PPL Corporation

02/20/2026 | Press release | Distributed by Public on 02/20/2026 12:48

Annual Report for Fiscal Year Ending 12-31, 2025 (Form 10-K)

Combined Management's Discussion and Analysis of Financial Condition and Results of Operations
(All Registrants)
This "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" is separately filed by PPL, PPL Electric, LG&E and KU. Information contained herein relating to any individual Registrant is filed by such Registrant solely on its own behalf, and no Registrant makes any representation as to information relating to any other Registrant. The specific Registrant to which disclosures are applicable is identified in parenthetical headings in italics above the applicable disclosure or within the applicable disclosure for each Registrant's related activities and disclosures. Within combined disclosures, amounts are disclosed for individual Registrants when significant.
The following should be read in conjunction with the Registrants' Consolidated Financial Statements and the accompanying Notes. Capitalized terms and abbreviations are defined in the glossary. Dollars are in millions, except per share data, unless otherwise noted.
"Management's Discussion and Analysis of Financial Condition and Results of Operations" includes the following information:
•"Overview" provides a description of each Registrant's business strategy and a discussion of important financial and operational developments.
•"Results of Operations" for all Registrants includes a "Statement of Income Analysis," which discusses significant changes in principal line items on the Statements of Income, comparing 2025 with 2024. For PPL, "Results of Operations" also includes "Segment Earnings," which provides a detailed analysis of earnings by reportable segment. These discussions include the non-GAAP financial measure "Earnings from Ongoing Operations" and provide an explanation of the non-GAAP financial measure and a reconciliation of the measure to the most comparable GAAP measure.
•"Financial Condition - Liquidity and Capital Resources" provides an analysis of the Registrants' liquidity positions and credit profiles. This section also includes a discussion of forecasted sources and uses of cash and rating agency actions.
•"Financial Condition - Risk Management" provides an explanation of the Registrants' risk management programs relating to market and credit risk.
•"Application of Critical Accounting Policies" provides an overview of the accounting policies that are particularly important to the results of operations and financial condition of the Registrants and that require their management to make significant estimates, assumptions and other judgments of inherently uncertain matters.
For comparison of the Registrants' results of operations and cash flows for the years ended December 31, 2024 to December 31, 2023, refer to "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" in the 2024 Form 10-K, filed with the SEC on February 13, 2025.
Overview
For a description of the Registrants and their businesses, see "Item 1. Business."
Business Strategy (All Registrants)
PPL operates four regulated utilities located in Pennsylvania, Kentucky and Rhode Island. Each of these jurisdictions has distinct regulatory structures and each of the utilities has distinct customer classes.
PPL's strategy, which is supported by the other Registrants and subsidiaries, is focused on creating the utilities of the future to drive greater value for our customers and shareowners. Key objectives in support of this strategy include:
•Strengthening the reliability and resilience of our electric and gas networks to improve service and protect against current and future weather and storms.
•Advancing a cleaner energy future affordably and reliably. This includes expanding and modernizing our generation with natural gas, renewables and battery storage, while supporting research and development of low-carbon solutions.
•Driving operational efficiencies to improve customer service and help keep energy affordable.
•Utilizing artificial intelligence and other advanced technologies to inform decision making, optimize asset planning and maintenance and better manage supply and demand on the grid.
•Empowering customers through expanded digital options and improved service.
•Engaging with key stakeholders to strengthen resource adequacy, power economic development, and support the growth and success of the regions we serve.
This strategy supports our mission to provide safe, affordable, reliable and sustainable energy to our customers and competitive, long-term returns to shareowners.
Financial and Operational Developments
Joint Venture Agreement with Blackstone Infrastructure (PPL)
PPL and Blackstone Infrastructure have created a joint venture to build, own and operate new electricity generation stations to power data centers in Pennsylvania under long-term energy services agreements (ESAs) to address underlying resource adequacy and affordability concerns in Pennsylvania and PJM more broadly. Construction of new generation stations will require the execution of ESAs with data center developers, including hyperscalers, or the regulated utilities in Pennsylvania. PPL owns 51% of the joint venture interest and Blackstone Infrastructure owns 49%. The joint venture is actively engaged with hyperscalers, landowners, natural gas pipeline companies and turbine manufacturers, and has secured multiple land parcels to enable this new generation build out; however, no ESAs with hyperscalers have been signed as of the filing date of this Form 10-K.
Regulatory Requirements
(All Registrants)
The Registrants cannot predict the impact that future regulatory requirements may have on their financial condition or results of operations.
Rate Case Proceedings
(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. A ruling from the RIPUC is anticipated during the third quarter of 2026. PPL cannot predict the outcome of the proceeding.
See "Regulatory Matters - Rhode Island Activities - Hold Harmless Implementation Agreement" in Note 7 to the Financial Statements for discussion on an additional rate making initiative to mitigate customer rate impacts.
(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 rates are expected to become effective on July 1, 2026. Certain counterparties have intervened in the proceeding. A ruling from the PAPUC is anticipated during the second quarter of 2026. PPL and PPL Electric cannot predict the outcome of the proceeding.
(PPL, LG&E and KU)
On May 30, 2025, LG&E and KU filed requests with the KPSC for an increase in annual electricity and gas revenues of approximately $391 million ($105 million and $226 million in electricity revenues at LG&E and KU and $60 million in gas revenues at LG&E) and approval of certain regulatory and accounting treatments. The revenue increases would be an increase of 8.3% and 11.5% in electricity revenues at LG&E and KU, and an increase of 14.0% in gas revenues at LG&E.
The applications were based on a forecasted test year of January 1, 2026 through December 31, 2026 and requested an authorized ROE of 10.95%. New interim rates became effective on January 1, 2026, subject to refund pursuant to the KPSC's final order. Certain counterparties have intervened in the proceedings.
On October 20, 2025, LG&E and KU filed with the KPSC a stipulation and recommendation (the agreement) regarding a proposed resolution of issues with a majority of the intervenors in the proceedings.
Under the agreement, the parties proposed that the KPSC should issue orders granting a revised increase in annual electricity and gas revenues of approximately $235 million ($58 million and $132 million in electricity revenues at LG&E and KU and $45 million in gas revenues at LG&E.) The agreement proposed a revised authorized ROE of 9.90%.
The agreement proposed a "stay out" commitment from LG&E and KU to refrain from effective base rate increases before August 1, 2028, subject to certain exceptions. In connection with the stay out period, the agreement also proposed the establishment of two new rate adjustment clause mechanisms, a Generation Cost Recovery Adjustment Clause (GCR) and a Sharing Mechanism Adjustment Clause (SM).
The proposed GCR mechanism would provide LG&E and KU recovery of and return on investment of covered costs (excluding fuel amounts, which LG&E and KU can recover via an existing rate mechanism) of relevant new generation and energy storage assets authorized in the 2022 and 2025 CPCN proceedings (excluding the Mill Creek Unit 6 NGCC, see "2025 CPCN" for more information regarding the Mill Creek Unit 6 NGCC) as they are placed in service.
The proposed SM mechanism would address any base rate revenue deficiency or surplus during the final thirteen months of the stay out period, July 2027 through July 2028, below or above a suggested ROE band of 9.40% to 10.15%. Any such base rate revenue deficiency or surplus would be collected from or returned to customers over a thirteen-month billing period beginning November 2028.
Following issuance of the 2025 CPCN Order, LG&E and KU filed supplemental testimony with the KPSC in the rate case proceedings seeking recovery of the Mill Creek Unit 2 stay open costs through a proposed additional rate adjustment clause mechanism.
The agreement further proposed that LG&E and KU use regulatory deferral accounting for actual expenses above or below base rate levels for certain expenses including: pension and post-retirement benefits, storm restoration, vegetation management, transmission waivers and credits, and gas line or well activities, with recovery of such deferred asset or liability amounts to be addressed in future rate cases.
On February 16, 2026, the KPSC issued orders approving portions of the October 2025 stipulation and recommendation, with modifications.
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 GCR 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. Consistent with authorized rate case procedures, LG&E and KU will refund to customers amounts billed in excess of the final approved rates within sixty days.
The KPSC orders did not approve the SM 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 and all intervenors have rights to request rehearing or appeal of the orders of the KPSC and because the KPSC orders modified or denied terms of the proposed stipulation, LG&E and KU and all stipulating parties have the right to withdraw from the stipulation.
LG&E and KU continue to evaluate the details contained in the orders and related matters as they consider next steps. PPL, LG&E and KU cannot predict the outcome of this matter.
In addition, 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 filed a joint update with KU in the rate case proceedings stating that it expects to file necessary applications for merger approval in mid-2026 with the KPSC. Ultimately, formal approval for a merger would be required from the KPSC, VSCC and FERC via subsequent regulatory applications.
(PPL, LG&E and KU)
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 7, 12and 18to the Financial Statements for a discussion of these significant environmental matters. These and other environmental requirements led PPL, LG&E and KU to retire approximately1,500 MWof 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 7to the Financial Statements for additional information.
On October 4, 2024, LG&E submitted an application related to the retirement of Mill Creek Unit 1, which occurred on December 31, 2024, requesting recovery of associated costs under the RAR. On February 24, 2025, the KPSC issued an order approving LG&E's cost recovery for Mill Creek Unit 1 under the RAR of $125 million and related amounts were included in bills beginning in May 2025. See Note 7to the Financial Statements for additional information on the Mill Creek Unit 1 RAR.
2025 CPCN
On February 28, 2025, LG&E and KU filed an application with the KPSC regarding certain future plans for new generation and generation-related construction matters. The proposals included in the application were intended to serve anticipated load growth, including from potential data center demand in LG&E's or KU's service territory. The proposals did not include retirements of coal or other fossil-fueled plants, which would require additional KPSC approval procedures under Kentucky legislation enacted in 2023 and 2024.
LG&E and KU submitted a joint application to the KPSC for approval of certain certificates of public convenience and necessity, site compatibility certificates, and accounting treatment, where applicable, relating to a number of generation-related plans or projects that generally are expected to become operational or established within the next six years. The aggregate projected capital expenditures associated with these proposals were expected to be $3.7 billion. The application included proposals to build:
•a 645 MW NGCC generation unit at KU's E.W. Brown station (Brown Unit 12),
•a 645 MW NGCC generation unit at LG&E's Mill Creek station (Mill Creek Unit 6),
•a four-hour 400 MW (1600 MWh total) battery energy storage system (BESS) at LG&E's Cane Run station, and
•a selective catalytic reduction (SCR) environmental facility at KU's Ghent station Unit 2 (Ghent Unit 2).
The new NGCC units are anticipated to be wholly owned by LG&E and the BESS unit jointly owned by LG&E (32%) and KU (68%), with actual project costs allocated consistent with LG&E's and KU's ultimate ownership shares and existing shared dispatch, cost allocation, tariff or other frameworks. The proposed Mill Creek Unit 6 NGCC is in addition to a new NGCC unit currently under construction at that location (Mill Creek Unit 5).
The filing also noted projected in service dates for the projects, including the Brown Unit 12 NGCC in 2030, the Mill Creek Unit 6 NGCC in 2031, the Cane Run BESS in 2028 and the Ghent Unit 2 SCR in 2028.
On July 29, 2025, LG&E and KU filed with the KPSC a stipulation and recommendation regarding a proposed resolution of issues with several of the intervenors in the CPCN proceeding (stipulation). The stipulation recommended to the KPSC the approval of the large majority of LG&E's and KU's requested generation-related projects and associated accounting matters, subject to certain changes. Under the stipulation, the parties agreed the KPSC should issue an order granting a CPCN for the proposed: (a) Brown Unit 12 NGCC; (b) Mill Creek Unit 6 NGCC; and (c) Ghent Unit 2 SCR. In addition, the proposal to build the $775 million Cane Run BESS would be withdrawn without prejudice, the relevant costs regarding the proposed $1.4 billion Mill Creek Unit 6 NGCC would be recovered through a new rate adjustment clause mechanism, the retirement date for the existing Mill Creek Unit 2 coal unit would be extended from 2027 to the operational date of the proposed Mill Creek Unit 6 NGCC or afterwards, subject to relevant future economic analysis, regulatory or environmental authorizations, and the relevant costs to continue to operate the Mill Creek Unit 2 coal unit would be recovered through a new rate adjustment clause mechanism. The stipulation also contained provisions relating to regulatory asset accounting, proposed data center tariffs, future renewable power requests-for-proposals and other matters. LG&E and KU would retain the right to seek approval of the potentially withdrawn Cane Run BESS or similar substitute project in future regulatory proceedings.
On October 28, 2025, the KPSC issued an order approving much of LG&E's and KU's July 2025 stipulation, with certain modifications. The order granted the requested CPCNs and site-related permits to construct the proposed Brown Unit 12 NGCC, Mill Creek Unit 6 NGCC, and Ghent Unit 2 SCR. The order authorized inclusion of relevant costs of the Ghent Unit 2 SCR in KU's existing environmental cost recovery rate mechanism. The order established a separate monitoring case to receive and consider information during the construction of Mill Creek Unit 6 NGCC.
The order approved requests regarding regulatory asset deferral accounting treatment for certain AFUDC related amounts and noted the KPSC's expectation that the stipulating parties would follow through with their commitments regarding tariffs and power supply contracts related to potential future data center or high load customers in LG&E's and KU's pending rate proceedings. The order also approved other elements of the stipulation or the originally-filed application, with minor modifications.
The KPSC decided not to approve LG&E's and KU's proposed new rate adjustment cost recovery mechanisms for certain costs associated with Mill Creek Unit 6 NGCC and costs associated with operating the Mill Creek Unit 2 coal plant beyond its original retirement date in 2027. However, the denials were without prejudice to resubmission and the KPSC encouraged the parties to provide additional evidence on such matters in separate proceedings. LG&E and KU provided such evidence addressing recovery of the Mill Creek Unit 2 stay open costs in their pending rate case proceedings. Recovery of Mill Creek Unit 6 costs will be addressed in a future proceeding. The KPSC declined to rule on the matter related to the retirement date of Mill Creek Unit 2 coal plant. 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.
In light of the conditional withdrawal in the stipulation, the order did not include a CPCN for the Cane Run BESS. LG&E and KU retain the right to seek approval of the Cane Run BESS project or similar substitute projects at any time in future regulatory proceedings.
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. 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 Implementation Agreement
As a condition of its approval of the acquisition of RIE in May 2022, the Rhode Island Division of Public Utilities and Carriers 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 Rhode Island Division of Public Utilities and Carriers Advocacy Section (the Hold Harmless Implementation Agreement) to satisfy the Hold Harmless Commitment by providing approximately $155 million in miscellaneous bill credits issued to customers, with approximately $74 million to be issued in the first quarter of 2026 and approximately $81 million to be issued in the first quarter of 2027. The bill credits would be recorded as a reduction to revenue in the periods in which the credits are applied to customers' bills. On September 10, 2025, the Rhode Island Division of Public Utilities and Carriers 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. After responding to discovery in that proceeding and before the evidentiary hearing was held or convened, RIE 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 at this time. As a result of RIE's filing the notice of withdrawal, the Commission cancelled the evidentiary hearing. The docket remains open, but there has been no further activity since RIE's withdrawal of the tariff advice and the RIPUC's cancellation of the evidentiary hearing. PPL cannot predict whether there will be any further proceedings on the docket or the outcome of any further proceedings that may occur.
Winter Bill Volatility Docket
At an Open Meeting on November 24, 2025, the RIPUC approved several measures to help mitigate winter bill increases for electric customers. First, the RIPUC approved miscellaneous bill credits for all residential electric customers of $23.54 per month for January, February, and March 2026. Second, the RIPUC paused the Storm Fund Replenishment Factor for usage on and after January 1, 2026, subject to further review through the 2026 Annual Retail Rate Filing. Third, the RIPUC paused the electric Energy Efficiency Charge for usage beginning January 1, 2026 through March 31, 2026. To offset the costs of the miscellaneous bill credits, the RIPUC directed RIE to apply the December 31, 2025 electric Energy Efficiency fund balance, net of any earned incentives, and directed RIE to transfer $11 million from the storm fund balance. The RIPUC approved future cost recovery for RIE of any unfunded balance of the miscellaneous bill credits through future identified offsets and/or a reconciling recovery mechanism to be determined in conjunction with the 2026 electric retail rate filing to allow recovery by December 31, 2026. Any remaining unfunded balance shall accrue at RIE's weighted average cost of capital.
FY 2027 Gas ISR Plan
On December 22, 2025, RIE filed its FY 2027 Gas ISR Plan with the RIPUC with a budget of $184 million that primarily included $166 million of capital investment spend and $17 million for spending on curb-to-curb paving. A decision from the RIPUC on the Plan is expected by March 31, 2026. RIE cannot predict the outcome of this matter.
FY 2027 Electric ISR Plan
On December 22, 2025, RIE filed its FY 2027 Electric ISR Plan with the RIPUC with a budget that primarily included $154 million of capital investment spend (including $18 million for Advanced Metering Functionality) and $13 million of vegetation operation and maintenance spend. A decision from the RIPUC is expected by March 31, 2026. RIE cannot predict the outcome of this matter.
DSIC Petition (PPL and PPL Electric)
On April 26, 2024, PPL Electric filed a Petition with the PAPUC requesting that the PAPUC waive PPL Electric's DSIC cap of 5% of billed revenues and increase the maximum allowable DSIC to 9% for bills rendered on or after January 1, 2025. On February 28, 2025, the PAPUC issued its written order permitting PPL Electric to increase its DSIC cap from 5% to 7.5% for bills rendered on or after March 13, 2025 until the effective date of rates established in PPL Electric's next base rate case or the end of the PPL Electric's 2023-2027 Long-term Infrastructure Improvement Plan, whichever occurs first, at which time it will return to 5%.
Results of Operations
(PPL)
The "Statement of Income Analysis" discussion below describes significant changes in principal line items on the Statements of Income, comparing 2025 with 2024. The "Segment Earnings" discussions provide a review of results by reportable segment. These discussions include the non-GAAP financial measure "Earnings from Ongoing Operations" and provide an explanation of the non-GAAP financial measure and a reconciliation of the measure to the most comparable GAAP measure.
(PPL Electric, LG&E and KU)
A "Statement of Income Analysis" is presented separately for PPL Electric, LG&E and KU. The "Statement of Income Analysis" discussion below describes significant changes in principal line items on the Statements of Income, comparing 2025 with 2024. The results of operations section for PPL Electric, LG&E and KU is presented in a reduced disclosure format in accordance with General Instructions (I)(2)(a) of Form 10-K.
PPL: Statement of Income Analysis and Segment Earnings
Statement of Income Analysis
Net income for the years ended December 31 includes the following results:
Change
2025 2024 2025 vs. 2024
Operating Revenues $ 9,042 $ 8,462 $ 580
Operating Expenses
Operation
Fuel 855 783 72
Energy purchases 1,892 1,679 213
Other operation and maintenance 2,431 2,607 (176)
Depreciation 1,312 1,279 33
Taxes, other than income 423 374 49
Total Operating Expenses 6,913 6,722 191
Operating Income 2,129 1,740 389
Other Income (Expense) - net 151 114 37
Interest Expense 808 738 70
Income Before Income Taxes 1,472 1,116 356
Income Taxes 291 228 63
Net Income $ 1,181 $ 888 $ 293
Operating Revenues
The increase (decrease) in operating revenues was due to:
2025 vs. 2024
PPL Electric distribution volumes (a) $ 34
PPL Electric PLR (b) 174
PPL Electric transmission formula rate (c) 45
LG&E volumes (d) 15
LG&E fuel and other energy purchases (e) 67
LG&E off-system sales (f) 11
KU volumes (d) 34
KU fuel and other energy purchases (g) 31
KU off-system sales (f) 18
RIE energy purchases and other recoveries (h) 140
RIE capital investment 20
Other (9)
Total $ 580
(a)The increase was primarily due to weather and higher other usage in 2025.
(b)The increase was primarily due to higher energy prices, more PLR customers and higher customer volumes due to weather and other higher usage.
(c)The increase was primarily due to returns on additional transmission capital investments and return of depreciation expense.
(d)The increases were primarily due to weather.
(e)The increase was primarily due to higher recoveries of fuel expenses and energy purchases.
(f)The increases were primarily due to higher volumes.
(g)The increase was primarily due to higher recoveries of fuel expenses.
(h)The increase was primarily due to higher recoveries of energy purchases primarily due to net metering credits, transmission expenses and gross earnings taxes
Fuel
Fuel expense increased $72 million in 2025 compared with 2024, primarily due to a $40 million increase in commodity costs and a $32 million increase in volumes due to weather.
Energy Purchases
The increase (decrease) in energy purchases was due to:
2025 vs. 2024
PPL Electric PLR volumes $ 57
PPL Electric PLR prices 92
LG&E commodity costs 14
LG&E volumes 23
RIE net metering 19
Other 8
Total $ 213
Other Operation and Maintenance
The increase (decrease) in other operation and maintenance was due to:
2025 vs. 2024
PPL Electric DER projects impairment (a) $ (21)
PPL Electric vegetation management expenses (14)
PPL Electric bad debt expenses (21)
PPL Electric storm expenses (13)
RIE gas maintenance expenses 25
RIE transmission expenses 62
RIE integration related expenses (b) (57)
RIE customer service expenses 27
RIE pension alignment (c) 22
IT costs (d) 76
Transition costs associated with RIE (e) (236)
Other (26)
Total $ (176)
(a)2024 impairment of DER project costs associated with a pilot solar program for which PPL will not seek regulatory recovery.
(b)Certain transition services agreement costs in 2024 for IT systems that will not be part of PPL's ongoing operations.
(c)The increase is primarily due to a reclassification of the pension adjustment mechanism to align with PPL's accounting for other revenue related recovery items.
(d)Primarily costs associated with PPL's restructuring and rebuilding of its IT infrastructure, organization and systems.
(e)See Note 9 to the Financial Statements for additional information.
Interest Expense
The increase (decrease) in interest expense was due to:
2025 vs. 2024
Long-term debt (a) $ 47
Short-term debt 13
Other 10
Total $ 70
(a)The increase was primarily due to increased borrowings, partially offset by debt extinguishment gains resulting from affiliated debt repurchases. See Note 8 to the Financial Statements for additional information.
Income Taxes
The increase (decrease) in income taxes was due to:
2025 vs. 2024
Federal tax on change in pre-tax income $ 75
State income taxes 8
Income tax credits (8)
Amortization of (excess)/deficient deferred taxes (5)
AFUDC Equity (10)
Other 3
Total $ 63
See Note 6 to the Financial Statements for additional information on income taxes.
Segment Earnings
PPL's Net Income (Loss) by reportable segments was as follows:
Change
2025 2024 2025 vs. 2024
Kentucky Regulated $ 674 $ 620 $ 54
Pennsylvania Regulated 639 574 65
Rhode Island Regulated 85 109 (24)
Corporate and Other (a) (217) (415) 198
Net Income (Loss) $ 1,181 $ 888 $ 293
(a)Primarily represents financing and certain other costs incurred at the corporate level that have not been allocated or assigned to the segments, which are presented to reconcile segment information to PPL's consolidated results.
Earnings from Ongoing Operations
Management utilizes "Earnings from Ongoing Operations" as a non-GAAP financial measure that should not be considered as an alternative to net income, an indicator of operating performance determined in accordance with GAAP. PPL believes that Earnings from Ongoing Operations is useful and meaningful to investors because it provides management's view of PPL's earnings performance as another criterion in making investment decisions. In addition, PPL's management uses Earnings from Ongoing Operations in measuring achievement of certain corporate performance goals, including targets for certain executive incentive compensation. Other companies may use different measures to present financial performance.
Earnings from Ongoing Operations is adjusted for the impact of special items. Special items are presented in the financial tables on an after-tax basis with the related income taxes on special items separately disclosed. Income taxes on special items, when applicable, are calculated based on the statutory tax rate of the entity where the activity is recorded. Special items may include items such as:
• Gains and losses on sales of assets not in the ordinary course of business.
• Impairment charges.
• Significant workforce reduction and other restructuring effects.
• Acquisition and divestiture-related adjustments.
• Other charges or credits that are, in management's view, non-recurring or otherwise not reflective of the company's ongoing operations.
PPL's Earnings from Ongoing Operations by reportable segment were as follows:
Change
2025 2024 2025 vs. 2024
Kentucky Regulated $ 693 $ 624 $ 69
Pennsylvania Regulated 640 607 33
Rhode Island Regulated 142 155 (13)
Corporate and Other (131) (136) 5
Earnings from Ongoing Operations $ 1,344 $ 1,250 $ 94
See "Reconciliation of Earnings from Ongoing Operations" below for a reconciliation of this non-GAAP financial measure to Net Income.
Kentucky Regulated Segment
The Kentucky Regulated segment consists primarily of LG&E's and KU's regulated electricity generation, transmission and distribution operations, as well as LG&E's regulated distribution and sale of natural gas.
Net Income and Earnings from Ongoing Operations include the following results:
Change
2025 2024 2025 vs. 2024
Operating Revenues $ 3,760 $ 3,562 $ 198
Fuel 855 783 72
Energy purchases 214 176 38
Other operation and maintenance 818 803 15
Depreciation 717 710 7
Taxes, other than income 102 99 3
Total Operating Expenses 2,706 2,571 135
Other Income (Expense) - net 53 29 24
Interest Expense 264 240 24
Income Taxes 169 160 9
Net Income 674 620 54
Less: Special Items (19) (4) (15)
Earnings from Ongoing Operations $ 693 $ 624 $ 69
The following after-tax gains (losses), which management considers special items, impacted the Kentucky Regulated segment's results and are excluded from Earnings from Ongoing Operations:
Income Statement Line Item 2025 2024
FERC transmission credit refund, net of tax of $0 (a)
Operating Revenues $ - $ 1
ECR beneficial reuse transition adjustment, net of tax of $2 (b)
Operating Revenues - (4)
Strategic corporate initiatives, net of tax of $0 (c)
Other operation and maintenance - (1)
IT transformation, net of tax of $5 (d)
Other operation and maintenance (16) -
Office relocation and related costs, net of tax of $1 (e)
Other operation and maintenance (3) -
Total $ (19) $ (4)
(a)Prior period impact related to a FERC refund order.
(b)Prior period impact for an ECR mechanism revenue adjustment related to a KPSC order.
(c)Costs incurred related to PPL's corporate centralization efforts.
(d)Costs associated with PPL's restructuring and rebuilding of its IT infrastructure, organization and systems.
(e)Certain costs related to the relocation of corporate offices.
The changes in the components of the Kentucky Regulated segment's results between these periods were due to the factors set forth below, which exclude the items that management considers special.
2025 vs. 2024
Operating Revenues $ 194
Fuel (72)
Energy purchases (38)
Other operation and maintenance 9
Depreciation (7)
Taxes, other than income (3)
Other Income (Expense) - net 24
Interest Expense (24)
Income Taxes (14)
Earnings from Ongoing Operations 69
Special Items, after-tax (15)
Net Income $ 54
•Higher operating revenues in 2025 compared to 2024 primarily due to a $98 million increase in recoveries of fuel and energy purchases, a $50 million increase in sales volumes due to weather and a $29 million increase in off-system sales.
•Higher fuel expense in 2025 compared to 2024 primarily due to a $40 million increase in commodity costs and a $32 million increase in volumes due to weather.
•Higher energy purchases in 2025 compared to 2024 primarily due to a $24 million increase in volumes primarily due to weather and a $14 million increase in commodity costs.
Pennsylvania Regulated Segment
The Pennsylvania Regulated segment includes the regulated electricity transmission and distribution operations of PPL Electric.
Net Income and Earnings from Ongoing Operations include the following results:
Change
2025 2024 2025 vs. 2024
Operating Revenues $ 3,113 $ 2,876 $ 237
Energy purchases 876 721 155
Other operation and maintenance 630 705 (75)
Depreciation 413 401 12
Taxes, other than income 151 131 20
Total Operating Expenses 2,070 1,958 112
Other Income (Expense) - net 48 45 3
Interest Income from Affiliate 9 33 (24)
Interest Expense 257 246 11
Income Taxes 204 176 28
Net Income 639 574 65
Less: Special Items (1) (33) 32
Earnings from Ongoing Operations $ 640 $ 607 $ 33
The following after-tax gains (losses), which management considers special items, impacted the Pennsylvania Regulated segment's results and are excluded from Earnings from Ongoing Operations:
Income Statement Line Item 2025 2024
PPL Electric billing issue, net of tax of $5 (a)
Other operation and maintenance $ - $ (13)
Strategic corporate initiatives, net of tax of $2 (b)
Other operation and maintenance - (5)
DER projects impairment, net of tax of $6 (c)
Other operation and maintenance - (15)
Office relocation and related costs, net of tax of $0 (d)
Other operation and maintenance (2) -
Office relocation and related costs (e) Income Taxes 5 -
IT transformation, net of tax of $1 (f)
Other operation and maintenance (4) -
Total $ (1) $ (33)
(a)Certain expenses related to billing issues.
(b)Costs incurred related to PPL's corporate centralization efforts.
(c)Impairment of DER project costs associated with a pilot solar program for which PPL will not seek regulatory recovery.
(d)Certain costs related to the relocation of corporate offices.
(e)Tax benefit related to the sale of a corporate office.
(f)Costs associated with PPL's restructuring and rebuilding of its IT infrastructure, organization and systems.
The changes in the components of the Pennsylvania Regulated segment's results between these periods are due to the factors set forth below, which exclude the items that management considers special.
2025 vs. 2024
Operating Revenues $ 237
Energy purchases (155)
Other operation and maintenance 36
Depreciation (12)
Taxes, other than income (20)
Other Income (Expense) - net 3
Interest Income from Affiliate (24)
Interest Expense (11)
Income Taxes (21)
Earnings from Ongoing Operations 33
Special Items, after-tax 32
Net Income $ 65
•Higher operating revenues in 2025 compared to 2024 primarily due to a $174 million increase in PLR, a $45 million increase in transmission formula rate revenue and a $34 million increase in distribution volumes.
•Higher energy purchases in 2025 compared to 2024 primarily due to a $92 million increase in PLR prices and a $57 million increase in PLR volumes.
•Lower other operation and maintenance expense in 2025 compared to 2024 primarily due to a $14 million decrease in vegetation management expenses and a $13 million decrease in storm expenses.
Rhode Island Regulated Segment
The Rhode Island Regulated segment consists primarily of the regulated electricity transmission and distribution operations and regulated distribution and sale of natural gas conducted by RIE.
Net Income and Earnings from Ongoing Operations include the following results:
Change
2025 2024 2025 vs. 2024
Operating Revenues $ 2,168 $ 2,024 $ 144
Energy purchases 802 782 20
Other operation and maintenance 851 731 120
Depreciation 177 165 12
Taxes, other than income 170 144 26
Total Operating Expenses 2,000 1,822 178
Other Income (Expense) - net 33 20 13
Interest Income from Affiliate 3 4 (1)
Interest Expense 111 95 16
Income Taxes 8 22 (14)
Net Income 85 109 (24)
Less: Special Items (57) (46) (11)
Earnings from Ongoing Operations $ 142 $ 155 $ (13)
The following after-tax gains (losses), which management considers special items, impacted the Rhode Island Regulated segment's results and are excluded from Earnings from Ongoing Operations:
Income Statement Line Item 2025 2024
Acquisition integration, net of tax of $1 (a)
Operating Revenues $ (4) $ -
Post TSA adjustments, net of tax of $3 (b)
Operating Revenues (12) -
Acquisition integration, net of tax of $0, $13 (a)
Other operation and maintenance (1) (45)
IT transformation, net of tax of $2 (c)
Other operation and maintenance (8) -
Post TSA adjustments, net of tax of $1 (b)
Other operation and maintenance (4) -
Customer system integration impacts, net of tax of $4 (d)
Other operation and maintenance (15) -
Acquisition integration, net of tax of ($2), $0 (a)
Other Income (Expense) - net 7 (1)
Energy efficiency programs settlement, net of tax of $2 (e)
Other Income (Expense) - net (6) -
Post TSA adjustments, net of tax of $2 (b)
Other Income (Expense) - net (9) -
Post TSA adjustments, net of tax of $1 (b)
Interest Expense (5) -
Total $ (57) $ (46)
(a)2025 primarily includes a final transition services agreement settlement and certain other acquisition related items. 2024 primarily includes certain transition services agreement costs for IT systems that will not be part of PPL's ongoing operations.
(b)Adjustments related to account reconciliations and process alignment subsequent to the end of the transition services agreement associated with the acquisition of RIE.
(c)Costs associated with PPL's restructuring and rebuilding of its IT infrastructure, organization and systems.
(d)Certain collection process costs incurred due to the timing and implementation of the customer system integration.
(e)See Note 12 to the Financial Statements for additional information.
The changes in the components of the Rhode Island Regulated segment's results between these periods are due to the factors set forth below, which exclude the items that management considers special.
2025 vs. 2024
Operating Revenues $ 165
Energy purchases (20)
Other operation and maintenance (142)
Depreciation (12)
Taxes, other than income (26)
Other Income (Expense) - net 23
Interest Income from Affiliate (1)
Interest Expense (10)
Income Taxes 10
Earnings from Ongoing Operations (13)
Special Items, after-tax (11)
Net Income $ (24)
•Higher operating revenues in 2025 compared to 2024 primarily due to a $140 million increase primarily from recovery of transmission expenses, gross earnings taxes and net metering credits and a $20 million increase related to capital investments.
•Higher energy purchases in 2025 compared to 2024 primarily due to an increase in net metering.
•Higher other operation and maintenance expense in 2025 compared to 2024 primarily due to a $62 million increase in transmission expenses, a $30 million increase in IT costs, a $27 million increase in customer service costs, a $25 million increase in gas maintenance expenses and a $22 million increase due to a reclassification of the pension adjustment mechanism to align with PPL's accounting for other revenue related recovery items, partially offset by a $22 million decrease in bad debt expenses.
•Higher depreciation in 2025 compared to 2024 primarily due to an increase in PP&E additions, net of retirements.
•Higher taxes, other than income in 2025 compared to 2024 primarily due to an increase in gross earnings taxes.
•Higher other income (expense) - net in 2025 compared to 2024 primarily due to a reclassification of the pension adjustment mechanism to align with PPL's accounting for other revenue related recovery items.
•Higher interest expense in 2025 compared to 2024 primarily due to increased borrowings.
•Lower income taxes in 2025 compared to 2024 primarily due to $5 million of lower pre-tax income and a $4 million deferred tax adjustment.
Reconciliation of Earnings from Ongoing Operations
The following tables contain after-tax gains (losses), in total, which management considers special items, that are excluded from Earnings from Ongoing Operations, and a reconciliation to PPL's "Net Income" for the years ended December 31.
2025
KY
Regulated 		PA
Regulated 		RI
Regulated 		Corporate
and Other 		Total
Net Income (Loss) $ 674 $ 639 $ 85 $ (217) $ 1,181
Less: Special Items (expense) benefit:
Talen litigation costs, net of tax of ($1) (a)
- - - 3 3
Acquisition integration, net of tax of $0, $15 (b)
- - 2 (56) (54)
IT transformation, net of tax of $5, $1, $2, $9 (c)
(16) (4) (8) (33) (61)
Energy efficiency programs settlement, net of tax of $2 (d)
- - (6) - (6)
Office relocation and related costs, net of tax of $1, $5 (e)
(3) 3 - - -
Post TSA adjustments, net of tax of $8 (f)
- - (30) - (30)
Customer system integration impacts, net of tax of $4 (g)
- - (15) - (15)
Total Special Items (19) (1) (57) (86) (163)
Earnings from Ongoing Operations $ 693 $ 640 $ 142 $ (131) $ 1,344
(a)PPL incurred legal expenses and received insurance reimbursement related to litigation associated with its former affiliate, Talen Montana, LLC and certain affiliated entities.
(b)Rhode Island Regulated primarily includes a final transition services agreement settlement and certain other acquisition related items. Corporate and Other primarily includes integration and related costs associated with the acquisition of RIE.
(c)Costs associated with PPL's restructuring and rebuilding of its IT infrastructure, organization and systems.
(d)See Note 12 to the Financial Statements for additional information.
(e)Certain costs and tax benefits related to the relocation of corporate offices.
(f)Adjustments related to account reconciliations and process alignment subsequent to the end of the transition services agreement associated with the acquisition of RIE.
(g)Certain collection process costs incurred due to the timing and implementation of the customer system integration.
2024
KY
Regulated 		PA
Regulated 		RI
Regulated 		Corporate
and Other 		Total
Net Income (Loss) $ 620 $ 574 $ 109 $ (415) $ 888
Less: Special Items (expense) benefit:
Talen litigation costs, net of tax of $1 (a)
- - - (2) (2)
Strategic corporate initiatives, net of tax of $0, $2, $2 (b)
(1) (5) - (5) (11)
Acquisition integration, net of tax of $13, $66 (c)
- - (46) (250) (296)
PPL Electric billing issue, net of tax of $5 (d)
- (13) - - (13)
FERC transmission credit refund, net of tax of $0 (e)
1 - - - 1
ECR beneficial reuse transition adjustment, net of tax of $2 (f)
(4) - - - (4)
DER projects impairment, net of tax of $6 (g)
- (15) - - (15)
IT transformation, net of tax of $5 (h)
- - - (22) (22)
Total Special Items (4) (33) (46) (279) (362)
Earnings from Ongoing Operations $ 624 $ 607 $ 155 $ (136) $ 1,250
(a)PPL incurred legal expenses related to litigation associated with its former affiliate, Talen Montana, LLC and certain affiliated entities.
(b)Represents costs primarily related to PPL's centralization and other strategic efforts.
(c)Rhode Island Regulated primarily includes certain transition services agreement costs for IT systems that will not be part of PPL's ongoing operations. Corporate and Other primarily includes integration and related costs associated with the acquisition of RIE.
(d)Certain expenses related to billing issues.
(e)Prior period impact related to a FERC refund order.
(f)Prior period impact for an ECR mechanism revenue adjustment related to a KPSC order.
(g)Impairment of DER project costs associated with a pilot solar program for which PPL will not seek regulatory recovery.
(h)Costs associated with PPL's restructuring and rebuilding of its IT infrastructure, organization and systems.
PPL Electric: Statement of Income Analysis
Net income for the years ended December 31 includes the following results:
Change
2025 2024 2025 vs. 2024
Operating Revenues $ 3,113 $ 2,876 $ 237
Operating Expenses
Operation
Energy purchases 876 721 155
Other operation and maintenance 630 705 (75)
Depreciation 413 401 12
Taxes, other than income 151 131 20
Total Operating Expenses 2,070 1,958 112
Operating Income 1,043 918 125
Other Income (Expense) - net 48 45 3
Interest Income from Affiliate 9 33 (24)
Interest Expense 257 246 11
Income Before Income Taxes 843 750 93
Income Taxes 204 176 28
Net Income $ 639 $ 574 $ 65
Operating Revenues
The increase (decrease) in operating revenues was due to:
2025 vs. 2024
Distribution price (a) $ (14)
Distribution volume (b) 34
PLR (c) 174
Transmission formula rate (d) 45
Other (2)
Total $ 237
(a)The decrease was primarily due to reconcilable cost recovery mechanisms approved by the PAPUC.
(b)The increase was primarily due to weather and higher other usage in 2025.
(c)The increase was primarily the result of higher energy prices, more PLR customers and higher customer volumes due to weather and other higher usage.
(d)The increase was primarily due to returns on additional transmission capital investments and return of depreciation expense.
Energy Purchases
Energy purchases increased $155 million in 2025 compared with 2024, primarily due to higher PLR prices of $92 million and higher PLR volumes of $57 million.
Other Operation and Maintenance
The increase (decrease) in other operation and maintenance was due to:
2025 vs. 2024
Vegetation management expenses $ (14)
Bad debts (21)
DER projects impairment (a) (21)
Storm expenses (13)
Other (6)
Total $ (75)
(a)2024 impairment of DER project costs associated with a pilot solar program for which PPL will not seek regulatory recovery.
LG&E: Statement of Income Analysis
Net income for the years ended December 31 includes the following results:
Change
2025 2024 2025 vs. 2024
Operating Revenues
Retail and wholesale $ 1,718 $ 1,617 $ 101
Electric revenue from affiliate 30 31 (1)
Total Operating Revenues 1,748 1,648 100
Operating Expenses
Operation
Fuel 338 308 30
Energy purchases 187 151 36
Energy purchases from affiliate 22 20 2
Other operation and maintenance 364 349 15
Depreciation 307 305 2
Taxes, other than income 51 49 2
Total Operating Expenses 1,269 1,182 87
Operating Income 479 466 13
Other Income (Expense) - net 24 12 12
Interest Income from Affiliate - 1 (1)
Interest Expense 116 105 11
Income Before Income Taxes 387 374 13
Income Taxes 78 77 1
Net Income $ 309 $ 297 $ 12
Operating Revenues
The increase (decrease) in operating revenues was due to:
2025 vs. 2024
Fuel and other energy purchases (a) $ 60
Volumes (b) 15
Off-system sales (c) 17
Other 8
Total $ 100
(a)The increase was primarily due to higher recoveries of fuel expenses and energy purchases.
(b)The increase was primarily due to weather.
(c)The increase was primarily due to higher volumes.
Fuel
Fuel expense increased $30 million in 2025 compared with 2024, primarily due to an increase in commodity costs.
Energy Purchases
Energy purchases increased $36 million in 2025 compared with 2024, primarily due to a $23 million increase in volumes primarily due to weather and a $14 million increase in commodity costs.
KU: Statement of Income Analysis
Net income for the years ended December 31 includes the following results:
Change
2025 2024 2025 vs. 2024
Operating Revenues
Retail and wholesale $ 2,042 $ 1,944 $ 98
Electric revenue from affiliate 22 20 2
Total Operating Revenues 2,064 1,964 100
Operating Expenses
Operation
Fuel 517 476 41
Energy purchases 26 25 1
Energy purchases from affiliate 30 31 (1)
Other operation and maintenance 416 413 3
Depreciation 408 403 5
Taxes, other than income 51 49 2
Total Operating Expenses 1,448 1,397 51
Operating Income 616 567 49
Other Income (Expense) - net 29 15 14
Interest Expense 148 137 11
Income Before Income Taxes 497 445 52
Income Taxes 99 89 10
Net Income $ 398 $ 356 $ 42
Operating Revenues
The increase (decrease) in operating revenues was due to:
2025 vs. 2024
Fuel and other energy purchases (a) $ 30
Volumes (b) 34
Off-system sales (c) 19
Other 17
Total $ 100
(a)The increase was primarily due to higher recoveries of fuel expenses.
(b)The increase was primarily due to weather.
(c)The increase was primarily due to higher volumes.
Fuel
Fuel expense increased $41 million in 2025 compared with 2024, primarily due to a $24 million increase in volumes due to weather and an $18 million increase in commodity costs.
Financial Condition
The remainder of this Item 7 in this Form 10-K is presented on a combined basis, providing information, as applicable, for all Registrants.
Liquidity and Capital Resources
(All Registrants)
The Registrants' cash flows from operations and access to cost-effective bank and capital markets are subject to risks and uncertainties. See "Item 1A. Risk Factors" for a discussion of risks and uncertainties that could affect the Registrants' cash flows.
The Registrants had the following at:
PPL PPL Electric LG&E KU
December 31, 2025
Cash and cash equivalents $ 1,071 $ 30 $ 162 $ 10
Short-term debt 456 - - -
Long-term debt due within one year 904 - 90 164
Notes payable with affiliates - - 36
December 31, 2024
Cash and cash equivalents $ 306 $ 24 $ 8 $ 13
Short-term debt 303 - 25 140
Long-term debt due within one year 551 - 300 250
Notes payable with affiliates - 43 73
(All Registrants)
Net cash provided by (used in) operating, investing and financing activities for the years ended December 31 and the changes between periods were as follows:
PPL PPL Electric LG&E KU
2025
Operating activities $ 2,629 $ 1,050 $ 599 $ 798
Investing activities (4,004) (1,503) (803) (986)
Financing activities 2,122 459 349 176
2024
Operating activities $ 2,340 $ 1,042 $ 554 $ 723
Investing activities (2,818) (1,455) (444) (643)
Financing activities 435 386 (130) (89)
2025 vs. 2024 Change
Operating activities $ 289 $ 8 $ 45 $ 75
Investing activities (1,186) (48) (359) (343)
Financing activities 1,687 73 479 265
Operating Activities
The components of the change in cash provided by (used in) operating activities were as follows:
PPL PPL Electric LG&E KU
2025 vs. 2024
Change - Cash Provided (Used):
Net income $ 293 $ 65 $ 12 $ 42
Non-cash components 17 (107) (9) 16
Working capital 13 77 33 7
Other operating activities (34) (27) 9 10
Total $ 289 $ 8 $ 45 $ 75
A majority of the Registrants' operating cash flows are provided by their electric and natural gas utilities, which are significantly influenced by factors such as weather, regulatory mechanisms, economic conditions, changes in working capital and operating costs.
(PPL)
PPL's cash provided by operating activities in 2025 increased $289 million compared with 2024.
•Net income increased $293 million between the periods and included an increase in non-cash components of $17 million.
•The $13 million increase in cash from changes in working capital was primarily due to an increase in regulatory liabilities, taxes payable and other current liabilities and a decrease in prepayments, partially offset by an increase in accounts receivable.
•The $34 million decrease in cash from other operating activities was primarily due to an increase in other noncurrent assets, partially offset by an increase in other noncurrent liabilities.
(PPL Electric)
PPL Electric's cash provided by operating activities in 2025 increased $8 million compared with 2024.
•Net income increased $65 million between the periods and included a decrease in non-cash components of $107 million, primarily due to a decrease in deferred income taxes and investment tax credits.
•The $77 million increase in cash from changes in working capital was primarily due to an increase in regulatory liabilities and taxes payable and a decrease in prepayments, partially offset by an increase in accounts receivable.
•The $27 million decrease in cash from other operating activities was primarily due to an increase in other noncurrent assets.
(LG&E)
LG&E's cash provided by operating activities in 2025 increased $45 million compared with 2024.
•Net income increased $12 million between the periods and included a decrease in non-cash components of $9 million.
•The $33 million increase in cash from changes in working capital was primarily due to an increase in taxes payable and a decrease in accounts receivable.
•The $9 million increase in cash from other operating activities was primarily due to an increase in other noncurrent liabilities, partially offset by an increase in other noncurrent assets.
(KU)
KU's cash provided by operating activities in 2025 increased $75 million compared with 2024.
•Net income increased $42 million between the periods and included an increase in non-cash components of $16 million.
•The $7 million increase in cash from changes in working capital was primarily due to an increase in accounts payable and taxes payable, partially offset by a decrease in regulatory liabilities.
•The $10 million increase in cash from other operating activities was primarily due to an increase in other noncurrent assets.
Investing Activities
(All Registrants)
The components of the change in cash provided by (used in) investing activities were as follows:
PPL PPL Electric LG&E KU
2025 vs. 2024
Change - Cash Provided (Used):
Expenditures for PP&E $ (1,225) $ (379) $ (323) $ (340)
Notes receivable from affiliate - 301 (36) -
Other investing activities 39 30 - (3)
Total $ (1,186) $ (48) $ (359) $ (343)
For PPL, the increase in expenditures for PP&E was primarily due to an increase in project expenditures at PPL Electric, LG&E, KU and RIE. The increase in expenditures at PPL Electric was primarily due to increases in transmission and distribution projects. The increase in expenditures at LG&E was primarily due to Mill Creek Units 5 and 6, the E.W. Brown battery storage project and the Bullitt County system reinforcement project. The increase in expenditures at KU was primarily due to Mill Creek Unit 5.
See "Forecasted Uses of Cash" for detail regarding projected capital expenditures for the years 2026 through 2028.
For PPL Electric, the changes in "Notes receivable from affiliate" activity resulted from payments received in 2025 on the short-term note between affiliates, issued in 2024 to support general corporate purposes. See Note 13 to the Financial Statements for further discussion of intercompany borrowings.
Financing Activities
(All Registrants)
The components of the change in cash provided by (used in) financing activities were as follows:
PPL PPL Electric LG&E KU
2025 vs. 2024
Change - Cash Provided (Used):
Long-term debt issuance/retirement, net $ 535 $ (153) $ 400 $ 450
Dividends (47) (26) (13) (17)
Issuance of treasury stock 399 - - -
Capital contributions/distributions, net - (258) 237 138
Changes in net short-term debt 842 509 (50) (187)
Note payable with affiliate - - (86) (110)
Other financing activities (42) 1 (9) (9)
Total $ 1,687 $ 73 $ 479 $ 265
(All Registrants)
See Note 8 to the Financial Statements for information on 2025 activity.
See "Long-term Debt and Equity Securities" below for additional information on current year activity. See "Forecasted Sources of Cash" for a discussion of the Registrants' plans to issue debt and equity securities, as well as a discussion of credit facility capacity available to the Registrants. Also see "Forecasted Uses of Cash" for a discussion of PPL's plans to pay dividends on common securities in the future, as well as the Registrants' maturities of long-term debt.
Long-term Debt and Equity Securities
Long-term debt and equity securities activity for 2025 included:
Debt Stock
Issuances (a) Retirements Issuances (b) Repurchases
Cash Flow Impact:
PPL (c) $ 3,045 $ 616 $ 401 $ -
PPL Electric 496 - - -
LG&E 700 300 - -
KU 700 250 - -
(a)Issuances are net of pricing discounts, where applicable, and exclude the impact of debt issuance costs.
(b)Primarily includes issuances of treasury stock.
(c)Retirements include $65 million related to repurchased affiliate debt. See Note 8 to the Financial Statements for additional information.
See Note 8 to the Financial Statements for additional long-term debt information.
Forecasted Sources of Cash
(All Registrants)
The Registrants expect to continue to have adequate liquidity available from operating cash flows, cash and cash equivalents, credit facilities, commercial paper issuances and debt, hybrid, and equity issuances to meet their requirements with respect to their contractual obligations and anticipated capital expenditures. Equity capital for PPL can be provided from any combination of issuances from at the market stock plans, private placements, or public offerings. Additionally, subject to market conditions, the Registrants and their subsidiaries may access the capital markets, and PPL Electric, LG&E and KU anticipate receiving equity contributions from their parent or member in 2026, which are expected to be used to fund capital expenditures and for other general corporate purposes.
PPL Electric, LG&E and KU plan to obtain the funds to meet their future capital needs from sources similar to those they used in the past, which were primarily from operating cash flows, external securities issuances, borrowings from financial institutions, and equity contributions from PPL. Operating cash flows provide a substantial portion of these subsidiary Registrants' cash needs.
The amount, type, and timing of any financings in 2026, as well as in subsequent years, will be contingent on investment opportunities and the Registrants' capital requirements and will depend upon prevailing market conditions, regulatory approvals as applicable for the subsidiary Registrants, and other factors.
Credit Facilities
The Registrants maintain credit facilities to enhance liquidity, provide credit support and provide a backstop to commercial paper programs. Amounts borrowed under these credit facilities are reflected in "Short-term debt" on the Balance Sheets. At December 31, 2025, the total committed borrowing capacity under credit facilities and the borrowings under these facilities were:
External
Committed Capacity Borrowed Letters of
Credit
and
Commercial
Paper
Issued (d) 		Unused
Capacity
PPL Capital Funding Credit Facilities (a) $ 1,600 $ - $ 456 $ 1,144
PPL Electric Credit Facilities 750 - 6 744
LG&E Credit Facilities 600 - - 600
KU Credit Facilities 600 - - 600
Total Credit Facilities (b)(c) $ 3,550 $ - $ 462 $ 3,088
(a)Includes a $1.5 billion syndicated credit facility with a $400 million borrowing sublimit for RIE and a $1.1 billion sublimit for PPL Capital Funding. RIE's borrowing sublimit is adjustable, at the borrowers' option, from $0 to $600 million, with the remaining balance of the $1.5 billion available under the facility allocated to PPL Capital Funding. At December 31, 2025, PPL Capital Funding had $355 million of commercial paper outstanding and RIE had $101 million of commercial paper outstanding. See Note 8 to the Financial Statements for additional information.
(b)The syndicated credit facilities and PPL Capital Funding's bilateral facility, each contain a financial covenant requiring debt to total capitalization not to exceed 70% for PPL Capital Funding, RIE, PPL Electric, LG&E and KU, as calculated in accordance with the facility, and other customary covenants.
The commitments under the credit facilities are provided by a diverse bank group, with no one bank and its affiliates providing an aggregate commitment of more than the following percentages of the total committed capacity: PPL - 8%, PPL Electric - 7%, LG&E - 7% and KU - 7%.
(c)Each company pays customary fees under its respective syndicated credit facility. Borrowings generally bear interest at applicable SOFR, plus an applicable margin.
(d)Commercial paper issued reflects the undiscounted face value of the issuance.
In addition to the financial covenants noted in the table above, the credit agreements governing the above credit facilities contain various other covenants. Failure to comply with the covenants after applicable grace periods could result in acceleration of repayment of borrowings and/or termination of the agreements. The Registrants monitor compliance with the covenants on a regular basis. At December 31, 2025, the Registrants were in compliance with these covenants. As of December 31, 2025, the Registrants believe that these covenants and other borrowing conditions will not limit access to these funding sources.
See Note 8 to the Financial Statements for further discussion of the Registrants' credit facilities.
Intercompany(LG&E and KU)
Committed
Capacity 		Borrowed Commercial Paper Issued Unused
Capacity
LG&E Money Pool (a) $ 750 $ - $ - $ 750
KU Money Pool (a) 650 36 - 614
(a)LG&E and KU participate in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E, and LKE and/or LG&E make available to KU funds up to the difference between LG&E's and KU's FERC borrowing limit and LG&E's and KU's commercial paper capacity limit, at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on the lower of a market index of commercial paper issues and two additional rate options based on SOFR.
See Note 13 to the Financial Statements for further discussion of intercompany credit facilities.
Commercial Paper(All Registrants)
The Registrants, PPL Capital Funding and RIE maintain commercial paper programs to provide an additional financing source to fund short-term liquidity needs, as necessary. Commercial paper issuances, included in "Short-term debt" on the Balance Sheets, are supported by the respective Registrant's credit facilities. The following commercial paper programs were in place at:
December 31, 2025
Capacity Commercial
Paper
Issuances (b) 		Unused
Capacity
PPL Capital Funding (a) $ 1,600 $ 355 $ 1,245
Rhode Island Energy (a) 400 101 299
PPL Electric 750 - 750
LG&E 600 - 600
KU 600 - 600
Total PPL $ 3,950 $ 456 $ 3,494
(a)Issuances under the PPL Capital Funding and RIE commercial paper programs are supported by the PPL Capital Funding syndicated credit facility, which at December 31, 2025, had a total capacity of $1.5 billion, with a $400 million borrowing sublimit for RIE and a $1.1 billion sublimit for PPL Capital Funding. The sublimits of each borrower may be decreased or increased at the borrowers' option up to a prescribed amount such that all borrowings under the syndicated credit facility cannot exceed the size of the credit facility of $1.5 billion. PPL Capital Funding's Commercial paper program is also backed by a separate bilateral credit facility for $100 million.
(b)Commercial paper issued reflects the undiscounted face value of the issuance.
Forecasted Uses of Cash
(All Registrants)
In addition to expenditures required for normal operating activities, such as purchased power, payroll, fuel and taxes, the Registrants currently expect to incur future cash outflows for capital expenditures, various contractual obligations, payment of dividends on its common stock, and possibly the purchase or redemption of a portion of debt securities.
Capital Expenditures
The table below shows the Registrants' current capital expenditure projections for the years 2026 through 2028. Expenditures for the regulated utilities are expected to be recovered through rates, pending regulatory approval.
Projected
Total 2026 (a) 2027 2028
PPL
Generating facilities $ 4,200 $ 1,100 $ 1,500 $ 1,600
Electric distribution facilities 5,575 1,775 1,950 1,850
Gas distribution facilities 1,225 375 400 450
Transmission facilities 5,875 1,625 2,025 2,225
Other 475 250 150 75
Total Capital Expenditures $ 17,350 $ 5,125 $ 6,025 $ 6,200
PPL Electric
Electric distribution facilities $ 2,850 $ 1,000 $ 950 $ 900
Transmission facilities 3,350 975 1,125 1,250
Total Capital Expenditures $ 6,200 $ 1,975 $ 2,075 $ 2,150
LG&E
Generating facilities $ 2,500 $ 600 $ 850 $ 1,050
Electric distribution facilities 825 200 325 300
Gas distribution facilities 450 125 150 175
Transmission facilities 450 125 175 150
Other 250 125 75 50
Total Capital Expenditures $ 4,475 $ 1,175 $ 1,575 $ 1,725
KU
Generating facilities $ 1,700 $ 500 $ 650 $ 550
Electric distribution facilities 1,075 275 400 400
Transmission facilities 1,350 300 475 575
Other 225 125 75 25
Total Capital Expenditures $ 4,350 $ 1,200 $ 1,600 $ 1,550
(a)The 2026 total excludes amounts included in accounts payable as of December 31, 2025.
Capital expenditure plans are revised periodically to reflect changes in operational, market and regulatory conditions.
Contractual Obligations
The Registrants have assumed various financial obligations and commitments in the ordinary course of conducting business. At December 31, 2025, estimated contractual cash obligations were as follows:
Total 2026 2027-2028 2028-2029 After 2030
PPL
Long-term Debt (a) $ 19,089 $ 904 $ 1,778 $ 2,297 $ 14,110
Interest on Long-term Debt (b) 13,775 836 1,611 1,516 9,812
Operating Leases 109 20 35 19 35
Purchase Obligations (c) 5,476 1,940 1,845 1,002 689
Total Contractual Cash Obligations $ 38,449 $ 3,700 $ 5,269 $ 4,834 $ 24,646
PPL Electric
Long-term Debt (a) $ 5,799 $ - $ 108 $ 116 $ 5,575
Interest on Long-term Debt (b) 4,965 274 543 538 3,610
Unconditional Power Purchase Obligations 739 63 144 143 389
Total Contractual Cash Obligations $ 11,503 $ 337 $ 795 $ 797 $ 9,574
LG&E
Long-term Debt (a) $ 2,889 $ 90 $ 260 $ - $ 2,539
Interest on Long-term Debt (b) 2,508 131 253 249 1,875
Operating Leases 19 6 9 4 -
Coal and Natural Gas Purchase Obligations (d) 856 314 357 162 23
Unconditional Power Purchase Obligations (e) 299 19 48 48 184
Construction Obligations (f) 369 319 48 2 -
Other Obligations 72 45 22 5 -
Total Contractual Cash Obligations $ 7,012 $ 924 $ 997 $ 470 $ 4,621
KU
Long-term Debt (a) $ 3,539 $ 164 $ 60 $ - $ 3,315
Interest on Long-term Debt (b) 3,096 163 315 314 2,304
Operating Leases 30 10 13 5 2
Coal and Natural Gas Purchase Obligations (d) 1,088 372 536 180 -
Unconditional Power Purchase Obligations (e) 133 8 21 21 83
Construction Obligations (f) 356 288 62 6 -
Other Obligations 49 19 18 12 -
Total Contractual Cash Obligations $ 8,291 $ 1,024 $ 1,025 $ 538 $ 5,704
(a)Reflects principal maturities based on stated maturity, sinking fund payments, or earlier put dates. See Note 8 to the Financial Statements for a discussion of variable-rate remarketable bonds issued on behalf of LG&E and KU. The Registrants do not have any significant finance lease obligations. For PPL, reduced by $84 million of repurchased affiliate bonds as of December 31, 2025. See Note 8 to the Financial Statements for more information.
(b)Assumes interest payments through stated maturity or earlier put dates. The payments herein are subject to change, as payments for debt that is or becomes variable-rate debt have been estimated.
(c)The amounts include agreements to purchase goods or services that are enforceable and legally binding and specify all significant terms, including: fixed or minimum quantities to be purchased; fixed, minimum or variable price provisions; and the approximate timing of the transaction. Primarily includes, as applicable, the purchase obligations of electricity, coal, natural gas and limestone, as well as certain construction expenditures, which are also included in the Capital Expenditures discussion above.
(d)Represents contracts to purchase coal, natural gas and natural gas transportation. See Note 12 to the Financial Statements for additional information.
(e)Represents future minimum payments under OVEC power purchase agreements through June 2040. See Note 12 to the Financial Statements for additional information.
(f)Represents construction commitments, which are also reflected in the Capital Expenditures table presented above.
Dividends/Distributions
(PPL)
PPL views dividends as an integral component of shareowner return and expects to continue to pay dividends in amounts intended to maintain a capitalization structure that supports investment grade credit ratings. In November 2025, PPL declared its quarterly common stock dividend, payable January 2, 2026, at 27.25 cents per share (equivalent to $1.09 per annum). On February 20, 2026, PPL announced a quarterly common stock dividend of 28.50 cents per share, payable April 1, 2026, to shareowners of record as of March 10, 2026. Future dividends will be declared at the discretion of the Board of Directors and will depend upon future earnings, cash flows, financial and legal requirements and other factors.
Subject to certain exceptions, PPL may not declare or pay any cash dividend or distribution on its capital stock during any period in which PPL Capital Funding defers interest payments on its 2007 Series A Junior Subordinated Notes due 2067. At December 31, 2025, no interest payments were deferred.
(PPL Electric, LG&E and KU)
From time to time, as determined by their respective Board of Directors, the Registrants pay dividends, distributions or return capital, as applicable, to their respective shareholders or members. Certain of the credit facilities of PPL Electric, LG&E and KU include minimum debt covenant ratios that could effectively restrict the payment of dividends or distributions.
(All Registrants)
See Note 8 to the Financial Statements for these and other restrictions related to distributions on capital interests for the Registrants and their subsidiaries.
Purchase or Redemption of Debt Securities
The Registrants will continue to evaluate outstanding debt securities and may decide to purchase or redeem these securities in open market or privately negotiated transactions, in exchange transactions or otherwise, depending upon prevailing market conditions, available cash and other factors, and may be commenced or suspended at any time. The amounts involved may be material.
Rating Agency Actions
Moody's and S&P periodically review the credit ratings of the debt of the Registrants and their subsidiaries. Based on their respective independent reviews, the rating agencies may make certain ratings revisions or ratings affirmations.
A credit rating reflects an assessment by the rating agency of the creditworthiness associated with an issuer and particular securities that it issues. The credit ratings of the Registrants and their subsidiaries are based on information provided by the Registrants and other sources. The ratings of Moody's and S&P are not a recommendation to buy, sell or hold any securities of the Registrants or their subsidiaries. Such ratings may be subject to revisions or withdrawal by the agencies at any time and should be evaluated independently of each other and any other rating that may be assigned to the securities.
The credit ratings of the Registrants and their subsidiaries affect their liquidity, access to capital markets and cost of borrowing under their credit facilities. A downgrade in the Registrants' or their subsidiaries' credit ratings could result in higher borrowing costs and reduced access to capital markets. The Registrants and their subsidiaries have no credit rating triggers that would result in the reduction of access to capital markets or the acceleration of maturity dates of outstanding debt.
The following table sets forth the Registrants' and their subsidiaries' credit ratings for outstanding debt securities or commercial paper programs as of December 31, 2025.
Senior Unsecured Senior Secured Commercial Paper
Issuer Moody's S&P Moody's S&P Moody's S&P
PPL
PPL Capital Funding Baa1 BBB+ P-2 A-2
Rhode Island Energy A3 A- P-2 A-2
PPL and PPL Electric
PPL Electric A1 A+ P-2 A-1
PPL, LG&E and KU
LG&E A1 A P-2 A-2
KU A1 A P-2 A-2
Since June 2023, the rating agencies have not taken rating actions related to the Registrants and their subsidiaries.
Ratings Triggers (PPL, LG&E and KU)
Various derivative and non-derivative contracts, including contracts for the sale and purchase of electricity and fuel, commodity transportation and storage, and interest rate instruments, contain provisions that require the posting of additional collateral or permit the counterparty to terminate the contract, if PPL's, LG&E's or KU's or their subsidiaries' credit rating, as applicable, were to fall below investment grade. See Note 16 to the Financial Statements for a discussion of "Credit Risk-Related Contingent Features," including a discussion of the potential additional collateral requirements for derivative contracts in a net liability position at December 31, 2025.
Guarantees for Subsidiaries (PPL)
PPL guarantees certain consolidated affiliate financing arrangements. Some of the guarantees contain financial and other covenants that, if not met, would limit or restrict the consolidated affiliates' access to funds under these financing arrangements, accelerate maturity of such arrangements or limit the consolidated affiliates' ability to enter into certain transactions. At this time, PPL believes that these covenants will not limit access to relevant funding sources. See Note 12 to the Financial Statements for additional information about guarantees.
Other Contingent Obligations (All Registrants)
The Registrants have entered into certain agreements that may contingently require payment to a guaranteed or indemnified party. See Note 12 to the Financial Statements for a discussion of these agreements.
Risk Management
Market Risk
(All Registrants)
See Notes 1, 15 and 16 to the Financial Statements for information about the Registrants' risk management objectives, valuation techniques and accounting designations.
The forward-looking information presented below provides estimates of what may occur in the future, assuming certain adverse market conditions and model assumptions. Actual future results may differ materially from those presented. These are not precise indicators of expected future losses, but are rather only indicators of possible losses under normal market conditions at a given confidence level.
Interest Rate Risk
PPL and its subsidiaries issue debt to finance their operations, which exposes them to interest rate risk. A variety of financial derivative instruments are utilized to adjust the mix of fixed and floating interest rates in their debt portfolios, adjust the duration of the debt portfolios and lock in benchmark interest rates in anticipation of future financing, when appropriate. Risk limits under PPL's risk management program are designed to balance risk exposure to volatility in interest expense and changes in the fair value of the debt portfolio due to changes in benchmark interest rates. In addition, the interest rate risk of certain subsidiaries is potentially mitigated as a result of the existing regulatory framework or the timing of rate cases.
The following interest rate hedges were outstanding at December 31:
2025 2024
Exposure
Hedged 		Fair Value,
Net - Asset
(Liability) (a) 		Effect of a
10% Adverse
Movement
in Rates (b) 		Maturities
Ranging
Through 		Exposure
Hedged 		Fair Value,
Net - Asset
(Liability) (a) 		Effect of a
10% Adverse
Movement
in Rates (b)
PPL and LG&E
Cash flow hedges
Interest rate derivatives $ 20 $ - $ (1) 2026 $ - $ - $ -
Economic hedges
Interest rate derivatives (c) $ 64 $ (5) $ (1) 2033 $ 64 $ (3) $ (1)
(a)Includes accrued interest, if applicable.
(b)Effects of adverse movements decrease assets or increase liabilities, as applicable, which could result in an asset becoming a liability. Sensitivities represent a 10% adverse movement in interest rates.
(c)Realized changes in the fair value of such economic hedges are recoverable through regulated rates and any subsequent changes in the fair value of these derivatives are included in regulatory assets or regulatory liabilities.
The Registrants are exposed to a potential increase in interest expense and to changes in the fair value of their debt portfolios. The estimated impact of a 10% adverse movement in interest rates on interest expense at December 31, 2025 and 2024 was insignificant for PPL, PPL Electric, LG&E, and KU. The estimated impact of a 10% adverse movement in interest rates on the fair value of debt at December 31 is shown below.
10% Adverse Movement in Rates on Fair Value of Debt
2025 2024
PPL $ 720 $ 622
PPL Electric 284 262
LG&E 135 89
KU 175 131
Commodity Price Risk
PPL is exposed to commodity price risk through its subsidiaries primarily from the purchases of electricity, natural gas and fuel but has cost recovery mechanisms to mitigate that risk. See Note 16 to the Financial Statements for further discussion of these risks.
Volumetric Risk
Volumetric risk is the risk related to the changes in volume of retail sales due to weather, economic conditions or other factors. PPL is exposed to volumetric risk through its subsidiaries as described below.
•PPL Electric, LG&E and KU are exposed to volumetric risk on retail sales, mainly due to weather and other economic conditions for which there is limited mitigation between rate cases.
•RIE is not materially exposed to volumetric risk. RIE's electric and gas distribution rates both have a revenue decoupling mechanism, which allows for annual adjustments to RIE's delivery rates.
Defined Benefit Plans - Equity Securities Price Risk
See "Application of Critical Accounting Policies - Defined Benefits" for additional information regarding the effect of equity securities price risk on plan assets.
Credit Risk
(All Registrants)
Credit risk is the potential loss that may be incurred due to a counterparty's non-performance.
PPL is exposed to credit risk from "in-the-money" transactions with counterparties as well as additional credit risk through certain of its subsidiaries, as discussed below.
In the event a supplier of PPL, PPL Electric, LG&E or KU defaults on its contractual obligation, those Registrants would be required to seek replacement power or replacement fuel in the market. In general, subject to regulatory review or other processes, appropriate incremental costs incurred by these entities would be recoverable from customers through applicable rate mechanisms, thereby mitigating the financial risk for these entities.
PPL and its subsidiaries have credit policies in place to manage credit risk, including the use of an established credit approval process, daily monitoring of counterparty positions and the use of master netting agreements or provisions. These agreements generally include credit mitigation provisions, such as margin, prepayment or collateral requirements. PPL and its subsidiaries may request additional credit assurance, in certain circumstances, if the counterparties' credit ratings fall below investment grade, their tangible net worth falls below specified percentages or their exposures exceed an established credit limit.
(All Registrants)
Related Party Transactions
The Registrants are not aware of any material ownership interests or operating responsibility by senior management in outside partnerships, including leasing transactions with variable interest entities, or other entities doing business with the Registrants. See Note 13 to the Financial Statements for additional information on related party transactions for PPL Electric, LG&E and KU.
Acquisitions, Development and Divestitures
The Registrants from time to time evaluate opportunities for potential acquisitions, divestitures, and development projects. See Note 9 to the Financial Statements for additional information on acquisition, development and divestiture activity. Development projects are reexamined based on market conditions and other factors to determine whether to proceed with, modify or terminate the projects. Any resulting transactions may impact future financial results.
Environmental Matters
Extensive federal, state and local environmental laws and regulations are applicable to the Registrants' air emissions, water discharges and the management of hazardous and solid waste, as well as other aspects of the Registrants' businesses. The costs of compliance or alleged non-compliance cannot be predicted with certainty but could be significant. In addition, costs may increase significantly if the requirements or scope of environmental laws or regulations, or similar rules, are expanded or changed. Costs may take the form of increased capital expenditures or operating and maintenance expenses, monetary fines, penalties or other restrictions. Many of these environmental law considerations are also applicable to the operations of key suppliers, or customers, such as coal producers and industrial power users, and may impact the costs for their products or their demand for the Registrants' services. Increased capital and operating costs are expected to be subject to rate recovery. The Registrants can provide no assurances as to the ultimate outcome of future environmental or rate proceedings before regulatory authorities.
See "Legal Matters" in Note 12 to the Financial Statements for a discussion of the more significant environmental claims. See Note 18 to the Financial Statements for information related to the impacts of CCRs on AROs. See "Item 1. Business - Environmental Matters" for additional information.
Sustainability
The Governance, Nominating and Sustainability Committee of PPL's Board of Directors has oversight of the company's practices and positions to further its sustainability strategy and corporate governance, including specific environmental and corporate social responsibility initiatives. Management considers several factors as part of the company's sustainability approach, including ongoing engagement with constituents such as shareholders and regulators on topics related to sustainability and other matters. To the extent sustainability issues have or may have a material impact on the Registrants' financial condition or results of operation, PPL discloses such matters in accordance with applicable securities law and SEC regulations.
In addition to disclosure required by applicable securities laws and SEC regulations, PPL provides additional disclosures on sustainability topics that it considers relevant to investors and stakeholders, which are available on the corporate website at https://www.pplweb.com/sustainability/reports-disclosures/. Primarily, PPL continues each spring to publish its annual sustainability report including data related to carbon emissions. PPL also participates in efforts by the Edison Electric Institute and American Gas Association to provide the appropriate subset of sustainability information that can be applied consistently across the electric and gas utility industries. Finally, PPL consults widely used reporting frameworks for discrete sustainability topics, including corporate political contributions and climate-related issues and maps its disclosure to various reporting frameworks such as Global Reporting Initiative (GRI) Standards and to the CDP Climate and Water Questionnaires.
Cybersecurity
See "Item 1A. Risk Factors" and "Item 1C. Cybersecurity" for a discussion of cybersecurity risks affecting the Registrants and the related strategies for managing these risks.
Competition
See "Competition" under each of PPL's reportable segments in "Item 1. Business - General - Segment Information" and "Item 1A. Risk Factors" for a discussion of competitive factors affecting the Registrants.
New Accounting Guidance
See Note 1 and Note 20 to the Financial Statements for a discussion of significant new accounting guidance adopted and pending adoption as of December 31, 2025.
Application of Critical Accounting Policies
Financial condition and results of operations are impacted by the methods, assumptions and estimates used in the application of critical accounting policies. The following accounting policies are particularly important to an understanding of the reported financial condition or results of operations and require management to make estimates or other judgments of matters that are inherently uncertain. Changes in the estimates or other judgments included within these accounting policies could result in a significant change to the information presented in the Financial Statements (these accounting policies are also discussed in Note 1 to the Financial Statements). Senior management has reviewed with PPL's Audit Committee these critical accounting policies, the following disclosures regarding their application, and the estimates and assumptions regarding them.
Defined Benefits (All Registrants)
Certain of the Registrants and/or their subsidiaries sponsor or participate in certain qualified funded and non-qualified unfunded defined benefit pension plans and both funded and unfunded other postretirement benefit plans. See Notes 1, 7 and 10 to the Financial Statements for additional information about the plans and the accounting for defined benefits.
A summary of plan sponsors by Registrant and whether a Registrant or its subsidiaries sponsor (S) or participate in and receives allocations (P) from those plans is shown in the table below.
Plan Sponsor PPL PPL Electric LG&E KU
PPL Services S P
LKE P P
Management makes certain assumptions regarding the valuation of benefit obligations and the performance of plan assets. As such, annual net periodic defined benefit costs are recorded in current earnings or regulatory assets and liabilities based on estimated results. Any differences between actual and estimated results are recorded in AOCI or, in the case of PPL Electric, LG&E and KU, regulatory assets and liabilities for amounts that are expected to be recovered through regulated customer rates. These amounts in AOCI or regulatory assets and liabilities are amortized to income over future periods. The significant assumptions are:
•Discount Rate - In selecting the discount rates for defined benefit plans, the plan sponsors start with a cash flow analysis of the expected benefit payment stream for their plans. The plan-specific cash flows are matched against the coupons and expected maturity values of Aa-rated non-callable (or callable with make-whole provisions) bonds that could be purchased for a hypothetical settlement portfolio. The plan sponsors then use the single discount rate derived from matching the discounted benefit payment stream to the market value of the selected bond portfolio.
•Expected Return on Plan Assets - The expected long-term rates of return for pension and other postretirement benefits are based on management's projections using a best-estimate of expected returns, volatilities and correlations for each asset class. Each plan's specific current and expected asset allocations are also considered in developing a reasonable return assumption.
•Rate of Compensation Increase - Management projects employees' annual pay increases, which are used to project employees' pension benefits at retirement. In selecting a rate of compensation increase, plan sponsors consider past experience, the potential impact of movements in inflation rates and expectations of ongoing compensation practices.
See Note 10 to the Financial Statements for details of the assumptions selected for pension and other postretirement benefits. A variance in the assumptions could significantly impact accrued defined benefit liabilities or assets, reported annual net periodic defined benefit costs and AOCI or regulatory assets and liabilities.
The following tables reflect changes in certain assumptions based on the Registrants' primary qualified defined benefit pension and other postretirement benefit plans. The inverse of this change would have the opposite impact on accrued defined benefit liabilities or assets, reported annual net periodic defined benefit costs and AOCI or regulatory assets and liabilities. The sensitivities below reflect an evaluation of the change based solely on a change in that assumption.
Increase (Decrease)
Actuarial assumption
Discount Rate (0.25 %)
Expected Return on Plan Assets (0.25 %)
Rate of Compensation Increase 0.25 %
Increase (Decrease) (Increase) Decrease (Increase) Decrease Increase (Decrease) Increase (Decrease)
Actuarial assumption Defined Benefit
Asset 		Defined Benefit
Liabilities 		AOCI
(pre-tax) 		Net Regulatory
Assets 		Defined Benefit
Costs
PPL
Discount rates $ (17) $ (73) $ 26 $ 64 $ 4
Expected return on plan assets n/a n/a n/a n/a 10
Rate of compensation increase (2) (6) 2 6 1
PPL Electric
Discount rates - (31) - 31 1
Expected return on plan assets n/a n/a - n/a 3
Rate of compensation increase - (2) - 2 -
LG&E
Discount rates (7) 1 n/a 8 1
Expected return on plan assets n/a n/a n/a n/a 1
Rate of compensation increase (1) - n/a 1 -
KU
Discount rates (6) 1 n/a 7 1
Expected return on plan assets n/a n/a n/a n/a 1
Rate of compensation increase (1) - n/a 1 -
Income Taxes (All Registrants)
Significant management judgment is required in developing the Registrants' provision for income taxes, primarily due to valuation allowances on deferred tax assets.
The need for valuation allowances to reduce deferred tax assets requires significant management judgment. Valuation allowances are initially recorded and reevaluated each reporting period by assessing the likelihood of the ultimate realization of a deferred tax asset. Management considers numerous factors in assessing the expected realization of a deferred tax asset, including the reversal of temporary differences, future taxable income and ongoing prudent and feasible tax planning strategies. Any tax planning strategy considered in this assessment must meet the recognition and measurement criteria for the valuation of a deferred tax asset. When evaluating the need for valuation allowances, the uncertainty posed by potential or expected legislative change on such factors is also considered by management. The amount of deferred tax assets ultimately realized may differ materially from the estimates utilized in the computation of valuation allowances and may materially impact the financial statements in the future.
See Note 6 to the Financial Statements for income tax disclosures.
Regulatory Assets and Liabilities (All Registrants)
PPL Electric, LG&E, KU and RIE are subject to cost-based rate regulation. As a result, the effects of regulatory actions are required to be reflected in the financial statements. Assets and liabilities that result from the regulated ratemaking process may not be recorded under GAAP for non-regulated entities. Regulatory assets generally represent incurred costs that have been deferred because such costs are probable of future recovery in regulated customer rates. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. In certain cases, regulatory liabilities are recorded based on an understanding or agreement with the regulator that rates have been set to recover costs that are expected to be incurred in the future, and the regulated entity is accountable for any amounts charged pursuant to such rates and not yet expended for the intended purpose.
Management continually assesses whether the regulatory assets are probable of future recovery by considering factors such as changes in the applicable regulatory and political environments, the ability to recover costs through regulated rates, recent rate orders to the Registrants and other regulated entities, and the status of any pending or potential deregulation legislation. Based on this continual assessment, management believes the existing regulatory assets are probable of recovery. This assessment reflects the current political and regulatory climate at the state and federal levels and is subject to change in the future. If future recovery of costs ceases to be probable, the regulatory asset would be written-off. There were no material write-offs of regulatory assets for the year ended December 31, 2025. Additionally, the regulatory agencies can provide flexibility in the manner and timing of recovery of regulatory assets.
See Note 7 to the Financial Statements for regulatory assets and regulatory liabilities recorded at December 31, 2025 and 2024, as well as additional information on those regulatory assets and liabilities. All regulatory assets are either currently being recovered under specific rate orders, represent amounts that are expected to be recovered in future rates or benefit future periods based upon established regulatory practices.
Price Risk Management (PPL)
See "Financial Condition - Risk Management" above.
Goodwill Impairment (PPL, LG&E and KU)
Goodwill is tested for impairment at the reporting unit level. The reporting units of PPL include the Kentucky Regulated reporting unit, the Pennsylvania Regulated reporting unit, and the Rhode Island Regulated reporting unit. LG&E and KU are each single reporting units. A goodwill impairment test is performed annually or more frequently if events or changes in circumstances indicate that the carrying amount of the reporting unit may be greater than the reporting unit's fair value.
The fair value of a reporting unit is compared with the carrying value and an impairment charge is recognized if the carrying amount exceeds the fair value of the reporting unit.
PPL, for its reporting units, and individually, LG&E and KU, may elect either to initially make a qualitative evaluation about the likelihood of an impairment of goodwill or to bypass the qualitative evaluation and test goodwill for impairment using a quantitative test.
As of October 1, 2025, PPL, for its reporting units, and individually, LG&E and KU, elected to perform the qualitative step zero evaluation of goodwill. These evaluations considered the excess of fair value over the carrying value of each reporting unit that was calculated during step one of the quantitative impairment tests performed in the fourth quarter of 2022, and the relevant events and circumstances that occurred since those tests were performed including:
•current year financial performance versus the prior year,
•changes in planned capital expenditures,
•the consistency of forecasted free cash flows,
•earnings quality and sustainability,
•changes in market participant discount rates,
•changes in long-term growth rates,
•changes in PPL's market capitalization, and
•the overall economic and regulatory environments in which these regulated entities operate.
Based on these evaluations, management concluded it was not more likely than not that the fair value of these reporting units was less than their carrying value. As such, the step one quantitative impairment test was not performed and no impairment was recognized.
See "Long-Lived and Intangible Assets - Asset Impairment (Excluding Investments)" in Note 1 to the Financial Statements for further discussion of goodwill impairment tests. See Note 17 to the Financial Statements for information on goodwill balances by reportable segment at December 31, 2025.
Asset Retirement Obligations (LG&E and KU)
ARO liabilities are required to be recognized for legal obligations associated with the retirement of long-lived assets. Initial obligations are measured at estimated fair value. An ARO must be recognized when incurred if the fair value of the ARO can be reasonably estimated. An equivalent amount is recorded as an increase in the value of the capitalized asset and amortized to expense, regulatory assets or regulatory liabilities over the asset's useful life.
In determining AROs, management must make significant judgments and estimates to calculate fair value. Fair value is developed using an expected present value technique based on assumptions of market participants that consider estimated retirement costs in current period dollars, inflated to the anticipated retirement date and discounted back to the date the ARO was incurred. Changes in assumptions and estimates included within the calculations of the fair value of AROs could result in significantly different results than those identified and recorded in the financial statements. Estimated ARO costs and settlement dates, which affect the carrying value of the ARO and the related capitalized asset, are reviewed periodically to ensure that any material changes are incorporated into the ARO estimate. Any change to the capitalized asset is generally amortized over the remaining life of the associated long-lived asset.
See "Long-Lived and Intangible Assets - Asset Retirement Obligations" in Note 1, Note 7 and Note 18 to the Financial Statements for additional information on AROs.
At December 31, 2025, the total recorded balances and information on the most significant recorded AROs were as follows.
Most Significant AROs
Total
ARO
Recorded 		Amount
Recorded 		% of Total Description
LG&E $ 75 $ 52 69 Ponds, landfills and natural gas mains
KU 57 27 47 Ponds and landfills
The most significant assumptions surrounding AROs are the forecasted retirement costs (including settlement dates and the timing of cash flows), discount and inflation rates. At December 31, 2025, a 10% increase to retirement cost would increase these ARO liabilities by $6 million at LG&E and $7 million at KU. A 0.25% decrease in the discount rate would increase these ARO liabilities by $4 million at LG&E and $1 million at KU and a 0.25% increase in the inflation rate would increase these ARO liabilities by $4 million at LG&E and $1 million at KU. There would be no significant change to the annual depreciation expense of the ARO asset or the annual accretion expense of the ARO liability as a result of these changes in assumptions.
Revenue Recognition - Unbilled Revenues (PPL, LG&E and KU)
For RIE, LG&E and KU, revenues related to the sale of energy are recorded when service is rendered or when energy is delivered to customers. Because customers are billed on cycles which vary based on the timing of actual meter reads taken throughout the month, estimates are recorded for unbilled revenues at the end of each reporting period. Such unbilled revenue amounts reflect estimates of deliveries to customers since the date of the last reading of their meters. The unbilled revenue estimates reflect consideration of factors including daily load models, estimated usage for each customer class, the effect of current and different rate schedules, the meter read schedule, the billing schedule, actual weather data, and, where applicable, the impact of weather normalization or other regulatory provisions of rate structures.
Other Information (All Registrants)
PPL's Audit Committee has approved the independent auditor to provide audit and audit-related services, tax services and other services permitted by Sarbanes-Oxley and SEC rules. The audit and audit-related services include services in connection with statutory and regulatory filings, reviews of offering documents and registration statements, and internal control reviews.
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