.

The KPSC orders did not approve the Sharing Mechanism Adjustment Clause that had been requested in the stipulation and made no modifications to the stay out offer by LG&E and KU to refrain from effective base rate increases prior to August 2028.

LG&E and KU filed a request for rehearing on several issues contained in the orders from the KPSC on March 11, 2026, along with a Notice of their Withdrawal from the stipulation. On March 27, 2026, the KPSC issued orders correcting tariff appendices, denying two intervenor rehearing requests, and reopening the dockets to consider LG&E's and KU's request for rehearing. The KPSC has established a procedural schedule with two additional rounds of discovery beginning on April 10, 2026.

PPL, LG&E and KU cannot predict the outcome of this matter.

Virginia 2026 (PPL and KU)

On April 30, 2026, KU filed a request with the VSCC for an increase in Virginia annual base electricity rates of approximately $19 million. KU's request is based on an authorized 10.95% ROE. Subject to regulatory review and approval, new rates would become effective February 1, 2027. PPL and KU cannot predict the outcome of this matter.

Potential Legal Merger of LG&E and KU

Pursuant to prior orders of the KPSC, the LG&E and KU rate case application included an assessment of a potential legal merger of LG&E and KU and concluded a legal merger may be appropriate. On December 30, 2025, LG&E and KU filed a joint update in the rate case proceedings stating that they expected to file necessary applications for merger approval in mid-2026 with the KPSC. On March 31, 2026, LG&E and KU filed an application with the KPSC for approval of the merger and associated accounting, financing and rate mechanism matters. On April 17, 2026, LG&E and KU filed an application with the VSCC for approval of the merger and certain associated matters. LG&E and KU anticipate filing a related application with the VSCC for approval of financing and affiliate transactions in connection with the proposed merger by mid-May 2026. LG&E and KU anticipate filing an application with the FERC for approval of the merger in the second quarter of 2026. Ultimately, any merger would require formal approval from the KPSC, VSCC and FERC, as well as the boards and sole shareholder of both companies.

PPL, LG&E and KU cannot predict the outcome of this matter, including the regulatory proceedings.

Environmental Considerations for Coal-Fired Generation

The businesses of LG&E and KU are subject to extensive federal, state and local environmental laws, rules and regulations, including those pertaining to CCRs, GHG, and ELGs. See Notes 6, 9 and 14 to the Financial Statements for a discussion ofthese significant environmental matters. These and other environmental requirements led PPL, LG&E and KU to retire approximately 1,500 MW of coal-fired generating plants in Kentucky since 2010. As part of the long-term generation planning process, LG&E and KU evaluate a range of factors including the impact of potential stricter environmental regulations, fuel price scenarios, the cost of replacement generation, continued operations and major maintenance costs and the risk of major equipment failures in determining when to retire generation assets.

As a result of environmental requirements and aging infrastructure, LG&E has sought and obtained approval to retire two older coal-fired units at the Mill Creek Plant. Mill Creek Unit 1, with 300 MW of capacity, was retired in 2024. Mill Creek Unit 2, with 297 MW of capacity, was approved to be retired in 2027, subject to certain conditions. On October 28, 2025, in LG&E and KU's 2025 CPCN proceeding, the KPSC declined to rule on a request to extend the operation of Mill Creek Unit 2. The KPSC indicated that a request for a new retirement approval proceeding may be required should LG&E elect to operate Mill Creek Unit 2 beyond its existing approved retirement date and seek to later retire the unit. See "Rate Case Proceedings" in Note 6 to the Financial Statements for additional information.

FERC Transmission Rate Filing

In 2018, LG&E and KU applied to the FERC requesting elimination of certain on-going waivers and 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 U.S. Court of Appeals - D.C. Circuit (D.C. Circuit Court of Appeals) regarding the FERC's orders on the elimination of the mitigation and required transition mechanism. In August 2022, the D.C. Circuit Court of Appeals issued an order remanding the proceedings back to the FERC. On May 18, 2023, the FERC issued an order on remand reversing its 2019 decision and requiring LG&E and KU to refund credits previously withheld, including under such transition mechanism. LG&E and KU filed a petition for review of the FERC's May 18, 2023 order with the D.C. Circuit Court of Appeals and provided refunds in accordance with the FERC order on December 1, 2023. The FERC issued an order on LG&E's and KU's compliance filing on November 16, 2023, and LG&E and KU filed a petition for review of this November 16, 2023 order on February 14, 2024. The FERC issued the substantive order on rehearing on March 21, 2024, reaffirming its prior decision. On August 8, 2025, the D.C. Circuit Court of Appeals issued a procedural ruling vacating the FERC's prior orders and remanded the matter back to the FERC for further proceedings, which are underway. LG&E and KU cannot predict the ultimate outcome of the proceedings or any other post decision process but do not expect the annual impact to have a material effect on their operations or financial condition. LG&E and KU currently receive recovery of certain waivers and credits primarily through existing base rate levels.

(PPL)

Hold Harmless Commitment

As a condition of its approval of the acquisition of RIE in May 2022, the Rhode Island Division of Public Utilities and Carriers (the Division) required PPL to hold harmless Rhode Island customers from the impact of future rate increases resulting from changes in Accumulated Deferred Income Taxes as a result of the Acquisition (the Hold Harmless Commitment). On June 13, 2025, an agreement was entered into by and among RIE, PPL, PPL Rhode Island Holdings and the Division's Advocacy Section (the Hold Harmless Implementation Agreement) to satisfy the Hold Harmless Commitment by providing approximately $155 million in miscellaneous bill credits. On September 10, 2025, the Division issued an order confirming that RIE's provision of proposed miscellaneous bill credits as set forth in the Hold Harmless Implementation Agreement would satisfy the Hold Harmless Commitment. Also on September 10, 2025, the RIPUC opened a docket to evaluate the miscellaneous bill credit proposal set forth in the Hold Harmless Implementation Agreement, including the underlying rate accounting, and required RIE to file a tariff advice with the RIPUC, which RIE filed on October 2, 2025. RIE subsequently filed a notice of withdrawal of its tariff advice filing noting that it would hold in abeyance a comprehensive satisfaction of the Hold Harmless Commitment.

During the first quarter of 2026, RIE re-engaged in discussions with the Division regarding a proposal to satisfy the Hold Harmless Commitment. On April 16, 2026, RIE filed a motion with the RIPUC to reopen the previous docket concerning the Hold Harmless Commitment along with an updated tariff advice which reflects a methodology consistent with the previously proposed miscellaneous bill credits and two potential, alternative methods of allocating the bill credits among customers. The actual amount of miscellaneous bill credits to be issued will vary depending upon the agreed upon cost of capital, timing of the issuance of the credits, and the outcome of the pending distribution rate case proceedings. As proposed, the bill credits would be issued and recorded as a reduction to revenue in the first quarters of 2027 and 2028. On April 17, 2026, the RIPUC approved the motion and consolidated the tariff advice docket with the pending base distribution rate proceeding. PPL cannot predict the outcome of these proceedings.

FY 2027 Gas ISR Plan

On March 27, 2026, the RIPUC approved a capital budget of $161 million. In addition, the RIPUC approved an O&M budget of $17 million for curb-to-curb paving. On March 31, 2026, the RIPUC approved RIE's compliance filing for rates effective April 1, 2026.

FY 2027 Electric ISR Plan

On March 27, 2026, the RIPUC approved a capital budget of $141 million (including $18 million for Advanced Metering Functionality). In addition, the RIPUC approved an O&M budget of $14 million, primarily for vegetation management. On March 31, 2026, the RIPUC approved RIE's compliance filing for rates effective April 1, 2026.