10-Q

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UNITED STATES SECURITIES AND EXCHANGE COMMISSION Washington, D.C. 20549
FORM 10-Q
☒	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 for the quarterly period ended March 31, 2025
OR
☐	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 for the transition period from _________ to ___________

Commission File Number	Registrant; State of Incorporation; Address and Telephone Number	IRS Employer Identification No.
1-11459	PPL Corporation (Exact name of Registrant as specified in its charter) Pennsylvania 645 Hamilton Street Allentown, PA 18101 (610) 774-5151	23-2758192
1-905	PPL Electric Utilities Corporation (Exact name of Registrant as specified in its charter) Pennsylvania 827 Hausman Road Allentown, PA 18104-9392 (610) 774-5151	23-0959590
1-2893	Louisville Gas and Electric Company (Exact name of Registrant as specified in its charter) Kentucky 820 West Broadway Louisville, KY 40202 (502) 627-2000 Former Address: 220 West Main Street Louisville, KY 40202-1377	61-0264150
1-3464	Kentucky Utilities Company (Exact name of Registrant as specified in its charter) Kentucky and Virginia One Quality Street Lexington, KY 40507-1462 (502) 627-2000	61-0247570

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Securities registered pursuant to Section 12(b) of the Act:

Title of each class	Trading Symbol(s):	Name of each exchange on which registered
Common Stock of PPL Corporation	PPL	New York Stock Exchange
Junior Subordinated Notes of PPL Capital Funding, Inc.
2007 Series A due 2067	PPL/67	New York Stock Exchange

Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days.

PPL Corporation	Yes	☒	No	☐
PPL Electric Utilities Corporation	Yes	☒	No	☐
Louisville Gas and Electric Company	Yes	☒	No	☐
Kentucky Utilities Company	Yes	☒	No	☐

Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrants were required to submit such files). 

PPL Corporation	Yes	☒	No	☐
PPL Electric Utilities Corporation	Yes	☒	No	☐
Louisville Gas and Electric Company	Yes	☒	No	☐
Kentucky Utilities Company	Yes	☒	No	☐

Indicate by check mark whether the registrants are large accelerated filers, accelerated filers, non-accelerated filers, smaller reporting companies or emerging growth companies. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company" and "emerging growth company" in Rule 12b-2 of the Exchange Act.

	Large accelerated filer	Accelerated filer	Non-accelerated filer	Smaller reporting company	Emerging growth company
PPL Corporation	☒	☐	☐	☐	☐
PPL Electric Utilities Corporation	☐	☐	☒	☐	☐
Louisville Gas and Electric Company	☐	☐	☒	☐	☐
Kentucky Utilities Company	☐	☐	☒	☐	☐

If emerging growth companies, indicate by check mark if the registrants have elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.

PPL Corporation	☐
PPL Electric Utilities Corporation	☐
Louisville Gas and Electric Company	☐
Kentucky Utilities Company	☐

Indicate by check mark whether the registrants are shell companies (as defined in Rule 12b-2 of the Exchange Act).

PPL Corporation	Yes	☐	No	☒
PPL Electric Utilities Corporation	Yes	☐	No	☒
Louisville Gas and Electric Company	Yes	☐	No	☒
Kentucky Utilities Company	Yes	☐	No	☒

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Indicate the number of shares outstanding of each of the issuer's classes of common stock, as of the latest practicable date.

PPL Corporation    Common stock, $0.01 par value, 739,263,912 shares outstanding at April 25, 2025.

PPL Electric Utilities Corporation    Common stock, no par value, 66,368,056 shares outstanding and all held by PPL Energy Holdings LLC, a wholly-owned, indirect subsidiary of PPL Corporation, at April 25, 2025.

Louisville Gas and Electric Company    Common stock, no par value, 21,294,223 shares outstanding and all held by LG&E and KU Energy LLC, a wholly-owned, indirect subsidiary of PPL Corporation, at April 25, 2025.

Kentucky Utilities Company    Common stock, no par value, 37,817,878 shares outstanding and all held by LG&E and KU Energy LLC, a wholly-owned, indirect subsidiary of PPL Corporation, at April 25, 2025.

This document is available free of charge at the Investors section of PPL Corporation's website at www.pplweb.com. However, other information on this website does not constitute a part of this Form 10-Q.

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PPL CORPORATION

PPL ELECTRIC UTILITIES CORPORATION

LOUISVILLE GAS AND ELECTRIC COMPANY

KENTUCKY UTILITIES COMPANY

FORM 10-Q

FOR THE QUARTER ENDED MARCH 31, 2025

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This combined Form 10-Q is separately filed by the following Registrants in their individual capacity: PPL Corporation, PPL Electric Utilities Corporation, Louisville Gas and Electric Company and Kentucky Utilities Company. 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, except that information under "Forward-Looking Information" relating to subsidiaries of PPL Corporation is also attributed to PPL Corporation.

Unless otherwise specified, references in this Report, individually, to PPL Corporation, PPL Electric Utilities Corporation, Louisville Gas and Electric Company and Kentucky Utilities Company are references to such entities directly or to one or more of their subsidiaries, as the case may be, the financial results of which subsidiaries are consolidated into such Registrants' financial statements in accordance with GAAP. This presentation has been applied where identification of particular subsidiaries is not material to the matter being disclosed, and to conform narrative disclosures to the presentation of financial information on a consolidated basis.

				Page
GLOSSARY OF TERMS AND ABBREVIATIONS				i
FORWARD-LOOKING INFORMATION				1
PART I.  FINANCIAL INFORMATION
	Item 1.  Financial Statements
		PPL Corporation and Subsidiaries
			Condensed Consolidated Statements of Income	3
			Condensed Consolidated Statements of Comprehensive Income	4
			Condensed Consolidated Statements of Cash Flows	5
			Condensed Consolidated Balance Sheets	6
			Condensed Consolidated Statements of Equity	8
		PPL Electric Utilities Corporation and Subsidiaries
			Condensed Consolidated Statements of Income	10
			Condensed Consolidated Statements of Cash Flows	11
			Condensed Consolidated Balance Sheets	12
			Condensed Consolidated Statements of Equity	14
		Louisville Gas and Electric Company
			Condensed Statements of Income	16
			Condensed Statements of Cash Flows	17
			Condensed Balance Sheets	18
			Condensed Statements of Equity	20
		Kentucky Utilities Company
			Condensed Statements of Income	22
			Condensed Statements of Cash Flows	23
			Condensed Balance Sheets	24
			Condensed Statements of Equity	26

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	Combined Notes to Condensed Financial Statements (Unaudited)
		Index to Combined Notes to Condensed Financial Statements		27
		1.   Interim Financial Statements		27
		2.   Segment and Related Information		28
		3.   Revenue from Contracts with Customers		30
		4.   Earnings Per Share		32
		5.   Income Taxes		33
		6.   Utility Rate Regulation		34
		7.   Financing Activities		38
		8.   Acquisitions, Developments and Divestitures		41
		9.   Defined Benefits		41
		10. Commitments and Contingencies		42
		11. Related Party Transactions		47
		12. Other Income (Expense) - net		48
		13. Fair Value Measurements		48
		14. Derivative Instruments and Hedging Activities		51
		15. Asset Retirement Obligations		57
		16. Accumulated Other Comprehensive Income (Loss)		58
		17. New Accounting Guidance Pending Adoption		59
	Item 2.  Combined Management's Discussion and Analysis of Financial Condition and Results of Operations
		Overview		60
			Introduction	60
			Business Strategy	62
			Financial and Operational Developments	62
		Results of Operations		64
			PPL Corporation and Subsidiaries - Statement of Income Analysis and Segment Earnings	65
			PPL Electric Utilities Corporation and Subsidiaries - Statement of Income Analysis	72
			Louisville Gas and Electric Company - Statement of Income Analysis	73
			Kentucky Utilities Company - Statement of Income Analysis	74
		Financial Condition		75
			Liquidity and Capital Resources	75
			Risk Management	80
			Related Party Transactions	81
			Acquisitions, Development and Divestitures	81
			Environmental Matters	82
		New Accounting Guidance		84
		Application of Critical Accounting Policies		84
	Item 3.  Quantitative and Qualitative Disclosures About Market Risk			85
	Item 4.  Controls and Procedures			85
PART II.  OTHER INFORMATION
	Item 1. Legal Proceedings			85
	Item 1A. Risk Factors			85
	Item 4. Mine Safety Disclosures			85
	Item 5. Other Information			86
	Item 6. Exhibits			86
SIGNATURES				88
CERTIFICATES OF PRINCIPAL EXECUTIVE OFFICER AND PRINCIPAL FINANCIAL OFFICER PURSUANT TO SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002
CERTIFICATES OF PRINCIPAL EXECUTIVE OFFICER AND PRINCIPAL FINANCIAL OFFICER PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

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GLOSSARY OF TERMS AND ABBREVIATIONS

PPL Corporation and its subsidiaries

CEP Reserves - CEP Reserves Inc., a cash management subsidiary of PPL that maintains cash reserves for the balance sheet management of PPL and certain subsidiaries.

KU - Kentucky Utilities Company, a public utility subsidiary of LKE engaged in the regulated generation, transmission, distribution and sale of electricity, primarily in Kentucky.

LG&E - Louisville Gas and Electric Company, a public utility subsidiary of LKE engaged in the regulated generation, transmission, distribution and sale of electricity and the distribution and sale of natural gas in Kentucky.

LKE - LG&E and KU Energy LLC, a subsidiary of PPL and the parent of LG&E, KU and other subsidiaries.

LKS - LG&E and KU Services Company, a subsidiary of LKE that provides administrative, management and support services primarily to LG&E and KU, as well as to LKE and its other subsidiaries.

Narragansett Electric - The Narragansett Electric Company, an entity that serves electric and natural gas customers in Rhode Island. On May 25, 2022, PPL and its subsidiary, PPL Rhode Island Holdings announced the completion of the acquisition of Narragansett Electric, which continues to provide services under the name Rhode Island Energy. Narragansett Electric is sometimes referred to as Rhode Island Energy or RIE.

PPL - PPL Corporation, the ultimate parent holding company of PPL Electric, PPL Energy Funding, PPL Capital Funding, LKE, RIE and other subsidiaries.

PPL Capital Funding - PPL Capital Funding, Inc., a financing subsidiary of PPL that provides financing for the operations of PPL and certain subsidiaries. Debt issued by PPL Capital Funding is fully and unconditionally guaranteed as to payment by PPL.

PPL Electric - PPL Electric Utilities Corporation, a public utility subsidiary of PPL engaged in the regulated transmission and distribution of electricity in its Pennsylvania service area and that provides electricity supply to its retail customers in this area as a PLR.

PPL Energy Funding - PPL Energy Funding Corporation, a subsidiary of PPL and the parent holding company of PPL Global and other subsidiaries.

PPL Energy Holdings - PPL Energy Holdings, LLC, a subsidiary of PPL and the parent holding company of PPL Energy Funding, LKE, PPL Electric, PPL Rhode Island Holdings, PPL Services and other subsidiaries.

PPL Global - PPL Global, LLC, a subsidiary of PPL Energy Funding that, prior to the sale of the U.K. utility business on June 14, 2021, primarily through its subsidiaries, owned and operated WPD, PPL's regulated electricity distribution businesses in the U.K. PPL Global was not included in the sale of the U.K. utility business on June 14, 2021.

PPL Rhode Island Holdings - PPL Rhode Island Holdings, LLC, a subsidiary of PPL Energy Holdings formed for the purpose of acquiring Narragansett Electric to which certain interests of PPL Energy Holdings in the Narragansett Stock Purchase Agreement were assigned.

PPL Services - PPL Services Corporation, a subsidiary of PPL that provides administrative, management and support services to PPL and its subsidiaries.

PPL WPD Limited - PPL WPD Limited, a U.K. subsidiary of PPL Global. Prior to the sale of the U.K. utility business on June 14, 2021, PPL WPD Limited was an indirect parent to WPD. PPL WPD Limited was not included in the sale of the U.K. utility business on June 14, 2021.

RIE - Rhode Island Energy, the name under which Narragansett Electric provides gas and electric services to customers in Rhode Island.

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Other terms and abbreviations

£ - British pound sterling.

2024 Form 10-K - Annual Report to the SEC on Form 10-K for the year ended December 31, 2024.

Act 11 - Act 11 of 2012 that became effective on April 16, 2012. The Pennsylvania legislation authorized the PAPUC to approve two specific ratemaking mechanisms: the use of a fully projected future test year in base rate proceedings and, subject to certain conditions, a DSIC.

Act 129 - Act 129 of 2008 that became effective in October 2008. The law amended the Pennsylvania Public Utility Code and created an energy efficiency and conservation program and smart metering technology requirements, adopted new PLR electricity supply procurement rules, provided remedies for market misconduct and changed the Alternative Energy Portfolio Standard (AEPS).

AFUDC - allowance for funds used during construction. The cost of equity and debt funds used to finance construction projects of regulated businesses, which is capitalized as part of construction costs.

AOCI - accumulated other comprehensive income or loss.

ARO - asset retirement obligation.

ATM Program - at-the-market stock offering program.

Bcf - billion cubic feet. A unit of measure commonly used in quoting volumes of natural gas.

CCR(s) - coal combustion residual(s). CCRs include fly ash, bottom ash and sulfur dioxide scrubber wastes.

Clean Air Act - federal legislation enacted to address certain environmental issues related to air emissions, including acid rain, ozone and toxic air emissions.

CPCN - Certificate of Public Convenience and Necessity. Authority granted by the KPSC pursuant to Kentucky Revised Statute 278.020 to provide utility service to or for the public or the construction of certain plant, equipment, property or facilities for furnishing of utility service to the public. A CPCN is required for any capital addition, subject to KPSC jurisdiction, in excess of $100 million.

Customer Choice Act - the Pennsylvania Electricity Generation Customer Choice and Competition Act, legislation enacted to restructure the state's electric utility industry to create retail access to a competitive market for generation of electricity.

DSIC - Distribution System Improvement Charge. Authorized under Act 11, which is an alternative ratemaking mechanism providing more-timely cost recovery of qualifying distribution system capital expenditures.

DSM - Demand Side Management. Pursuant to Kentucky Revised Statute 278.285, the KPSC may determine the reasonableness of DSM programs proposed by any utility under its jurisdiction. DSM programs consist of energy efficiency programs intended to reduce peak demand and delay the investment in additional power plant construction, provide customers with tools and information regarding their energy usage and support energy efficiency.

Earnings from Ongoing Operations - a non-GAAP financial measure of earnings adjusted for the impact of special items and used in "Item 2. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" (MD&A).

ECR - Environmental Cost Recovery. Pursuant to Kentucky Revised Statute 278.183, Kentucky electric utilities are entitled to the current recovery of costs of complying with the Clean Air Act, as amended, and those federal, state or local environmental requirements that apply to coal combustion wastes and byproducts from the production of energy from coal.

ELG(s) - Effluent Limitation Guidelines, regulations promulgated by the EPA.

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Environmental Response Fund - Established in RIPUC Docket No. 2930. Created to satisfy remedial and clean-up obligations of RIE arising from the past ownership and/or operation of manufactured gas plants and sites associated with the operation and disposal activities of such gas plants.

EPA - Environmental Protection Agency, a U.S. government agency.

EPS - earnings per share.

FERC - Federal Energy Regulatory Commission, the U.S. federal agency that regulates, among other things, interstate transmission and wholesale sales of electricity, hydroelectric power projects and related matters.

FY - fiscal year.

GAAP - Generally Accepted Accounting Principles in the U.S.

GHG(s) - greenhouse gas(es).

GLT - gas line tracker. The KPSC approved mechanism for LG&E's recovery of certain costs associated with gas transmission lines, gas service lines, gas risers, leak mitigation, and gas main replacements.

IBEW - International Brotherhood of Electrical Workers.

IRS - Internal Revenue Service, a U.S. government agency.

ISO - Independent System Operator.

ISR - Infrastructure, safety and reliability.

KPSC - Kentucky Public Service Commission, the state agency that has jurisdiction over the regulation of rates and service of utilities in Kentucky.

Mill Creek Unit 5 - a combined cycle natural gas unit under construction in Kentucky, jointly owned by LG&E and KU, which is expected to provide additional generating capacity of 200 MW and 445 MW to LG&E and KU beginning in 2027.

Moody's - Moody's Investors Service, Inc., a credit rating agency.

MW - megawatt, one thousand kilowatts.

NAAQS - National Ambient Air Quality Standards periodically adopted pursuant to the Clean Air Act. 

National Grid USA - National Grid USA is a wholly-owned subsidiary of National Grid plc, a British multinational electricity and gas utility company headquartered in London, England.

NEP - New England Power Company, a National Grid U.S. affiliate.

NERC - North American Electric Reliability Corporation.

NGCC - Natural gas combined cycle.

NPNS - the normal purchases and normal sales exception as permitted by derivative accounting rules. Derivatives that qualify for this exception may receive accrual accounting treatment.

OCI - other comprehensive income or loss.

OVEC - Ohio Valley Electric Corporation, located in Piketon, Ohio, an entity in which LG&E owns a 5.63% interest and KU owns a 2.50% interest, which are recorded at cost. OVEC owns and operates two coal-fired power plants, the Kyger Creek plant in Ohio and the Clifty Creek plant in Indiana, with combined capacities of 2,120 MW.

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PAPUC - Pennsylvania Public Utility Commission, the state agency that regulates certain ratemaking, services, accounting and operations of Pennsylvania utilities.

PHMSA - Pipeline and Hazardous Materials Safety Administration.

PLR - Provider of Last Resort, the role of PPL Electric in providing default electricity supply within its delivery area to retail customers who have not chosen to select an alternative electricity supplier under the Customer Choice Act.

PP&E - property, plant and equipment.

RAR - Retired Asset Recovery rider, established by KPSC orders in 2021 to provide for recovery of and return on the remaining investment in certain electric generating units upon their retirement over a ten-year period following retirement.

Registrant(s) - refers to the Registrants named on the cover of this Report (each a "Registrant" and collectively, the "Registrants").

Regulation S-X - SEC regulation governing the form and content of and requirements for financial statements required to be filed pursuant to the federal securities laws.

RIPUC - Rhode Island Public Utilities Commission, a three-member quasi-judicial tribunal with jurisdiction, powers, and duties to implement and enforce the standards of conduct under R.I. Gen. Laws § 39-1-27.6 and to hold investigations and hearings involving the rates, tariffs, tolls, and charges, and the sufficiency and reasonableness of facilities and accommodations of public utilities.

Rhode Island Division of Public Utilities and Carriers - the Rhode Island Division of Public Utilities and Carriers, which is headed by an Administrator who is not a Commissioner of the RIPUC, exercises the jurisdiction, supervision, power, and duties not specifically assigned to the RIPUC.

Safari Energy - Safari Energy, LLC, which was, prior to the sale of Safari Holdings on November 1, 2022, a subsidiary of Safari Holdings that provided solar energy solutions for commercial customers in the U.S.

Safari Holdings - Safari Holdings, LLC, which was, prior to its sale on November 1, 2022, a subsidiary of PPL and parent holding company of Safari Energy.

Sarbanes-Oxley - Sarbanes-Oxley Act of 2002, which sets requirements for management's assessment of internal controls for financial reporting. It also requires an independent auditor to make its own assessment.

Scrubber - an air pollution control device that can remove particulates and/or gases (primarily sulfur dioxide) from exhaust gases.

SEC - the U.S. Securities and Exchange Commission, a U.S. government agency primarily responsible to protect investors and maintain the integrity of the securities markets.

Smart metering technology - technology that can measure, among other things, time of electricity consumption to permit offering rate incentives for usage during lower cost or demand intervals. The use of this technology also has the potential to strengthen network reliability.

SOFR - Secured Overnight Financing Rate, a broad measure of the cost of borrowing cash overnight collateralized by Treasury securities.

S&P - S&P Global Ratings, a credit rating agency.

Superfund - federal environmental statute that addresses remediation of contaminated sites; states also have similar statutes.

TCJA - Tax Cuts and Jobs Act. Comprehensive U.S. federal tax legislation enacted on December 22, 2017.

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Treasury Stock Method - a method applied to calculate diluted EPS that assumes any proceeds that could be obtained upon exercise of options and warrants (and their equivalents) would be used to purchase common stock at the average market price during the relevant period.

U.K. utility business - PPL WPD Investments Limited and its subsidiaries, including, notably, WPD plc and the four distribution network operators, which substantially represented PPL's U.K. Regulated segment. The U.K. utility business was sold on June 14, 2021.

UWUA - Utility Workers Union of America.

VEBA - Voluntary Employee Beneficiary Association, a tax-exempt trust under the Internal Revenue Code Section 501(c)(9) used by employers to fund and pay eligible medical, life and similar benefits.

VSCC - Virginia State Corporation Commission, the state agency that has jurisdiction over the regulation of Virginia corporations, including utilities.

WPD - Prior to the sale of the U.K. utility business on June 14, 2021, refers to PPL WPD Investments Limited and its subsidiaries. WPD was included in the sale of the U.K. utility business on June 14, 2021.

WPD plc - Western Power Distribution plc, prior to the sale of the U.K utility business, a U.K. indirect subsidiary of PPL WPD Limited. Its principal indirectly owned subsidiaries are WPD (East Midlands), WPD (South Wales), WPD (South West) and WPD (West Midlands). WPD plc was included in the sale of the U.K. utility business on June 14, 2021.

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Forward-looking Information

Statements contained in this Form 10-Q concerning expectations, beliefs, plans, objectives, goals, strategies, future events or performance and underlying assumptions and other statements that are other than statements of historical fact are "forward-looking statements" within the meaning of the federal securities laws. Although the Registrants believe that the expectations and assumptions reflected in these statements are reasonable, there can be no assurance that these expectations will prove to be correct. Forward-looking statements are subject to many risks and uncertainties, and actual results may differ materially from the results discussed in forward-looking statements. In addition to the specific factors discussed in each Registrant's 2024 Form 10-K and in "Item 2. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" in this Form 10-Q, the following are among the important factors that could cause actual results to differ materially and adversely from the forward-looking statements:

•weather and other conditions affecting generation, transmission and distribution operations, operating costs and customer energy use;

•strategic acquisitions, dispositions, or similar transactions and our ability to consummate these business transactions, integrate the acquired entities or realize expected benefits from them;

•pandemic health events or other catastrophic events such as wildfires, earthquakes, explosions, floods, droughts, tornadoes, hurricanes and other extreme weather-related events (including events potentially caused or exacerbated by climate change) and their impact on economic conditions, financial markets and supply chains;

•capital market conditions, including the availability of capital, credit or insurance, changes in interest rates and certain economic indices, and decisions regarding capital structure;

•volatility in or the impact of other changes in financial markets, commodity prices and economic conditions, including inflation;

•the outcome of rate cases or other cost recovery, revenue or regulatory proceedings;

•the direct or indirect effects on PPL or its subsidiaries or business systems of cyber-based intrusion or the threat of cyberattacks;

•development, adoption and use of artificial intelligence by us, our customers and our third-party vendors;

•the effect of recently established tariffs, the establishment of additional tariffs, or subsequent changes to tariffs once announced or implemented, on the cost or availability of imported goods;

•significant changes in the demand for electricity;

•expansion of alternative and distributed sources of electricity generation and storage;

•the effectiveness of our risk management programs, including commodity and interest rate hedging;

•defaults by counterparties or suppliers for energy, capacity, coal, natural gas or key commodities, goods or services;

•a material decline in the market value of PPL's equity;

•significant decreases in the fair value of debt and equity securities and their impact on the value of assets in defined benefit plans, and the related cash funding requirements if the fair value of those assets decline;

•interest rates and their effect on pension and retiree medical liabilities, ARO liabilities, interest payable on certain debt securities, and the general economy;

•the potential impact of any unrecorded commitments and liabilities of the Registrants and their subsidiaries;

•new accounting requirements or new interpretations or applications of existing requirements;

•adverse changes in the corporate credit ratings or securities analyst rankings of the Registrants and their securities;

•any requirement to record impairment charges pursuant to GAAP with respect to any of our significant investments;

•laws or regulations to reduce emissions of GHGs or the physical effects of climate change;

•the availability of electricity and natural gas, and any consequences of a perceived or actual inability to serve demand reliably;

•continuing ability to access fuel supply for LG&E and KU, as well as the ability to recover fuel costs and environmental expenditures in a timely manner at LG&E and KU and natural gas supply costs at LG&E and RIE;

•war, armed conflicts, terrorist attacks, or similar disruptive events, including the ongoing conflicts in Ukraine and the Middle East;

•changes in political, regulatory or economic conditions in states or regions where the Registrants or their subsidiaries conduct business;

•the ability to obtain necessary governmental permits and approvals;

•changes in state or federal tax laws or regulations;

•changes in state, federal or foreign legislation or regulatory developments;

•the impact of any state, federal or foreign investigations applicable to the Registrants, their subsidiaries or the energy industry;

•our ability to attract and retain qualified employees;

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•the effect of changing expectations and demands of our customers, regulators, investors and stakeholders, including differing views on environmental, social and governance concerns;

•the effect of any business or industry restructuring;

•the ability to control costs and avoid cost and schedule overruns during the development, construction and operation of generation facilities or other projects;

•development of new projects, markets and technologies;

•performance of new ventures;

•collective labor bargaining negotiations and labor costs;

•risks related to wildfires, including costs of potential regulatory penalties and other liabilities, and the cost and availability of insurance and damages in excess of insurance liability coverage; and

•the outcome of litigation involving the Registrants and their subsidiaries.

Any forward-looking statements should be considered in light of these important factors and in conjunction with other documents of the Registrants on file with the SEC.

New factors that could cause actual results to differ materially from those described in forward-looking statements emerge from time to time, and it is not possible for the Registrants to predict all such factors, or the extent to which any such factor or combination of factors may cause actual results to differ from those contained in any forward-looking statement. Any forward-looking statement speaks only as of the date on which such statement is made, and the Registrants undertake no obligation to update the information contained in the statement to reflect subsequent developments or information.

Investors should note that PPL announces material financial information in SEC filings, press releases and public conference calls. In accordance with SEC guidelines, PPL also uses the Investors section of its website, www.pplweb.com, to communicate with investors. It is possible that the financial and other information posted there could be deemed to be material information. The information on PPL's website is not part of this document.

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PART I. FINANCIAL INFORMATION

ITEM 1. Financial Statements

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, except share data)

	Three Months Ended March 31,
	2025		2024
Operating Revenues	$	2,504	$	2,304
Operating Expenses
Operation
Fuel	234		209
Energy purchases	559		520
Other operation and maintenance	598		626
Depreciation	322		316
Taxes, other than income	113		88
Total Operating Expenses	1,826		1,759
Operating Income	678		545
Other Income (Expense) - net (Note 12)	28		22
Interest Expense	190		179
Income Before Income Taxes	516		388
Income Taxes	102		81
Net Income	$	414	$	307
Earnings Per Share of Common Stock:
Basic and Diluted
Net Income Available to PPL Common Shareowners	$	0.56	$	0.42
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic	738,691		737,512
Diluted	741,400		738,820

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)

	Three Months Ended March 31,
	2025		2024
Net income	$	414	$	307
Other comprehensive income (loss):
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Equity investees' other comprehensive income (loss), net of tax of $0, $0	—		1
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Qualifying derivatives, net of tax of $0, $0	1		1
Defined benefit plans:
Net actuarial (gain) loss, net of tax of $0, $0	(1)		—
Total other comprehensive income (loss)	—		2
Comprehensive income	$	414	$	309

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)

	Three Months Ended March 31,
	2025		2024
Cash Flows from Operating Activities
Net income	$	414	$	307
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	322		316
Amortization	20		24
Defined benefit plans - income	(16)		(15)
Deferred income taxes and investment tax credits	38		72
Other	13		3
Change in current assets and current liabilities
Accounts receivable	(277)		(75)
Accounts payable	(120)		(221)
Unbilled revenues	108		57
Fuel, materials and supplies	37		33
Prepayments	(87)		(108)
Taxes payable	40		(47)
Regulatory assets and liabilities, net	79		(61)
Accrued interest	67		90
Other	(80)		(103)
Other operating activities
Defined benefit plans - funding	(5)		(5)
Other assets	(50)		(1)
Other liabilities	10		16
Net cash provided by operating activities	513		282
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(793)		(596)
Other investing activities	10		5
Net cash used in investing activities	(783)		(591)
Cash Flows from Financing Activities
Issuance of long-term debt	—		1,148
Payment of common stock dividends	(190)		(177)
Net increase (decrease) in short-term debt	475		(701)
Other financing activities	(14)		(22)
Net cash provided by financing activities	271		248
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	1		(61)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	339		382
Cash, Cash Equivalents and Restricted Cash at End of Period	$	340	$	321
Supplemental Disclosures of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at March 31,	$	397	$	253

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED CONSOLIDATED BALANCE SHEETS

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, shares in thousands)

	March 31, 2025		December 31, 2024
Assets
Current Assets
Cash and cash equivalents	$	312	$	306
Accounts receivable (less reserve: 2025, $166; 2024, $147)
Customer	1,208		961
Other	93		76
Unbilled revenues (less reserve: 2025, $4; 2024, $6)	377		485
Fuel, materials and supplies	476		511
Prepayments	223		136
Regulatory assets	274		320
Other current assets	133		85
Total Current Assets	3,096		2,880
Property, Plant and Equipment
Regulated utility plant	40,648		40,391
Less: accumulated depreciation - regulated utility plant	9,751		9,682
Regulated utility plant, net	30,897		30,709
Non-regulated property, plant and equipment	80		79
Less: accumulated depreciation - non-regulated property, plant and equipment	30		29
Non-regulated property, plant and equipment, net	50		50
Construction work in progress	2,695		2,390
Property, Plant and Equipment, net	33,642		33,149
Other Noncurrent Assets
Regulatory assets	2,049		2,060
Goodwill	2,247		2,247
Other intangibles	312		314
Other noncurrent assets (less reserve for accounts receivable: 2025, $2; 2024, $1)	463		419
Total Other Noncurrent Assets	5,071		5,040
Total Assets	$	41,809	$	41,069

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED CONSOLIDATED BALANCE SHEETS

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, shares in thousands)

	March 31, 2025		December 31, 2024
Liabilities and Equity
Current Liabilities
Short-term debt	$	778	$	303
Long-term debt due within one year	569		551
Accounts payable	1,097		1,196
Taxes	143		103
Interest	224		157
Dividends	197		186
Regulatory liabilities	274		223
Other current liabilities	545		614
Total Current Liabilities	3,827		3,333
Long-term Debt	15,938		15,952
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	3,421		3,356
Investment tax credits	111		111
Accrued pension obligations	298		317
Asset retirement obligations	130		136
Regulatory liabilities	3,338		3,335
Other deferred credits and noncurrent liabilities	449		452
Total Deferred Credits and Other Noncurrent Liabilities	7,747		7,707
Commitments and Contingent Liabilities (Notes 6 and 10)
Equity
Common stock - $0.01 par value (a)	8		8
Additional paid-in capital	12,330		12,346
Treasury stock	(904)		(928)
Earnings reinvested	3,047		2,835
Accumulated other comprehensive loss	(184)		(184)
Total Equity	14,297		14,077
Total Liabilities and Equity	$	41,809	$	41,069

(a)1,560,000 shares authorized, 770,415 shares issued and 739,066 shares outstanding at March 31, 2025. 1,560,000 shares authorized, 770,215 shares issued and 738,033 shares outstanding at December 31, 2024.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

PPL Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)

	Common stock shares outstanding (a)	Common stock		Additional paid-in capital		Treasury stock		Earnings reinvested		Accumulated other comprehensive loss		Total
December 31, 2024	738,033	$	8	$	12,346	$	(928)	$	2,835	$	(184)	$	14,077
Common stock issued	200			—								—
Treasury stock issued	833			—		24						24
Stock-based compensation				(16)								(16)
Net income								414				414
Dividends and dividend equivalents (b)								(202)				(202)
Other comprehensive income (loss)										—		—
March 31, 2025	739,066	$	8	$	12,330	$	(904)	$	3,047	$	(184)	$	14,297
December 31, 2023	737,130	$	8	$	12,326	$	(948)	$	2,710	$	(163)	$	13,933
Treasury stock issued	606			—		17						17
Stock-based compensation				(12)								(12)
Net income								307				307
Dividends and dividend equivalents (b)								(189)				(189)
Other comprehensive income (loss)										2		2
March 31, 2024	737,736	$	8	$	12,314	$	(931)	$	2,828	$	(161)	$	14,058

(a)Shares in thousands. Each share entitles the holder to one vote on any question presented at any shareowners' meeting.

(b)Dividends declared per share of common stock were $0.2725 and $0.2575 for the three months ended March 31, 2025 and March 31, 2024.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED CONSOLIDATED STATEMENTS OF INCOME

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)

	Three Months Ended March 31,
	2025		2024
Operating Revenues	$	819	$	770
Operating Expenses
Operation
Energy purchases	229		214
Other operation and maintenance	162		181
Depreciation	102		99
Taxes, other than income	41		36
Total Operating Expenses	534		530
Operating Income	285		240
Other Income (Expense) - net (Note 12)	11		9
Interest Income from Affiliate	2		10
Interest Expense	60		62
Income Before Income Taxes	238		197
Income Taxes	54		48
Net Income (a)	$	184	$	149

(a)Net income equals comprehensive income.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)

	Three Months Ended March 31,
	2025		2024
Cash Flows from Operating Activities
Net income	$	184	$	149
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	102		99
Amortization	11		12
Defined benefit plans - income	(7)		(11)
Deferred income taxes and investment tax credits	20		32
Other	(5)		(7)
Change in current assets and current liabilities
Accounts receivable	(132)		(33)
Accounts payable	(7)		(59)
Unbilled revenues	43		30
Materials and supplies	(8)		(4)
Prepayments	(90)		(110)
Regulatory assets and liabilities, net	36		(28)
Taxes payable	(2)		(48)
Accrued interest	19		35
Other	(13)		(26)
Other operating activities
Other assets	(18)		—
Other liabilities	1		(3)
Net cash provided by operating activities	134		28
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(328)		(229)
Expenditures for intangible assets	(1)		(1)
Notes receivable from affiliates	222		(554)
Other investing activities	10		4
Net cash used in investing activities	(97)		(780)
Cash Flows from Financing Activities
Issuance of long-term debt	—		649
Contributions from parent	—		675
Payment of common stock dividends to parent	(88)		(88)
Net increase (decrease) in short-term debt	55		(509)
Debt issuance costs	(1)		(5)
Net cash provided by (used in) financing activities	(34)		722
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash	3		(30)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period	24		51
Cash, Cash Equivalents and Restricted Cash at End of Period	$	27	$	21
Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at March 31,	$	185	$	146

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED CONSOLIDATED BALANCE SHEETS

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, shares in thousands)

	March 31, 2025		December 31, 2024
Assets
Current Assets
Cash and cash equivalents	$	27	$	24
Accounts receivable (less reserve: 2025, $39; 2024, $37)
Customer	457		353
Other	21		8
Accounts receivable from affiliates	11		10
Notes receivable from affiliate	—		222
Unbilled revenues (less reserve: 2025, $2; 2024, $3)	116		159
Materials and supplies	110		104
Prepayments	164		74
Regulatory assets	94		133
Other current assets	43		30
Total Current Assets	1,043		1,117
Property, Plant and Equipment
Regulated utility plant	16,503		16,469
Less: accumulated depreciation - regulated utility plant	3,983		4,052
Regulated utility plant, net	12,520		12,417
Construction work in progress	1,032		898
Property, Plant and Equipment, net	13,552		13,315
Other Noncurrent Assets
Regulatory assets	685		673
Intangibles	274		274
Other noncurrent assets (less reserve for accounts receivable: 2025, $2; 2024, $1)	100		96
Total Other Noncurrent Assets	1,059		1,043
Total Assets	$	15,654	$	15,475

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED CONSOLIDATED BALANCE SHEETS

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars, shares in thousands)

	March 31, 2025		December 31, 2024
Liabilities and Equity
Current Liabilities
Short-term debt	$	55	$	—
Accounts payable	477		565
Accounts payable to affiliates	133		44
Interest	74		55
Regulatory liabilities	54		57
Other current liabilities	77		85
Total Current Liabilities	870		806
Long-term Debt	5,214		5,214
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	1,756		1,726
Regulatory liabilities	835		839
Other deferred credits and noncurrent liabilities	153		160
Total Deferred Credits and Other Noncurrent Liabilities	2,744		2,725
Commitments and Contingent Liabilities (Notes 6 and 10)
Equity
Common stock - no par value (a)	364		364
Additional paid-in capital	4,668		4,668
Earnings reinvested	1,794		1,698
Total Equity	6,826		6,730
Total Liabilities and Equity	$	15,654	$	15,475

(a)170,000 shares authorized; 66,368 shares issued and outstanding at March 31, 2025 and December 31, 2024.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED CONSOLIDATED STATEMENTS OF EQUITY

PPL Electric Utilities Corporation and Subsidiaries

(Unaudited)

(Millions of Dollars)

	Common stock shares outstanding (a)	Common stock		Additional paid-in capital		Earnings reinvested		Total
December 31, 2024	66,368	$	364	$	4,668	$	1,698	$	6,730
Net income						184		184
Dividends declared						(88)		(88)
March 31, 2025	66,368	$	364	$	4,668	$	1,794	$	6,826
December 31, 2023	66,368	$	364	$	4,040	$	1,499	$	5,903
Net income						149		149
Capital contributions from parent				675				675
Dividends declared						(88)		(88)
March 31, 2024	66,368	$	364	$	4,715	$	1,560	$	6,639

(a)Shares in thousands. All common shares of PPL Electric stock are owned by PPL Energy Holdings.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED STATEMENTS OF INCOME

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars)

	Three Months Ended March 31,
	2025		2024
Operating Revenues
Retail and wholesale	$	500	$	460
Electric revenue from affiliate	5		16
Total Operating Revenues	505		476
Operating Expenses
Operation
Fuel	82		86
Energy purchases	88		71
Energy purchases from affiliate	5		1
Other operation and maintenance	89		88
Depreciation	74		76
Taxes, other than income	13		13
Total Operating Expenses	351		335
Operating Income	154		141
Other Income (Expense) - net	3		2
Interest Expense	26		26
Income Before Income Taxes	131		117
Income Taxes	26		24
Net Income (a)	$	105	$	93

(a)Net income equals comprehensive income.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

16

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CONDENSED STATEMENTS OF CASH FLOWS

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars)

	Three Months Ended March 31,
	2025		2024
Cash Flows from Operating Activities
Net income	$	105	$	93
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	74		76
Amortization	4		3
Deferred income taxes and investment tax credits	1		2
Other	—		1
Change in current assets and current liabilities
Accounts receivable	(11)		(19)
Accounts receivable from affiliates	12		(11)
Accounts payable	23		6
Accounts payable to affiliates	26		34
Unbilled revenues	19		16
Fuel, materials and supplies	23		13
Regulatory assets and liabilities, net	(21)		(21)
Taxes payable	(23)		(26)
Accrued interest	23		23
Other	(19)		(19)
Other operating activities
Expenditures for asset retirement obligations	(2)		(2)
Other assets	(32)		—
Other liabilities	(3)		(3)
Net cash provided by operating activities	199		166
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(117)		(92)
Net increase in notes receivable with affiliates	(5)		(28)
Net cash used in investing activities	(122)		(120)
Cash Flows from Financing Activities
Net decrease in notes payable to affiliates	(43)		—
Net increase in short-term debt	64		28
Payment of common stock dividends to parent	(43)		(37)
Return of capital to parent	(55)		(51)
Debt issuance costs	(1)		—
Net cash used in financing activities	(78)		(60)
Net Decrease in Cash, Cash Equivalents, and Restricted Cash	(1)		(14)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	24		44
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	23	$	30
Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at March 31,	$	72	$	35

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

17

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CONDENSED BALANCE SHEETS

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars, shares in thousands)

	March 31, 2025		December 31, 2024
Assets
Current Assets
Cash and cash equivalents	$	10	$	8
Accounts receivable (less reserve: 2025, $5; 2024, $3)
Customer	141		134
Other	31		23
Unbilled revenues (less reserve: 2025, $0; 2024, $0)	68		87
Accounts receivable from affiliates	28		40
Notes receivable from affiliates	5		—
Fuel, materials and supplies	134		157
Prepayments	9		9
Regulatory assets	31		8
Other current assets	11		2
Total Current Assets	468		468
Property, Plant and Equipment
Regulated utility plant	7,787		7,748
Less: accumulated depreciation - regulated utility plant	1,696		1,643
Regulated utility plant, net	6,091		6,105
Construction work in progress	515		443
Property, Plant and Equipment, net	6,606		6,548
Other Noncurrent Assets
Regulatory assets	491		491
Goodwill	389		389
Other intangibles	11		12
Other noncurrent assets	116		84
Total Other Noncurrent Assets	1,007		976
Total Assets	$	8,081	$	7,992

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

18

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CONDENSED BALANCE SHEETS

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars, shares in thousands)

	March 31, 2025		December 31, 2024
Liabilities and Equity
Current Liabilities
Short-term debt	$	89	$	25
Long-term debt due within one year	300		300
Notes payable to affiliates	—		43
Accounts payable	193		158
Accounts payable to affiliates	90		64
Customer deposits	36		36
Taxes	17		40
Regulatory liabilities	16		14
Interest	44		21
Asset retirement obligations	10		11
Other current liabilities	41		50
Total Current Liabilities	836		762
Long-term Debt	2,171		2,171
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	809		803
Investment tax credits	29		30
Price risk management liabilities	4		3
Asset retirement obligations	74		73
Regulatory liabilities	814		815
Other deferred credits and noncurrent liabilities	66		64
Total Deferred Credits and Other Noncurrent Liabilities	1,796		1,788
Commitments and Contingent Liabilities (Notes 6 and 10)
Stockholder's Equity
Common stock - no par value (a)	424		424
Additional paid-in capital	1,927		1,982
Earnings reinvested	927		865
Total Equity	3,278		3,271
Total Liabilities and Equity	$	8,081	$	7,992

(a)75,000 shares authorized; 21,294 shares issued and outstanding at March 31, 2025 and December 31, 2024.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED STATEMENTS OF EQUITY

Louisville Gas and Electric Company

(Unaudited)

(Millions of Dollars)

	Common stock shares outstanding (a)	Common stock		Additional paid-in capital		Earnings reinvested		Total
December 31, 2024	21,294	$	424	$	1,982	$	865	$	3,271
Net income						105		105
Return of capital to parent				(55)				(55)
Dividends declared						(43)		(43)
March 31, 2025	21,294	$	424	$	1,927	$	927	$	3,278
December 31, 2023	21,294	$	424	$	1,993	$	755	$	3,172
Net income						93		93
Return of capital to parent				(51)				(51)
Dividends declared						(37)		(37)
March 31, 2024	21,294	$	424	$	1,942	$	811	$	3,177

(a)Shares in thousands. All common shares of LG&E stock are owned by LKE.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED STATEMENTS OF INCOME

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars)

	Three Months Ended March 31,
	2025		2024
Operating Revenues
Retail and wholesale	$	559	$	524
Electric revenue from affiliate	5		1
Total Operating Revenues	564		525
Operating Expenses
Operation
Fuel	152		123
Energy purchases	7		6
Energy purchases from affiliate	5		16
Other operation and maintenance	100		102
Depreciation	102		99
Taxes, other than income	12		12
Total Operating Expenses	378		358
Operating Income	186		167
Other Income (Expense) - net	5		2
Interest Expense	35		34
Income Before Income Taxes	156		135
Income Taxes	31		27
Net Income (a)	$	125	$	108

(a)Net income equals comprehensive income.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED STATEMENTS OF CASH FLOWS

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars)

	Three Months Ended March 31,
	2025		2024
Cash Flows from Operating Activities
Net income	$	125	$	108
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation	102		99
Amortization	4		5
Deferred income taxes and investment tax credits	3		(1)
Other	(3)		(2)
Change in current assets and current liabilities
Accounts receivable	(29)		(21)
Accounts payable	(3)		(13)
Accounts payable to affiliates	29		52
Unbilled revenues	18		6
Fuel, materials and supplies	7		8
Regulatory assets and liabilities, net	5		1
Taxes payable	(18)		(17)
Accrued interest	32		32
Other	(3)		(7)
Other operating activities
Expenditures for asset retirement obligations	(2)		(2)
Other assets	(9)		8
Other liabilities	(5)		(4)
Net cash provided by operating activities	253		252
Cash Flows from Investing Activities
Expenditures for property, plant and equipment	(174)		(148)
Other investing activities	—		—
Net cash used in investing activities	(174)		(148)
Cash Flows from Financing Activities
Net increase in notes payable to affiliates	(65)		37
Net increase (decrease) in short-term debt	68		(48)
Payment of common stock dividends to parent	(46)		(47)
Return of capital to parent	(37)		(50)
Debt issuance costs	(1)		—
Net cash used in financing activities	(81)		(108)
Net Decrease in Cash, Cash Equivalents, and Restricted Cash	(2)		(4)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	29		38
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	27	$	34
Supplemental Disclosure of Cash Flow Information
Significant non-cash transactions:
Accrued expenditures for property, plant and equipment at March 31,	$	74	$	44

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

23

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CONDENSED BALANCE SHEETS

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars, shares in thousands)

	March 31, 2025		December 31, 2024
Assets
Current Assets
Cash and cash equivalents	$	14	$	13
Accounts receivable (less reserve: 2025, $2; 2024, $2)
Customer	180		160
Other	28		22
Unbilled revenues (less reserve: 2025, $0; 2024, $0)	84		102
Fuel, materials and supplies	166		173
Prepayments	10		11
Regulatory assets	—		1
Other current assets	16		9
Total Current Assets	498		491
Property, Plant and Equipment
Regulated utility plant	10,454		10,419
Less: accumulated depreciation - regulated utility plant	2,721		2,652
Regulated utility plant, net	7,733		7,767
Construction work in progress	679		567
Property, Plant and Equipment, net	8,412		8,334
Other Noncurrent Assets
Regulatory assets	460		458
Goodwill	607		607
Other intangibles	27		28
Other noncurrent assets	157		155
Total Other Noncurrent Assets	1,251		1,248
Total Assets	$	10,161	$	10,073

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

24

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CONDENSED BALANCE SHEETS

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars, shares in thousands)

	March 31, 2025		December 31, 2024
Liabilities and Equity
Current Liabilities
Short-term debt	$	208	$	140
Long-term debt due within one year	268		250
Notes payable to affiliates	8		73
Accounts payable	89		96
Accounts payable to affiliates	129		100
Customer deposits	39		39
Taxes	19		37
Regulatory liabilities	26		22
Interest	56		24
Asset retirement obligations	14		10
Other current liabilities	61		58
Total Current Liabilities	917		849
Long-term Debt	2,798		2,816
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes	934		924
Investment tax credits	81		81
Asset retirement obligations	47		54
Regulatory liabilities	1,007		1,009
Other deferred credits and noncurrent liabilities	36		41
Total Deferred Credits and Other Noncurrent Liabilities	2,105		2,109
Commitments and Contingent Liabilities (Notes 6 and 10)
Stockholder's Equity
Common stock - no par value (a)	308		308
Additional paid-in capital	3,019		3,056
Earnings reinvested	1,014		935
Total Equity	4,341		4,299
Total Liabilities and Equity	$	10,161	$	10,073

(a)80,000 shares authorized; 37,818 shares issued and outstanding at March 31, 2025 and December 31, 2024.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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CONDENSED STATEMENTS OF EQUITY

Kentucky Utilities Company

(Unaudited)

(Millions of Dollars)

	Common stock shares outstanding (a)	Common stock		Additional paid-in capital		Earnings reinvested		Total
December 31, 2024	37,818	$	308	$	3,056	$	935	$	4,299
Net income						125		125
Return of capital to parent				(37)				(37)
Dividends declared						(46)		(46)
March 31, 2025	37,818	$	308	$	3,019	$	1,014	$	4,341
December 31, 2023	37,818	$	308	$	3,033	$	811	$	4,152
Net income						108		108
Return of capital to parent				(50)				(50)
Dividends declared						(47)		(47)
March 31, 2024	37,818	$	308	$	2,983	$	872	$	4,163

(a)Shares in thousands. All common shares of KU stock are owned by LKE.

The accompanying Notes to Condensed Financial Statements are an integral part of the financial statements.

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Combined Notes to Condensed Financial Statements (Unaudited)

Index to Combined Notes to Condensed Financial Statements

The notes to the condensed financial statements that follow are a combined presentation. The following list indicates the Registrants to which the notes apply:

	Registrant
	PPL	PPL Electric	LG&E	KU
1. Interim Financial Statements	x	x	x	x
2. Segment and Related Information	x	x	x	x
3. Revenue from Contracts with Customers	x	x	x	x
4. Earnings Per Share	x
5. Income Taxes	x	x	x	x
6. Utility Rate Regulation	x	x	x	x
7. Financing Activities	x	x	x	x
8. Acquisitions, Development and Divestitures	x
9. Defined Benefits	x	x	x	x
10. Commitments and Contingencies	x	x	x	x
11. Related Party Transactions		x	x	x
12. Other Income (Expense) - net	x	x
13. Fair Value Measurements	x	x	x	x
14. Derivative Instruments and Hedging Activities	x	x	x	x
15. Asset Retirement Obligations	x		x	x
16. Accumulated Other Comprehensive Income (Loss)	x
17. New Accounting Guidance Pending Adoption	x	x	x	x

1. Interim Financial Statements

(All Registrants)

Capitalized terms and abbreviations appearing in the unaudited combined notes to condensed financial statements are defined in the glossary. Dollars are in millions, except per share data, unless otherwise noted. 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 any Registrant when significant.

The accompanying unaudited condensed financial statements have been prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X and, therefore, do not include all of the information and footnote disclosures required by GAAP for complete financial statements. In the opinion of management, all adjustments considered necessary for a fair presentation in accordance with GAAP are reflected in the condensed financial statements. All adjustments are of a normal recurring nature, except as otherwise disclosed. Each Registrant's Balance Sheet at December 31, 2024 is derived from that Registrant's 2024 audited Balance Sheet. The financial statements and notes thereto should be read in conjunction with the financial statements and notes contained in each Registrant's 2024 Form 10-K. The results of operations for the three months ended March 31, 2025 are not necessarily indicative of the results to be expected for the full year ending December 31, 2025 or other future periods, because results for interim periods can be disproportionately influenced by various factors, developments and seasonal variations.

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2. Segment and Related Information

(PPL)

PPL is organized into three segments, broken down by geographic location: Kentucky Regulated, Pennsylvania Regulated and Rhode Island Regulated.

The Kentucky Regulated segment primarily consists of the regulated electricity generation, transmission and distribution operations conducted by LG&E and KU, as well as LG&E's regulated transmission, distribution and sale of natural gas.

The Pennsylvania Regulated segment consists of the regulated electricity transmission and distribution operations of PPL Electric.

The Rhode Island Regulated segment consists of the regulated electricity transmission and distribution and natural gas distribution operations of RIE.

"Corporate and Other" primarily consists of corporate level financing costs, certain unallocated costs and certain non-recoverable costs incurred in conjunction with the acquisition of Rhode Island Energy. "Corporate and Other" is presented to reconcile segment information to PPL's consolidated results and is not a reportable segment.

The table below provides information about PPL’s segments and includes the reconciliation to consolidated net income for the three months ended March 31, 2025:

	Kentucky Regulated		Pennsylvania Regulated		Rhode Island Regulated		Total
Operating Revenues from external customers (a)	$	1,059	$	819	$	626	$	2,504
Reconciliation of revenue
Corporate and Other revenues							—
Total consolidated revenues							$	2,504
Less:
Fuel	234		—		—		234
Energy Purchases	96		229		235		560
Other operation and maintenance	200		162		200		562
Depreciation	176		102		42		320
Taxes, other than income	25		41		47		113
Other (income) expense - net	(8)		(11)		(7)		(26)
Interest (income) from affiliate	—		(2)		(2)		(4)
Interest expense	60		60		23		143
Income taxes	53		54		18		125
Segment net income	$	223	$	184	$	70	$	477
Reconciliation of segment profit or loss to consolidated net income
Corporate and Other net loss							(63)
Net Income							$	414

(a)See Note 3 for additional information on Operating Revenues.

Other information for the segments and reconciliation to PPL's Consolidated results for the three months ended March 31, 2025 are as follows:

	Kentucky Regulated		Pennsylvania Regulated		Rhode Island Regulated		Total Segments		Corporate and Other		Consolidated Total
Other Segment Disclosures
Amortization (a)	$	5	$	11	$	—	$	16	$	4	$	20
Deferred income taxes and investment tax credits (b)	8		20		(7)		21		17		38
Expenditures for long lived assets	290		328		172		790		3		793

(a)Represents non-cash expense items that include amortization of operating lease right-of-use assets, regulatory assets and liabilities, debt discounts and premiums and debt issuance costs.

(b)Represents a non-cash expense item that is also included in "Income Taxes."

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The table below provides information about PPL’s segments and includes the reconciliation to consolidated net income for the three months ended March 31, 2024:

	Kentucky Regulated		Pennsylvania Regulated		Rhode Island Regulated		Total
Operating Revenues from external customers (a)	$	984	$	770	$	549	$	2,303
Reconciliation of revenue
Corporate and Other revenues							1
Total consolidated revenues							$	2,304
Less:
Fuel	209		—		—		209
Energy Purchases	77		214		229		520
Other operation and maintenance	202		181		156		539
Depreciation	176		99		41		316
Taxes, other than income	25		36		27		88
Other (income) expense - net	(3)		(9)		(7)		(19)
Interest (income) from affiliate	—		(10)		—		(10)
Interest expense	60		62		24		146
Income taxes	48		48		15		111
Segment net income	$	190	$	149	$	64	$	403
Reconciliation of segment profit or loss to consolidated net income
Corporate and Other net loss							(96)
Net Income							$	307

(a)See Note 3 for additional information on Operating Revenues.

Other information for the segments and reconciliation to PPL's Consolidated results for the three months ended March 31, 2024 are as follows:

	Kentucky Regulated		Pennsylvania Regulated		Rhode Island Regulated		Total Segments		Corporate and Other		Consolidated Total
Other Segment Disclosures
Amortization (a)	$	8	$	12	$	—	$	20	$	4	$	24
Deferred income taxes and investment tax credits (b)	4		32		18		54		18		72
Expenditures for long lived assets	241		229		125		595		1		596

(a)Represents non-cash expense items that include amortization of operating lease right-of-use assets, regulatory assets and liabilities, debt discounts and premiums and debt issuance costs.

(b)Represents a non-cash expense item that is also included in "Income Taxes."

The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated Balance Sheets as of:

	March 31, 2025		December 31, 2024
Total Assets
Kentucky Regulated	$	17,789	$	17,626
Pennsylvania Regulated	15,654		15,475
Rhode Island Regulated	7,194		7,055
Corporate and Other (a)	1,172		913
Total	$	41,809	$	41,069

(a)Primarily consists of unallocated items, including cash, PP&E, goodwill and the elimination of inter-segment transactions.

(PPL Electric)

PPL Electric has two operating segments, distribution and transmission, which are aggregated into a single reportable segment.

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The measure of segment assets is reported on PPL Electric's Balance Sheets as total consolidated assets. The measures of significant segment expenses are reported on PPL Electric's Statements of Income. The measures of significant non-cash segment expenses as well as expenditures for long lived assets are reported on PPL Electric's Statements of Cash Flows.

(LG&E and KU)

Each of LG&E and KU operates as a single operating and reportable segment.

The measures of segment assets are reported on the Balance Sheets of LG&E and KU as total assets. The measures of significant segment expenses are reported on the Statements of Income of LG&E and KU. The measures of significant non-cash segment expenses as well as expenditures for long lived assets are reported on the Statements of Cash Flows of LG&E and KU.

3. Revenue from Contracts with Customers

(All Registrants)

See Note 3 in the Registrants' 2024 Form 10-K for a discussion of the principal activities from which PPL Electric, LG&E and KU and PPL’s Pennsylvania Regulated, Rhode Island Regulated, and Kentucky Regulated segments generate their revenues. The following tables reconcile "Operating Revenues" included in each Registrant's Statement of Income with revenues generated from contracts with customers for the periods ended March 31.

	2025 Three Months
	PPL		PPL Electric		LG&E		KU
Operating Revenues (a)(b)	$	2,504	$	819	$	505	$	564
Revenues derived from:
Alternative revenue programs (c)	50		(2)		2		4
Other (d)	(9)		(5)		(1)		(2)
Revenues from Contracts with Customers	$	2,545	$	812	$	506	$	566
	2024 Three Months
	PPL		PPL Electric		LG&E		KU
Operating Revenues (a)(b)	$	2,304	$	770	$	476	$	525
Revenues derived from:
Alternative revenue programs (c)	7		(3)		2		5
Other (d)	(8)		(5)		(1)		(1)
Revenues from Contracts with Customers	$	2,303	$	762	$	477	$	529

(a)PPL includes $626 million for the three months ended March 31, 2025 and $549 million for the three months ended March 31, 2024 of revenues from external customers reported by the Rhode Island Regulated segment. PPL Electric represents revenues from external customers reported by the Pennsylvania Regulated segment and LG&E and KU, net of intercompany power sales and transmission revenues, represent revenues from external customers reported by the Kentucky Regulated segment. See Note 2 for additional information.

(b)PPL's transition services agreement associated with the RIE acquisition ended in the third quarter of 2024. In conjunction with the completion of the agreement, PPL conformed the presentation of RIE's and the Rhode Island Regulated segment’s net metering charges with the presentation of the other segments, resulting in an increase in Operating Revenues and a corresponding increase in Energy purchases beginning in the fourth quarter of 2024. For the quarter ended March 31, 2025, net metering of $41 million was included in Energy purchases on PPL's Statement of Income. For the quarter ended March 31, 2024, $32 million of net metering was presented as a reduction of Operating Revenues on PPL's Statement of Income.

(c)This line item shows the over/under collection of rate mechanisms deemed alternative revenue programs with over-collections of revenue shown as positive amounts in the table above and under-collections shown as negative amounts.

(d)Represents additional revenues outside the scope of revenues from contracts with customers, such as lease and other miscellaneous revenues.

The following tables show revenues from contracts with customers disaggregated by customer class for the periods ended March 31.

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	Three Months
	Residential		Commercial		Industrial		Other (a)		Wholesale - municipality		Wholesale - other (b)		Transmission		Revenues from Contracts with Customers
PPL
2025
PA Regulated	$	457	$	106	$	13	$	13	$	—	$	—	$	223	$	812
KY Regulated	487		280		154		96		7		38		—		1,062
RI Regulated (c)	441		197		18		(35)		—		—		50		671
Total PPL	$	1,385	$	583	$	185	$	74	$	7	$	38	$	273	$	2,545
2024
PA Regulated	$	426	$	106	$	12	$	13	$	—	$	—	$	205	$	762
KY Regulated	443		267		161		97		6		15		—		989
RI Regulated (c)	261		78		4		161		—		—		47		551
Corp and Other	—		—		—		1		—		—		—		1
Total PPL	$	1,130	$	451	$	177	$	272	$	6	$	15	$	252	$	2,303
PPL Electric
2025	$	457	$	106	$	13	$	13	$	—	$	—	$	223	$	812
2024	$	426	$	106	$	12	$	13	$	—	$	—	$	205	$	762
LG&E
2025	$	239	$	147	$	46	$	54	$	—	$	20	$	—	$	506
2024	$	218	$	138	$	47	$	52	$	—	$	22	$	—	$	477
KU
2025	$	248	$	133	$	108	$	42	$	7	$	28	$	—	$	566
2024	$	225	$	129	$	114	$	46	$	6	$	9	$	—	$	529

(a)Primarily includes revenues from pole attachments, street lighting, other public authorities and other non-core businesses, and for the Rhode Island Regulated Segment certain regulatory deferral mechanisms which could result in a reduction in revenues from over collections. For the period ended 2024, the Rhode Island Regulated segment primarily includes open access tariff revenues, which are calculated on combined customer classes.

(b)Includes wholesale power and transmission revenues. LG&E and KU amounts include intercompany power sales and transmission revenues, which are eliminated upon consolidation at the Kentucky Regulated segment.

(c)PPL's transition services agreement associated with the RIE acquisition ended in the third quarter of 2024. In conjunction with the completion of the agreement, PPL disaggregated the 2024 revenues of the Rhode Island Regulated segment in a manner consistent with that of its other segments. This resulted in certain customer revenues for the Rhode Island Regulated segment, which were previously presented in the "Other" category, being presented in the "Residential", "Commercial" or "Industrial" customer classes beginning in the fourth quarter of 2024. Applying the previous methodology to 2025 revenues would result in $155 million of Residential, $89 million of Commercial and $13 million of Industrial for the Rhode Island Regulated segment being presented as "Other" for the three months ended March 31, 2025.

As discussed in Note 2, PPL segments its business by geographic location. Revenues from external customers for each segment are reconciled to revenues from contracts with customers in the footnotes to the tables above.

Contract receivables from customers are primarily included in "Accounts receivable - Customer", "Unbilled revenues", and "Other noncurrent assets" on the Balance Sheets.

The following table shows the accounts receivable and unbilled revenues balances that were impaired for the periods ended March 31.

	Three Months
	2025		2024
PPL (a)	$	25	$	42
PPL Electric (a)	7		28
LG&E	2		1
KU	1		1

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(a)2024 includes amounts impaired related to PPL Electric's billing issues.

Contract liabilities result from recording contractual billings in advance for customer attachments to the Registrants' infrastructure and payments received in excess of revenues earned to date. Advanced billings for customer attachments are generally recognized as revenue ratably over the quarterly billing period. Payments received in excess of revenues earned to date are recognized as revenue as services are delivered in subsequent periods. PPL's contract liabilities are not material at March 31, 2025 and 2024.

4. Earnings Per Share

(PPL)

Basic EPS is computed by dividing income available to PPL common shareowners by the weighted-average number of common shares outstanding during the applicable period. Diluted EPS is computed by dividing income available to PPL common shareowners by the weighted-average number of common shares outstanding, increased by the number of incremental shares that would be outstanding if potentially dilutive share-based payment awards were converted to common shares as calculated using the Two-Class Method or Treasury Stock Method. Incremental non-participating securities that have a dilutive impact are detailed in the table below. In 2025, these securities also included forward sales of PPL common stock issued through an ATM Program. See Note 7 for additional information on the ATM Program. The forward sale agreements are dilutive under the Treasury Stock Method to the extent the average stock price of PPL's common shares exceeds the forward sale price prescribed in the agreements.

Reconciliations of the amounts of income and shares of PPL common stock (in thousands) for the periods ended March 31 used in the EPS calculation are:

	Three Months
	2025		2024
Income (Numerator)
Net income attributable to PPL	$	414	$	307
Less amounts allocated to participating securities	1		—
Net income available to PPL common shareowners - Basic and Diluted	$	413	$	307
Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS	738,691		737,512
Add: Dilutive share-based payment awards (a)	2,709		1,308
Weighted-average shares - Diluted EPS	741,400		738,820
Basic and Diluted EPS
Net Income available to PPL common shareowners	$	0.56	$	0.42

(a)    The Treasury Stock Method was applied to non-participating share-based payment awards.

For the periods ended March 31, PPL issued common stock related to stock-based compensation plans as follows (in thousands):

	Three Months
	2025	2024
DRIP	200	—

For the periods ended March 31, the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive.

	Three Months
	2025	2024
Stock-based compensation awards	175	—
Forward sale agreements	2,033	—

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5. Income Taxes

Reconciliations of income tax expense (benefit) for the periods ended March 31 are as follows.

(PPL)
	Three Months
	2025		2024
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	108	$	81
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	20		17
Utility rate-making tax adjustments (a)	(10)		(5)
Amortization of excess deferred federal and state income taxes	(15)		(13)
Other	(1)		1
Total increase (decrease)	(6)		—
Total income tax expense (benefit)	$	102	$	81

(a)     Primarily consists of tax impacts of AFUDC equity and related depreciation across PPL's regulated utility subsidiaries and flow through tax impacts of Pennsylvania utility ratemaking. Flow through occurs when the regulator excludes deferred tax expense or benefit from recoverable costs when determining income tax expense.

(PPL Electric)
	Three Months
	2025		2024
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	50	$	41
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	15		14
Utility rate-making tax adjustments (a)	(6)		(4)
Amortization of excess deferred federal and state income taxes	(3)		(2)
Other	(2)		(1)
Total increase (decrease)	4		7
Total income tax expense (benefit)	$	54	$	48

(a)     Primarily consists of tax impacts of AFUDC equity and related depreciation and flow through tax impacts of Pennsylvania utility ratemaking. Flow through occurs when the regulator excludes deferred tax expense or benefit from recoverable costs when determining income tax expense.

(LG&E)
	Three Months
	2025		2024
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	27	$	25
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	5		4
Amortization of excess deferred federal and state income taxes	(4)		(3)
Other	(2)		(2)
Total increase (decrease)	(1)		(1)
Total income tax expense (benefit)	$	26	$	24

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(KU)
	Three Months
	2025		2024
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	33	$	28
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	6		5
Amortization of excess deferred federal and state income taxes	(5)		(5)
Other	(3)		(1)
Total increase (decrease)	(2)		(1)
Total income tax expense (benefit)	$	31	$	27

Other

IRS Revenue Procedure 2023-15 (PPL and LG&E)

On April 14, 2023, the IRS issued Revenue Procedure 2023-15, which provides a safe harbor method of accounting that taxpayers may use to determine whether expenses to repair, maintain, replace, or improve natural gas transmission and distribution property must be capitalized for tax purposes. PPL and LG&E are currently reviewing the revenue procedure to determine what impact the guidance may have on their financial statements.

6. Utility Rate Regulation

(All Registrants)

The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations.

	PPL				PPL Electric				LG&E				KU
	March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024
Current Regulatory Assets:
Rate adjustment mechanisms	$	74	$	95	$	—	$	—	$	—	$	—	$	—	$	—
Renewable energy certificates	16		14		—		—		—		—		—		—
Storm damage expense rider	46		68		46		68		—		—		—		—
Gas supply clause	23		3		—		—		23		3		—		—
Transmission service charge	35		44		—		27		—		—		—		—
Transmission formula rate	13		14		3		2		—		—		—		—
DSIC	9		8		9		8		—		—		—		—
TCJA customer refund and recovery	28		21		28		21		—		—		—		—
ISR deferral	10		22		—		—		—		—		—		—
Gas line tracker	5		4		—		—		5		4		—		—
Other	15		27		8		7		3		1		—		1
Total current regulatory assets	$	274	$	320	$	94	$	133	$	31	$	8	$	—	$	1

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	PPL				PPL Electric				LG&E				KU
	March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024
Noncurrent Regulatory Assets:
Defined benefit plans	$	962	$	967	$	472	$	473	$	223	$	226	$	147	$	149
Plant outage costs	29		30		—		—		7		7		22		23
Net metering	147		147		—		—		—		—		—		—
Environmental cost recovery	96		96		—		—		—		—		—		—
Storm costs	116		113		41		22		22		20		36		29
Unamortized loss on debt	20		20		3		3		9		9		6		6
Terminated interest rate swaps	51		53		—		—		30		31		21		22
Accumulated cost of removal of utility plant	165		173		165		173		—		—		—		—
AROs	278		280		—		—		76		75		202		205
Retired asset recovery	83		83		—		—		83		83		—		—
Gas line inspections	24		24		—		—		22		22		2		2
Advanced metering infrastructure	31		28		—		—		15		14		16		14
Other	47		46		4		2		4		4		8		8
Total noncurrent regulatory assets	$	2,049	$	2,060	$	685	$	673	$	491	$	491	$	460	$	458

	PPL				PPL Electric				LG&E				KU
	March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024
Current Regulatory Liabilities:
Generation supply charge	$	45	$	52	$	45	$	52	$	—	$	—	$	—	$	—
Environmental cost recovery	9		12		—		—		4		6		5		6
Rate adjustment mechanisms	63		71		—		—		—		—		—		—
Energy efficiency	24		25		—		—		—		—		—		—
DSM	24		17		—		—		10		7		14		10
Revenue decoupling mechanism	40		10		—		—		—		—		—		—
Deferred revenue	25		—		—		—		—		—		—		—
Derivative instruments	15		—		—		—		—		—		—		—
Other	29		36		9		5		2		1		7		6
Total current regulatory liabilities	$	274	$	223	$	54	$	57	$	16	$	14	$	26	$	22
Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	1,027	$	1,022	$	—	$	—	$	318	$	314	$	409	$	408
Net deferred taxes	1,875		1,899		729		739		434		439		491		498
Defined benefit plans	296		294		106		100		24		24		66		65
Terminated interest rate swaps	54		54		—		—		27		27		27		27
Energy efficiency	28		16		—		—		—		—		—		—
Other	58		50		—		—		11		11		14		11
Total noncurrent regulatory liabilities	$	3,338	$	3,335	$	835	$	839	$	814	$	815	$	1,007	$	1,009

Regulatory Matters

Rhode Island Activities (PPL)

FY 2026 Gas ISR Plan

On December 31, 2024, RIE filed its FY 2026 Gas ISR Plan with the RIPUC with a budget that included $187 million of capital investment spend and up to $15 million of additional contingency plan spend in connection with the PHMSA's potential

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enactment of regulations during FY 2026 that, if enacted, would significantly alter RIE's leak detection and repair obligations under federal regulations. The Plan also included proposed spending on curb-to-curb paving of $22 million. On March 28, 2025, the RIPUC approved a FY 2026 Gas ISR Plan of $165 million of which $147 million is for capital investment spend and $18 million spend for paving costs as operations and maintenance (O&M), plus a potential additional $15 million is available if the above-mentioned regulations are implemented by the PHMSA. On March 31, 2025, the RIPUC approved RIE's compliance filing for rates effective April 1, 2025.

FY 2026 Electric ISR Plan

On December 23, 2024, RIE filed its FY 2026 Electric ISR Plan with the RIPUC with a budget that included $248 million of capital investment spend (including $88 million for Advanced Metering Functionality (AMF)), $14 million of vegetation operation and maintenance (O&M) spend and $1 million of Other O&M spend. On March 28, 2025, the RIPUC approved a FY 2026 Electric ISR Plan of $219 million for capital investment spend (including $88 million for AMF), $14 million for vegetation management O&M spend, and $1 million for Other O&M spend. On March 31, 2025, the RIPUC approved RIE's compliance filing for rates effective April 1, 2025.

Kentucky Activities

(PPL, LG&E and KU)

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 are intended to serve anticipated load growth, including from potential data center demand in LG&E's or KU’s service territory. The proposals do 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 are currently expected to be $3.7 billion over the 2025 to 2031 period. The application includes proposals:

•to build a 645 MW natural gas combined cycle (NGCC) generation unit at KU's E.W. Brown station,

•to build a 645 MW NGCC generation unit at LG&E's Mill Creek station,

•to build a four-hour 400 MW (1,600 MWh total) battery energy storage system (BESS) at LG&E's Cane Run station, and

•to build a selective catalytic reduction (SCR) environmental facility at KU’s Ghent station 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 NGCC unit is in addition to a new NGCC unit currently under construction at that location.

The filing also notes projected in service dates for the projects, including the E.W. Brown NGCC unit in 2030, the Mill Creek NGCC unit in 2031, the Cane Run BESS in 2028 and the Ghent SCR facility in 2028.

LG&E and KU anticipate a ruling from the KPSC during the fourth quarter of 2025. LG&E and KU cannot predict the outcome of the proceedings.

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Kentucky January 2025 Storm

In January 2025, LG&E and KU experienced snow, ice, sleet and freezing rain in their service territories, resulting in substantial damage to certain of LG&E's and KU's assets. On January 31, 2025, LG&E and KU submitted a filing with the KPSC requesting regulatory asset treatment of the extraordinary operations and maintenance (O&M) expenses portion of the costs incurred related to the storm. On March 19, 2025, the KPSC issued an order authorizing LG&E and KU to establish, for accounting purposes only, regulatory assets based on the jurisdictional incremental costs of extraordinary O&M expense incurred by LG&E and KU as a result of the 2025 Winter Storm, with recovery amounts and amortization thereof to be determined in subsequent base rate proceedings. LG&E and KU cannot predict the outcome of this matter. As of March 31, 2025, LG&E and KU recorded regulatory assets related to the storm of $2 million and $7 million.

Mill Creek Unit 1 and Unit 2 Retired Asset Recovery (RAR) Application (PPL and LG&E)

In 2023, the KPSC issued an order approving, among other items, the requested retirement of Mill Creek Units 1 and 2.

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 rider. LG&E expects these costs to be approximately $125 million and proposed to begin application of the RAR rider with bills issued in May 2025. On February 24, 2025, the KPSC issued an order approving LG&E’s cost recovery for Mill Creek Unit 1 under the RAR rider.

Mill Creek Unit 2 is expected to be retired in 2027. LG&E anticipates the recovery of associated costs, including the remaining net book value, for Mill Creek Unit 2 through the RAR rider. The remaining net book value of Mill Creek Unit 2 was approximately $215 million at March 31, 2025 and LG&E is continuing to depreciate using the current approved rates through its retirement date in 2027. LG&E expects to reclassify the net book value remaining at retirement, which is expected to total approximately $161 million, to a regulatory asset to be amortized over a period of ten years in accordance with the RAR. There can be no assurance that these costs will be recovered in the amounts or at the time that LG&E expects.

Pennsylvania Activities (PPL and PPL Electric)

DSIC Petition

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%.

Federal Matters

FERC Transmission Rate Filing (PPL, LG&E and KU)

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

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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. Oral argument before the D.C. Circuit Court of Appeals occurred on January 21, 2025. 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 base rates increases, provided, however, that increases associated with the FERC's May 18, 2023 order are expected to be subject to future rate proceedings.

Recovery of Transmission Costs (PPL)

Until December 2022, RIE's transmission facilities were operated in combination with the transmission facilities of National Grid USA's New England affiliates, Massachusetts Electric Company (MECO) and New England Power (NEP), as a single integrated system with NEP designated as the combined operator. As of January 1, 2023, RIE operates its own transmission facilities. NE-ISO allocates RIE's costs among transmission customers in New England, in accordance with the ISO Open Access Transmission Tariff (ISO-NE OATT). According to the FERC orders, RIE is compensated for its actual monthly transmission costs, with its authorized maximum return on equity (ROE) of 11.74% on its transmission assets.

The ROE for transmission rates under the ISO-NE OATT is the subject of four complaints that are pending before the FERC. On October 16, 2014, the FERC issued an order on the first complaint, Opinion No. 531-A, resetting the base ROE applicable to transmission assets under the ISO-NE OATT from 11.14% to 10.57% effective as of October 16, 2014 and establishing a maximum ROE of 11.74%. On April 14, 2017, this order was vacated and remanded by the D. C. Circuit Court of Appeals (Court of Appeals). After the remand, the FERC issued an order on October 16, 2018 applicable to all four pending cases where it proposed a new base ROE methodology that, with subsequent input and support from the New England Transmission Owners (NETO), yielded a base ROE of 10.41%. Subsequent to the FERC's October 2018 order in the New England Transmission Owners cases, the FERC further refined its ROE methodology in another proceeding and has applied that refined methodology to transmission owners’ ROEs in other jurisdictions, and the NETOs filed further information in the New England matters to distinguish their case. Those determinations in other jurisdictions have recently been vacated and remanded back to the FERC for further proceedings by the D.C. Circuit Court of Appeals. The proceeding and the final base rate ROE determination in the New England matters remain open, pending a final order from the FERC. PPL cannot predict the outcome of this matter, and an estimate of the impact cannot be determined.

Other

Purchase of Receivables Program

(PPL and PPL Electric)

In accordance with RIPUC-approved and PAPUC-approved purchase of accounts receivable programs, RIE and PPL Electric purchase certain accounts receivable from alternative electricity suppliers at a discount, which reflects a provision for uncollectible accounts. The alternative electricity suppliers have no continuing involvement or interest in the purchased accounts receivable. Accounts receivable that are acquired are initially recorded at fair value on the date of acquisition.

During the three months ended March 31, 2025 and 2024, RIE purchased $87 million and $51 million of accounts receivable from alternative suppliers.

During the three months ended March 31, 2025 and 2024, PPL Electric purchased $466 million and $419 million of accounts receivable from alternative suppliers.

7. Financing Activities

Credit Arrangements and Short-term Debt

(All Registrants)

The Registrants maintain credit facilities to enhance liquidity, provide credit support and provide a backstop to commercial paper programs. For reporting purposes, on a consolidated basis, the credit facilities and commercial paper programs of PPL Electric, LG&E and KU are attributable to PPL. The amounts listed in the borrowed column below are recorded as "Short-term debt" on the Balance Sheets. The following credit facilities were in place at:

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	March 31, 2025									December 31, 2024
	Expiration Date	Capacity		Borrowed		Letters of Credit and Commercial Paper Issued (c)		Unused Capacity		Borrowed		Letters of Credit and Commercial Paper Issued (c)
PPL
PPL Capital Funding (a)
Syndicated Credit Facility (b)	Dec. 2029	$	1,500	$	—	$	427	$	1,073	$	—	$	138
Bilateral Credit Facility	Feb. 2026	100		—		—		100		—		—
Bilateral Credit Facility	Feb. 2026	100		—		55		45		—		15
Total PPL Capital Funding Credit Facilities		$	1,700	$	—	$	482	$	1,218	$	—	$	153
PPL Electric
Syndicated Credit Facility	Dec. 2029	$	750	$	—	$	56	$	694	$	—	$	1
Total PPL Electric Credit Facilities		$	750	$	—	$	56	$	694	$	—	$	1
LG&E
Syndicated Credit Facility	Dec. 2029	$	600	$	—	$	89	$	511	$	—	$	25
Total LG&E Credit Facilities		$	600	$	—	$	89	$	511	$	—	$	25
KU
Syndicated Credit Facility	Dec. 2029	$	600	$	—	$	209	$	391	$	—	$	140
Total KU Credit Facilities		$	600	$	—	$	209	$	391	$	—	$	140

(a)PPL Capital Funding's obligations are fully and unconditionally guaranteed by PPL.

(b)In January 2025, PPL Capital Funding increased the borrowing capacity of this facility from $1.25 billion to $1.50 billion. At March 31, 2025, the facility included a $250 million borrowing sublimit for RIE and a $1.25 billion sublimit for PPL Capital Funding. At December 31, 2024, the facility included a $250 million borrowing sublimit for RIE and a $1 billion borrowing sublimit for PPL Capital Funding. RIE’s borrowing sublimit is adjustable, at the borrowers’ option, from $0 to $600 million, with the remaining balance available under the facility allocated to PPL Capital Funding. At March 31, 2025, PPL Capital Funding had $427 million of commercial paper outstanding and RIE had no commercial paper outstanding. At December 31, 2024, PPL Capital Funding had $138 million of commercial paper outstanding and RIE had no commercial paper outstanding. RIE's obligations under the facility are not guaranteed by PPL.

(c)Commercial paper issued reflects the undiscounted face value of the issuance.

(PPL)

In January 2025, PPL Capital Funding amended its existing $1.25 billion syndicated credit facility to extend the termination date from December 6, 2028 to December 6, 2029 and to increase the borrowing capacity under the facility to $1.50 billion.

(PPL and PPL Electric)

In January 2025, PPL Electric amended its existing $650 million syndicated credit facility to extend the termination date from December 6, 2028 to December 6, 2029 and to increase the borrowing capacity under the facility to $750 million.

(PPL and LG&E)

In January 2025, LG&E amended its existing $500 million syndicated credit facility to extend the termination date from December 6, 2028 to December 6, 2029 and to increase the borrowing capacity under the facility to $600 million.

(PPL and KU)

In January 2025, KU amended its existing $400 million syndicated credit facility to extend the termination date from December 6, 2028 to December 6, 2029 and to increase the borrowing capacity under the facility to $600 million.

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(All Registrants)

The Registrants maintain commercial paper programs to provide an additional financing source to fund short-term liquidity needs. 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:

	March 31, 2025							December 31, 2024
	Weighted - Average Interest Rate	Capacity		Commercial Paper Issuances (c)		Unused Capacity		Weighted - Average Interest Rate	Commercial Paper Issuances (c)
PPL Capital Funding (a)(b)	4.71%	$	1,350	$	427	$	923	4.76%	$	138
RIE (b)		250		—		250			—
PPL Electric	4.68%	650		55		595			—
LG&E	4.67%	500		89		411		4.72%	25
KU	4.71%	400		209		191		4.71%	140
Total		$	3,150	$	780	$	2,370		$	303

(a)PPL Capital Funding's obligations are fully and unconditionally guaranteed by PPL.

(b)Issuances under the PPL Capital Funding and RIE commercial paper programs are supported by the PPL Capital Funding syndicated credit facility. At March 31, 2025, the borrowing sublimits were $250 million for RIE and $1.25 billion for PPL Capital Funding. At December 31, 2024, the borrowing sublimits were $250 million for RIE and $1 billion for PPL Capital Funding. PPL Capital Funding’s commercial paper program is also backed by a separate bilateral credit facility for $100 million.

(c)Commercial paper issued reflects the undiscounted face value of the issuance.

(PPL Electric, LG&E, and KU)

See Note 11 for discussion of intercompany borrowings.

(PPL)

Equity Securities

ATM Program

In February 2025, PPL entered into an equity distribution agreement, pursuant to which PPL may sell, from time to time, up to an aggregate of $2 billion of its common stock through an ATM Program, including an optional forward sales component. Each forward contract under the agreement must be settled within 24 months. The compensation paid to the selling agents by PPL may be up to 2% of the gross offering proceeds of the shares. During the three months ended March 31, 2025, PPL entered into a forward contract to sell approximately 2.0 million shares of its common stock at an initial forward price of $34.49 per share. The forward sale price may be adjusted based on changes in daily interest rates, for certain stock loan fees as determined by a third-party agent, and will be subject to predetermined reductions based on expected dividends. This forward contract must be settled on or before December 30, 2025. PPL may elect, at its discretion, to physically settle, net share settle or net cash settle the forward contracts. At March 31, 2025, PPL could have settled the forward sale contract with physical delivery of 2.0 million shares of common stock for proceeds of approximately $70 million. In April 2025, PPL entered into forward contracts to sell approximately 2.8 million additional shares at a blended initial forward price of approximately $35.22 per share. The forward contracts under the ATM program are classified as equity transactions.

Dividends

In February 2025, PPL declared a quarterly cash dividend on its common stock, payable April 1, 2025, of 27.25 cents per share (equivalent to $1.09 per annum).

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8. Acquisitions, Developments and Divestitures

Acquisitions (PPL)

Acquisition of Narragansett Electric

On May 25, 2022, PPL Rhode Island Holdings acquired 100% of the outstanding shares of common stock of Narragansett Electric from National Grid USA, a subsidiary of National Grid plc (the Acquisition). Following the closing of the Acquisition, Narragansett Electric provides services doing business under the name Rhode Island Energy (RIE). Please see Note 9 in PPL's 2024 Form 10-K for additional information concerning the Acquisition.

In connection with the Acquisition, National Grid USA Service Company, Inc., National Grid USA and Narragansett Electric entered into a transition services agreement (TSA), pursuant to which the National Grid entities agreed to provide certain transition services to Narragansett Electric to facilitate the transition of the operation of Narragansett Electric to PPL following the Acquisition, as agreed upon in the Narragansett share purchase agreement. The TSA was for an initial two-year term and was completed in the third quarter of 2024. TSA costs were $48 million during the three months ended March 31, 2024.

As a condition to the Acquisition, PPL made certain commitments to the Rhode Island Division of Public Utilities and Carriers and the Attorney General of the State of Rhode Island. See Note 9 in PPL's 2024 Form 10-K for a complete listing of those commitments. Included in these commitments is RIE's commitment to forgo potential recovery of any and all transition costs, which includes (1) the installation of certain information technology systems; (2) modification and enhancements to physical facilities in Rhode Island; and (3) costs related to severance payments, communications and branding changes, and other transition related costs. These costs, which are being expensed as incurred, were $17 million and $81 million for the three months ended March 31, 2025 and 2024.

9. Defined Benefits

(PPL)

Certain net periodic defined benefit costs are applied to accounts that are further distributed among capital, expense, regulatory assets and regulatory liabilities, including certain costs allocated to applicable subsidiaries for plans sponsored by PPL Services and LKE. Following are the net periodic defined benefit costs (credits) of the plans sponsored by PPL and its subsidiaries for the periods ended March 31:

	Pension Benefits
	Three Months
	2025		2024
PPL
Service cost	$	8	$	9
Interest cost	45		46
Expected return on plan assets	(72)		(75)
Amortization of:
Prior service cost	—		1
Actuarial loss	5		2
Net periodic defined benefit costs (credits)	$	(14)	$	(17)

	Other Postretirement Benefits
	Three Months
	2025		2024
PPL
Service cost	$	2	$	1
Interest cost	7		7
Expected return on plan assets	(8)		(7)
Amortization of:
Actuarial loss	(1)		(1)
Net periodic defined benefit costs (credits)	$	—	$	—

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(All Registrants)

The non-service cost components of net periodic defined benefit costs (credits) (interest cost, expected return on plan assets, amortization of prior service cost and amortization of actuarial gain and loss) are presented in "Other Income (Expense) - net" on the Statements of Income. See Note 12 for additional information.

10. Commitments and Contingencies

Legal Matters

(All Registrants)

PPL and its subsidiaries are involved in legal proceedings, claims and litigation in the ordinary course of business. PPL and its subsidiaries cannot predict the outcome of such matters, or whether such matters may result in material liabilities, unless otherwise noted.

Narragansett Electric Litigation (PPL)

Energy Efficiency Programs Investigation

Narragansett Electric, while under the ownership of National Grid, performed an internal investigation into conduct associated with its energy efficiency programs. On June 27, 2022, the RIPUC opened a new docket (RIPUC Docket No. 22-05-EE) to investigate RIE’s actions and the actions of employees of National Grid USA and affiliates during the time RIE was a National Grid USA affiliate being provided services by National Grid USA Service Company, Inc. relating to the manipulation of the reporting of invoices affecting the calculation of past energy efficiency shareholder incentives and the resulting impact on customers. The Rhode Island Attorney General and National Grid USA intervened in the docket and the Rhode Island Division of Public Utilities and Carriers (the Division) is an automatic party in the docket.

On February 21, 2025, the Division filed testimony confirming its initial testimony that $12 million is the appropriate amount to be refunded to the energy efficiency program. On March 4, 2025, a Settlement Agreement between RIE, the Division, and the Rhode Island Attorney General was filed with the RIPUC requiring refunds of $10 million. Of this amount, $2 million has already been refunded through the energy efficiency mechanism with the remaining $8 million to reduce the storm cost regulatory asset recorded on PPL's balance sheet. The settlement also included reimbursement of minor consulting fees and various other compliance actions. On March 5, 2025, the RIPUC approved the Settlement Agreement.

E.W. Brown Environmental Assessment (PPL and KU)

KU is undertaking extensive remedial measures at the E.W. Brown plant including closure of the former ash pond, implementation of a groundwater remedial action plan and performance of a corrective action plan including aquatic study of adjacent surface waters and risk assessment. The aquatic study and risk assessment are being undertaken pursuant to a 2017 Agreed Order with the Kentucky Energy and Environment Cabinet (KEEC). KU conducted sampling of Herrington Lake in 2017 and 2018. In June 2019, KU submitted to the KEEC the required aquatic study and risk assessment, conducted by an independent third-party consultant, finding that discharges from the E.W. Brown plant have not had any significant impact on Herrington Lake and that the water in the lake is safe for recreational use and meets safe drinking water standards. On May 31, 2021, the KEEC approved the report and released a response to public comments. On August 6, 2021, KU submitted a Supplemental Remedial Alternatives Analysis report to the KEEC that outlines proposed additional fish, water, and sediment testing. On February 18, 2022, the KEEC provided approval to KU to proceed with the proposed sampling, which commenced in the spring of 2022. On November 17, 2022, KU submitted a Supplemental Performance Monitoring Report to the KEEC finding that there are no significant unaddressed risks to human health or the environment at the plant. KU revised the Supplemental Performance Monitoring Report on June 8, 2023, in response to KEEC comments from April 24, 2023. On September 1, 2023, the KEEC requested KU to propose additional monitoring or remedial measures. KU submitted a revised Supplemental Performance Monitoring and Corrective Action Completion on December 28, 2023. In August 2024, KU submitted a proposed environmental covenant to the KEEC specifying certain site restrictions. Discussions between KU and the KEEC are ongoing, but KU cannot predict the outcome of this matter.

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(PPL, LG&E and KU)

EPA Deregulatory Initiative

On March 12, 2025, the EPA announced a plan to reconsider 31 environmental rules including the Section 111 performance standards and emissions limits for greenhouse gases, the endangerment finding for greenhouse gases, the Good Neighbor Plan, the Mercury and Air Toxics Standards, revisions to the fine particulate matter standard, the ELGs, and the CCRs Rule. Supplementing previous Executive Orders directing various regulatory changes, on April 9, 2025, President Trump issued an Executive Order and Presidential Memorandum directing review of existing rules, repeal of unlawful rules, and initiation of a zero-based budgeting process by which certain rules would automatically expire unless extended. While the administration may seek to implement some regulatory changes outside of the rulemaking process, changes to existing rules are generally expected to require formal rulemaking proceedings. Any final EPA actions repealing or revising current rules will likely result in legal challenges. PPL, LG&E, and KU are unable to predict future regulatory changes, if any, that may result from the EPA’s deregulatory plan or the outcome of any associated legal challenges. PPL, LG&E, and KU will closely monitor the ongoing EPA initiative and any related litigation for the impact to our business including planned capital expenditures to comply with the EPA rules.

Water/Waste

ELGs

In 2015, the EPA finalized ELGs for wastewater discharge permits for new and existing steam electricity generating facilities. These guidelines require deployment of additional control technologies providing physical, chemical and biological treatment and mandate operational changes including "zero discharge" requirements for certain wastewaters. The implementation date for individual generating stations was to be determined by the states on a case-by-case basis according to criteria provided by the EPA. In September 2017, the EPA issued a rule to postpone the compliance date for certain requirements. In October 2020, the EPA issued revisions to its best available technology standards for certain wastewaters and potential extensions to compliance dates (the Reconsideration Rule). On May 9, 2024, the EPA issued a final rule modifying the 2020 ELG revisions. The rule increases the stringency of previous control technology and zero discharge requirements, revises certain exemptions for generating units planned for retirement, and requires case-by-case limitations for legacy wastewaters based on the best professional judgment of the state regulators. Legal challenges to the final rule have been consolidated before the U.S. Court of Appeals for the Eighth Circuit. The final rule could potentially result in significant operational changes and additional controls for LG&E and KU plants, but in March 2025 the EPA announced its plan to reconsider the rule. The ELGs are expected to be implemented by the states or applicable permitting authorities in the course of their normal permitting activities. Certain costs are included in the Registrants' capital plans and expected to be recovered from customers through rate recovery mechanisms, but additional costs and recovery will depend on further regulatory developments at the state level.

CCRs

In 2015, the EPA issued a final rule governing management of CCRs, which include fly ash, bottom ash and sulfur dioxide scrubber wastes (2015 CCR Rule). The 2015 CCR Rule imposed extensive new requirements for certain CCR impoundments and landfills, including public notifications, location restrictions, design and operating standards, groundwater monitoring and corrective action requirements, and closure and post-closure care requirements, and specifies restrictions relating to the beneficial use of CCRs. In January 2022, the EPA issued several proposed regulatory determinations, facility notifications, and public announcements which indicate increased scrutiny by the EPA to determine the adequacy of measures taken by facility owners and operators to achieve closure of CCR surface impoundments and landfills. In particular, the agency indicated that it will focus on certain practices which it views as posing a threat of continuing groundwater contamination. On May 8, 2024, the EPA issued a final rule (2024 CCR Rule) establishing regulatory requirements for inactive surface impoundments at inactive electricity generation facilities (legacy impoundments). The 2024 CCR Rule also establishes identification, groundwater monitoring, corrective action, closure, and post-closure care requirements for all CCR management units, as defined in the rule, at regulated CCR facilities regardless of how or when the CCR was placed. The rule also requires LG&E and KU to complete applicability determinations, implement site security measures, initiate weekly inspections and monthly monitoring of the impoundment, create a website, and complete hazard assessments and reports for its legacy impoundments. Additionally, the rule could potentially subject CCR management units that have previously completed remedial action and closure and certain beneficial use projects to additional federal regulatory requirements. Legal challenges to the rule have been filed in the D.C. Circuit Court. In March 2025, the EPA announced its plan to update the rule.

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In connection with the 2015 CCR Rule, LG&E and KU recorded adjustments to existing AROs beginning in 2015. In connection with the 2024 CCR Rule, in the second quarter of 2024, LG&E and KU recognized ARO obligations related to preliminary risk assessments, facility evaluations, feasibility studies and sampling. See Note 15 for additional information. The results of those evaluations, as well as future guidance, regulatory determinations, rulemakings, implementation determinations and other developments could potentially require revisions to current LG&E and KU compliance plans including additional monitoring and remediation at surface impoundments and landfills, the cost of which could be material. PPL, LG&E and KU are unable to predict the outcome of the ongoing litigation, rulemaking, and regulatory determinations or potential impacts on current LG&E and KU compliance plans. PPL, LG&E and KU are currently finalizing or revising closure plans and schedules in accordance with applicable regulations and further material changes to AROs, current capital plans or operating costs may be required as estimates are refined based on closure developments, groundwater monitoring results, and regulatory or legal proceedings. Costs relating to this rule are expected to be subject to rate recovery.

LG&E and KU received KPSC approval for a compliance plan associated with the 2015 CCR Rule providing for the closure of impoundments at the Mill Creek, Trimble County, E.W. Brown, and Ghent stations, and construction of process water management facilities at those plants. In addition to the foregoing measures required for compliance with the federal CCR Rule, KU also received KPSC approval for its plans to close impoundments at the retired Green River, Pineville and Tyrone plants to comply with applicable state law. LG&E and KU have completed planned closure measures at most of the subject impoundments and have commenced post closure groundwater monitoring as required at those facilities. LG&E and KU generally expect to complete all impoundment closures within five years of commencement, although a longer period may be required to complete closure of some facilities. Associated costs are expected to be subject to rate recovery.

Superfund and Other Remediation

(All Registrants)

The Registrants are potentially responsible for investigating and remediating contamination under the federal Superfund program and similar state programs. Actions are under way at certain sites including former manufactured gas plants in Pennsylvania, Rhode Island and Kentucky previously owned or operated by, or currently owned by predecessors or affiliates of, PPL subsidiaries.

Depending on the outcome of investigations at identified sites where investigations have not begun or been completed, or developments at sites for which information is incomplete, additional costs of remediation could be incurred. PPL, PPL Electric, LG&E and KU lack sufficient information about such additional sites to estimate any potential liability or range of reasonably possible losses, if any, related to these sites. Such costs, however, are not currently expected to be significant.

The EPA is evaluating the risks associated with polycyclic aromatic hydrocarbons and naphthalene, chemical by-products of manufactured gas plant operations. As a result, individual states may establish stricter standards for water quality and soil cleanup, that could require several PPL subsidiaries to take more extensive assessment and remedial actions at former manufactured gas plants. The Registrants cannot reasonably estimate a range of possible losses, if any, related to these matters.

(PPL and PPL Electric)

PPL Electric is a potentially responsible party for a share of clean-up costs at certain sites. Cleanup actions have been or are being undertaken at these sites as requested by governmental agencies, the costs of which have not been and are not expected to be significant to PPL Electric.

As of March 31, 2025 and December 31, 2024, PPL Electric had a recorded liability of $8 million, representing its best estimate of the probable loss incurred to remediate these sites.

(PPL)

RIE is a potentially responsible party for a share of clean-up costs at certain sites including former manufactured gas plant facilities formerly owned by the Blackstone Valley Gas and Electric Company and the Rhode Island gas distribution assets of the New England Gas division of Southern Union Company and electric operations at certain RIE facilities. RIE is currently investigating and remediating, as necessary, those sites and certain other properties under agreements with governmental agencies, the costs of which have not been and are not expected to be significant to PPL.

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As of March 31, 2025 and December 31, 2024, RIE had a recorded liability of $99 million and $98 million, representing its best estimate of the remaining costs of RIE's environmental remediation activities. These undiscounted costs are expected to be incurred over approximately 30 years and generally to be subject to rate recovery. However, remediation costs for each site may be materially higher than estimated, depending on changing technologies and regulatory standards, selected end uses for each site, and actual environmental conditions encountered. RIE has recovered amounts from certain insurers and potentially responsible parties, and, where appropriate, may seek additional recovery from other insurers and potentially responsible parties, but it is uncertain whether, and to what extent, such efforts will be successful.

The RIPUC has approved two settlement agreements that provide for rate recovery of qualified remediation costs of certain contaminated sites located in Rhode Island and Massachusetts. Rate-recoverable contributions for electric operations of approximately $3 million are added annually to RIE's Environmental Response Fund, established with RIPUC approval in March 2000 to address such costs, along with interest and any recoveries from insurance carriers and other third parties. In addition, RIE recovers approximately $1 million annually for gas operations under a distribution adjustment charge in which the qualified remediation costs are amortized over 10 years. See Note 6 for additional information on RIE's recorded environmental regulatory assets and liabilities.

Regulatory Issues

(All Registrants)

See Note 6 for information on regulatory matters related to utility rate regulation.

Electricity - Reliability Standards

The NERC is responsible for establishing and enforcing mandatory reliability standards (Reliability Standards) regarding the bulk electric system in North America. The FERC oversees this process and independently enforces the Reliability Standards.

The Reliability Standards have the force and effect of law and apply to certain users of the bulk electric system, including electric utility companies, generators and marketers. Under the Federal Power Act, the FERC may assess civil penalties for certain violations.

PPL Electric, LG&E, KU and RIE monitor their compliance with the Reliability Standards and self-report or self-log potential violations of applicable reliability requirements whenever identified, and submit accompanying mitigation plans, as required. The resolution of a small number of potential violations is pending. Penalties incurred to date have not been significant. Any Regional Reliability Entity determination concerning the resolution of violations of the Reliability Standards remains subject to the approval of the NERC and the FERC.

In the course of implementing their programs to ensure compliance with the Reliability Standards by those PPL affiliates subject to the standards, certain other instances of potential non-compliance may be identified from time to time. The Registrants cannot predict the outcome of these matters, and an estimate or range of possible losses cannot be determined.

Gas - Security Directives (PPL and LG&E)

In May and July of 2021, the Department of Homeland Security’s (DHS) Transportation Security Administration released two security directives applicable to certain notified owners and operators of natural gas pipeline facilities (including local distribution companies) that the Transportation Security Administration has determined to be critical. The Transportation Security Administration has determined that LG&E is within the scope of the directive, while RIE has not been notified of this distinction. The first security directive required notified owners/operators to implement cybersecurity incident reporting to the DHS, designate a cybersecurity coordinator, and perform a gap assessment of current entity cybersecurity practices against certain voluntary Transportation Security Administration security guidelines and report relevant results and proposed mitigation to applicable DHS agencies. The second security directive, revised in July of 2024, requires refinement of the cybersecurity implementation plan and the cybersecurity assessment plan. LG&E does not believe the security directives have had or will have a significant impact on LG&E’s operations or financial condition.

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Other

Guarantees and Other Assurances

(All Registrants)

In the normal course of business, the Registrants enter into agreements that provide financial performance assurance to third parties on behalf of certain subsidiaries. Examples of such agreements include: guarantees, stand-by letters of credit issued by financial institutions and surety bonds issued by insurance companies. These agreements are entered into primarily to support or enhance the creditworthiness attributed to a subsidiary on a stand-alone basis or to facilitate the commercial activities in which these subsidiaries engage.

(PPL)

PPL fully and unconditionally guarantees all of the debt securities and loan obligations of PPL Capital Funding.

(All Registrants)

The table below details guarantees provided as of March 31, 2025. "Exposure" represents the estimated maximum potential amount of future payments that could be required to be made under the guarantee. The Registrants believe the probability of expected payment/performance under each of these guarantees is remote, except for the guarantees and indemnifications related to the sale of Safari Holdings, which PPL believes are reasonably possible but not probable of occurring. For reporting purposes, on a consolidated basis, the guarantees of PPL include the guarantees of its subsidiary Registrants.

	Exposure at March 31, 2025			Expiration Date
PPL
Indemnifications related to certain tax liabilities related to the sale of the U.K. utility business	£	50	(a)	2028
PPL guarantee of Safari payment obligations under certain sale/leaseback financing transactions related to the sale of Safari Holdings	$	97	(b)	2028
Indemnifications for losses suffered related to items not covered by Aspen Power's representation and warranty insurance associated with the sale of Safari Holdings	140		(c)	2028
LG&E and KU
LG&E and KU obligation of shortfall related to OVEC			(d)

(a)PPL WPD Limited entered into a Tax Deed dated June 9, 2021, in which it agreed to a tax indemnity regarding certain potential tax liabilities of the entities sold with respect to periods prior to the completion of the sale, subject to customary exclusions and limitations. Because National Grid Holdings One plc, the buyer, agreed to purchase indemnity insurance, the amount of the cap on the indemnity for these liabilities is £1, except with respect to certain surrenders of tax losses, for which the amount of the cap on the indemnity is £50 million.

(b)PPL guaranteed the payment obligations of Safari under certain sale/leaseback financing transactions executed by Safari. These guarantees will remain in place until Safari exercises its option to buy-out the projects under the sale/leaseback financings by the year 2028. Safari will indemnify PPL for any payments made by PPL or claims against PPL under the sale/leaseback transaction guarantees up to $25 million.

(c)Aspen Power has obtained representation and warranty insurance, therefore, PPL generally has no liability for its representations and warranties under the agreement except for losses suffered related to items not covered. Expiration of these indemnifications range from 18 months to 6 years from the date of the closing of the transaction, and PPL’s aggregate liability for these claims will not exceed $140 million, subject to certain adjustments.

(d)Pursuant to the OVEC power purchase contract, LG&E and KU are obligated to pay for their share of OVEC's excess debt service, post-retirement, and decommissioning costs, as well as any shortfall from amounts included within a demand charge designed and expected to cover these costs over the term of the contract. PPL's proportionate share of OVEC's outstanding debt was $77 million at March 31, 2025, consisting of LG&E's share of $53 million and KU's share of $24 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchase Commitments" in Note 12 in PPL's, LG&E's and KU's 2024 Form 10-K for additional information on the OVEC power purchase contract.

The Registrants provide other miscellaneous guarantees through contracts entered into in the normal course of business. These guarantees are primarily in the form of indemnification or warranties related to services or equipment and vary in duration. The amounts of these guarantees often are not explicitly stated, and the overall maximum amount of the obligation under such guarantees cannot be reasonably estimated. Historically, no significant payments have been made with respect to these types of guarantees and the probability of payment/performance under these guarantees is generally remote.

PPL, on behalf of itself and certain of its subsidiaries, maintains insurance that covers liability assumed under contract for bodily injury and property damage. The insurance provides maximum aggregate coverage of $231 million for non-wildfire liability losses and maximum aggregate coverage of $181 million for wildfire liability losses. This insurance may be applicable to obligations under certain of these contractual arrangements.

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11. Related Party Transactions

Support Costs (PPL Electric, LG&E and KU)

PPL Services and LKS provide the Registrants, their respective subsidiaries and each other with administrative, management and support services. For all services companies, the costs of directly assignable and attributable services are charged to the respective recipients as direct support costs. General costs that cannot be directly attributed to a specific entity are allocated and charged to the respective recipients as indirect support costs. PPL Services and LKS use a three-factor methodology that includes the applicable recipients' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. PPL Services and LKS charged the following amounts for the periods ended March 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable.

	Three Months
	2025		2024
PPL Electric from PPL Services	$	64	$	56
LG&E from LKS	30		29
LG&E from PPL Services	20		11
KU from LKS	38		38
KU from PPL Services	19		11

In addition to the charges for services noted above, LKS makes payments on behalf of LG&E and KU for fuel purchases and other costs for products or services provided by third parties. LG&E and KU also provide services to each other and to LKS. Billings between LG&E and KU relate to labor and overheads associated with union and hourly employees performing work for the other company, charges related to jointly-owned generating units and other miscellaneous charges. Tax settlements between PPL and LG&E and KU are reimbursed through LKS.

Intercompany Borrowings

(PPL Electric)

CEP Reserves maintains a $800 million revolving line of credit with a PPL Electric subsidiary. At March 31, 2025, CEP Reserves had an insignificant amount of borrowings outstanding. At December 31, 2024, CEP Reserves had borrowings outstanding of $222 million. The interest rates on borrowings are equal to an adjusted one-month SOFR plus a spread. Interest income is reflected in "Interest Income from Affiliate" on the PPL Electric Income Statements.

(LG&E and KU)

LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to the difference between LG&E's FERC borrowing limit and LG&E's commercial paper issued at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on SOFR. At March 31, 2025, LG&E's money pool unused capacity was $661 million. At March 31, 2025, LG&E had insignificant borrowings outstanding from KU and/or LKE. At December 31, 2024, LG&E had borrowings outstanding of $43 million from KU and/or LKE. These balances are reflected in "Notes payable to affiliates" on the LG&E Balance Sheets.

KU participates in an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to the difference between KU's FERC borrowing limit and KU's commercial paper issued at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on SOFR. At March 31, 2025, KU's money pool unused capacity was $433 million. At March 31, 2025, KU had borrowings outstanding from LG&E and/or LKE of $8 million. At December 31, 2024, KU had borrowings outstanding of $73 million from LG&E and/or LKE. These balances are reflected in "Notes payable to affiliates" on the KU Balance Sheets.

VEBA Funds Receivable

(PPL Electric)

In 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA, to be used to pay medical claims of active

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bargaining unit employees. In 2024, additional excess funds were removed from the PPL Bargaining Unit Retiree Health Plan VEBA and deposited into the existing subaccount within the VEBA to be used to pay medical claims of active bargaining unit employees. Based on PPL Electric's participation in PPL’s Other Postretirement Benefit plan, PPL Electric was allocated a portion of the excess funds from PPL Services. These funds have been recorded as an intercompany receivable on PPL Electric's Balance Sheets. The receivable balance decreases as PPL Electric pays incurred medical claims and is reimbursed by PPL Services. The intercompany receivable balance associated with these funds was $4 million at March 31, 2025, which was reflected in "Accounts receivable from affiliates" on PPL Electric's Balance Sheets. The intercompany receivable balance associated with these funds was $7 million at December 31, 2024, of which $4 million was reflected in "Accounts receivable from affiliates" and $3 million was reflected in "Other noncurrent assets" on PPL Electric's Balance Sheets.

12. Other Income (Expense) - net

(PPL)

The details of "Other Income (Expense) - net" for the periods ended March 31, were:

	Three Months
	2025		2024
Defined benefit plans - non-service credits (Note 9)	$	8	$	8
Interest income	5		9
AFUDC - equity component	16		9
Charitable contributions	(2)		(2)
Miscellaneous	1		(2)
Other Income (Expense) - net	$	28	$	22

(PPL Electric)

The details of "Other Income (Expense) - net" for the periods ended March 31, were:

	Three Months
	2025		2024
Defined benefit plans - non-service credits (Note 9)	$	3	$	4
Interest income	2		1
AFUDC - equity component	7		5
Charitable contributions	(1)		(1)
Other Income (Expense) - net	$	11	$	9

13. Fair Value Measurements

(All Registrants)

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (an exit price). A market approach (generally, data from market transactions), an income approach (generally, present value techniques and option pricing models) and/or a cost approach (generally, replacement cost) are used to measure the fair value of an asset or liability, as appropriate. These valuation approaches incorporate inputs such as observable, independent market data and/or unobservable data that management believes are predicated on the assumptions market participants would use to price an asset or liability. These inputs may incorporate, as applicable, certain risks such as nonperformance risk, which includes credit risk. The fair value of a group of financial assets and liabilities is measured on a net basis. See Note 1 in each Registrant's 2024 Form 10-K for information on the levels in the fair value hierarchy.

Recurring Fair Value Measurements

The assets and liabilities measured at fair value were:

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	March 31, 2025								December 31, 2024
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
PPL
Assets
Cash and cash equivalents	$	312	$	312	$	—	$	—	$	306	$	306	$	—	$	—
Restricted cash and cash equivalents (a)	28		28		—		—		33		33		—		—
Total Cash, Cash Equivalents and Restricted Cash (b)	340		340		—		—		339		339		—		—
Special use funds (a):
Money market fund	1		1		—		—		1		1		—		—
Commingled debt fund measured at NAV (c)	8		—		—		—		10		—		—		—
Commingled equity fund measured at NAV (c)	7		—		—		—		8		—		—		—
Total special use funds	16		1		—		—		19		1		—		—
Price risk management assets (d):
Gas contracts	22		—		22		—		9		—		4		5
Total assets	$	378	$	341	$	22	$	—	$	367	$	340	$	4	$	5
Liabilities
Price risk management liabilities (d):
Interest rate swaps	$	5	$	—	$	5	$	—	$	3	$	—	$	3	$	—
Gas contracts	6		—		—		6		13		—		10		3
Total price risk management liabilities	$	11	$	—	$	5	$	6	$	16	$	—	$	13	$	3
PPL Electric
Assets
Cash and cash equivalents	$	27	$	27	$	—	$	—	$	24	$	24	$	—	$	—
Total assets	$	27	$	27	$	—	$	—	$	24	$	24	$	—	$	—
LG&E
Assets
Cash and cash equivalents	$	10	$	10	$	—	$	—	$	8	$	8	$	—	$	—
Restricted cash and cash equivalents (a)	13		13		—		—		16		16		—		—
Total Cash, Cash Equivalents and Restricted Cash (b)	23		23		—		—		24		24		—		—
Total assets	$	23	$	23	$	—	$	—	$	24	$	24	$	—	$	—
Liabilities
Price risk management liabilities:
Interest rate swaps	$	5	$	—	$	5	$	—	$	3	$	—	$	3	$	—
Total price risk management liabilities	$	5	$	—	$	5	$	—	$	3	$	—	$	3	$	—
KU
Assets
Cash and cash equivalents	$	14	$	14	$	—	$	—	$	13	$	13	$	—	$	—
Restricted cash and cash equivalents (a)	13		13		—		—		16		16		—		—
Total Cash, Cash Equivalents and Restricted Cash (b)	27		27		—		—		29		29		—		—
Total assets	$	27	$	27	$	—	$	—	$	29	$	29	$	—	$	—

(a)Current portion is included in "Other current assets" and noncurrent portion is included in "Other noncurrent assets" on the Balance Sheets.

(b)Total Cash, Cash Equivalents and Restricted Cash provides a reconciliation of these items reported within the Balance Sheets to the sum shown on the Statements of Cash Flows.

(c)In accordance with accounting guidance, certain investments that are measured at fair value using net asset value per share (NAV), or its equivalent, have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the Balance Sheets.

(d)Current portion is included in "Other current assets" and "Other current liabilities" and noncurrent portion is included in "Other noncurrent assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets.

A reconciliation of net liabilities classified as Level 3 for the three months ended March 31 is as follows:

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	Gas Contracts
2025
Balance at beginning of period	$	(2)
Total unrealized gains (losses) recognized as Regulatory Assets/Regulatory Liabilities:	8
Settlements	—
Balance at end of period	$	6

Special Use Funds (PPL)

The special use funds are investments restricted for paying active union employee medical costs. In 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA to be used to pay medical claims of active bargaining unit employees. In 2024, additional excess funds were removed from the PPL Bargaining Unit Retiree Health Plan VEBA and deposited in the existing subaccount within the VEBA to be used to pay medical claims of active bargaining unit employees. The funds are invested primarily in commingled debt and equity funds measured at NAV and are classified as investments in equity securities. Changes in the fair value of the funds are recorded to the Statements of Income.

Price Risk Management Assets/Liabilities

Interest Rate Swaps (PPL, LG&E and KU)

To manage interest rate risk, PPL, LG&E and KU use interest rate contracts such as treasury locks, forward-starting swaps, floating-to-fixed swaps and fixed-to-floating swaps. An income approach is used to measure the fair value of these contracts, utilizing readily observable inputs, such as forward interest rates (e.g., SOFR and government security rates), as well as inputs that may not be observable, such as credit valuation adjustments. In certain cases, market information cannot practicably be obtained to value credit risk and therefore internal models are relied upon. These models use projected probabilities of default and estimated recovery rates based on historical observances. When the credit valuation adjustment is significant to the overall valuation, the contracts are classified as Level 3.

Gas Contracts (PPL)

To manage gas commodity price risk associated with natural gas purchases, RIE utilizes over-the-counter (OTC) gas swaps contracts with pricing inputs obtained from the New York Mercantile Exchange (NYMEX) and the Intercontinental Exchange (ICE), except in cases where the ICE publishes seasonal averages or where there were no transactions within the last seven days. RIE may utilize discounting based on quoted interest rate curves, including consideration of non-performance risk, and may include a liquidity reserve calculated based on bid/ask spread. Substantially all of these price curves are observable in the marketplace throughout at least 95% of the remaining contractual quantity, or they could be constructed from market observable curves with correlation coefficients of 95% or higher. These contracts are classified as Level 2.

RIE also utilizes gas option and purchase and capacity transactions, which are valued based on internally developed models. Industry-standard valuation techniques, such as the Black-Scholes pricing model, are used for valuing such instruments. For valuations that include both observable and unobservable inputs, if the unobservable input is determined to be significant to the overall inputs, the entire valuation is classified as Level 3. This includes derivative instruments valued using indicative price quotations whose contract tenure extends into unobservable periods. In instances where observable data is unavailable, consideration is given to the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility, and contract duration. Such instruments are classified as Level 3 as the model inputs generally are not observable. RIE considers non-performance risk and liquidity risk in the valuation of derivative instruments classified as Level 2 and Level 3.

The significant unobservable inputs used in the fair value measurement of the gas derivative instruments are implied volatility and gas forward curves. A relative change in commodity price at various locations underlying the open positions can result in significantly different fair value estimates.

Financial Instruments Not Recorded at Fair Value (All Registrants)

Long-term debt is classified as Level 2. The effect of third-party credit enhancements is not included in the fair value measurement. The carrying amounts of long-term debt on the Balance Sheets and their estimated fair values are set forth below.

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	March 31, 2025				December 31, 2024
	Carrying Amount (a)		Fair Value		Carrying Amount (a)		Fair Value
PPL	$	16,507	$	15,847	$	16,503	$	15,562
PPL Electric	5,214		4,931		5,214		4,862
LG&E	2,471		2,335		2,471		2,295
KU	3,066		2,804		3,066		2,750

(a)Amounts are net of debt issuance costs.

The carrying amounts of other current financial instruments (except for long-term debt due within one year) approximate their fair values because of their short-term nature.

14. Derivative Instruments and Hedging Activities

(All Registrants)

Risk Management Objectives

PPL has a risk management policy approved by the Board of Directors to manage market risk associated with commodities, interest rates on debt issuances (including price, liquidity and volumetric risk) and credit risk (including non-performance risk and payment default risk). The Risk Management Committee, comprised of senior management and chaired by the Vice President-Financial Strategy and Chief Risk Officer, oversees the risk management function. Key risk control activities designed to ensure compliance with the risk policy and detailed programs include, but are not limited to, credit review and approval, validation of transactions, verification of risk and transaction limits, value-at-risk analyses (VaR, a statistical model that attempts to estimate the value of potential loss over a given holding period under normal market conditions at a given confidence level) and the coordination and reporting of the Enterprise Risk Management program.

Market Risk

Market risk includes the potential loss that may be incurred as a result of price changes associated with a particular financial or commodity instrument as well as market liquidity and volumetric risks. Forward contracts, futures contracts, options, swaps and structured transactions are utilized as part of risk management strategies to minimize unanticipated fluctuations in earnings caused by changes in commodity prices and interest rates. Many of these contracts meet the definition of a derivative. All derivatives are recognized on the Balance Sheets at their fair value, unless NPNS is elected.

The following summarizes the market risks that affect PPL and its subsidiaries.

Interest Rate Risk

•PPL and its subsidiaries are exposed to interest rate risk associated with forecasted fixed-rate and existing floating-rate debt issuances. PPL and LG&E utilize over-the-counter interest rate swaps to limit exposure to market fluctuations on floating-rate debt. PPL, LG&E and KU utilize hedging instruments to limit exposure to fluctuations in benchmark interest rates, when appropriate, in connection with future debt issuance.

•PPL and its subsidiaries are exposed to interest rate risk associated with debt securities and derivatives held by defined benefit plans. This risk is significantly mitigated to the extent that the plans are sponsored at, or sponsored on behalf of, the regulated utilities due to the recovery methods in place.

Commodity Price Risk

PPL is exposed to commodity price risk through its subsidiaries as described below.

•PPL Electric is required to purchase electricity to fulfill its obligation as a PLR. Potential commodity price risk is mitigated through its PAPUC-approved cost recovery mechanism and full-requirement supply agreements to serve its PLR customers which transfer the risk to energy suppliers.

•LG&E's and KU's rates include certain mechanisms for fuel, fuel-related expenses and energy purchases. In addition, LG&E's rates include a mechanism for natural gas supply costs. These mechanisms generally provide for timely recovery of market price fluctuations associated with these costs.

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•RIE utilizes derivative instruments pursuant to its RIPUC-approved plan to manage commodity price risk associated with its natural gas purchases. RIE's commodity price risk management strategy is to reduce fluctuations in firm gas sales prices to its customers. RIE's costs associated with derivatives instruments are recoverable through its RIPUC-approved cost recovery mechanisms. RIE is also required to purchase electricity to fulfill its obligation to provide Last Resort Service (LRS). Potential commodity price risk is mitigated through its RIPUC-approved cost recovery mechanisms and full requirements service agreements to serve LRS customers, which transfer the risk to energy suppliers. Additionally, RIE is required to contract through long-term agreements for clean energy supply under the Rhode Island Renewable Energy Growth program and Long-term Clean Energy Standard. Potential commodity price risk is mitigated through its RIPUC-approved cost recovery mechanisms, which true-up cost differences between contract prices and market prices.

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 exposed to volumetric risk, which is significantly mitigated by regulatory mechanisms. RIE's electric and gas distribution rates both have a revenue decoupling mechanism, which allows for annual adjustments to RIE's delivery rates.

Equity Securities Price Risk

•PPL and its subsidiaries are exposed to equity securities price risk associated with the fair value of the defined benefit plans' assets. This risk is significantly mitigated due to the recovery methods in place.

•PPL is exposed to equity securities price risk from future stock sales and/or purchases.

Credit Risk

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.

Master Netting Arrangements (PPL, LG&E and KU)

Net derivative positions on the balance sheets are not offset against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements.

PPL, LG&E and KU had no obligation to return or post cash collateral under master netting arrangements at March 31, 2025 and December 31, 2024.

See "Offsetting Derivative Instruments" below for a summary of derivative positions presented in the balance sheets where a right of setoff exists under these arrangements.

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Interest Rate Risk

(All Registrants)

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.

Cash Flow Hedges (PPL)

Interest rate risks include exposure to adverse interest rate movements for outstanding variable rate debt and for future anticipated financings. Financial interest rate swap contracts that qualify as cash flow hedges may be entered into to hedge floating interest rate risk associated with both existing and anticipated debt issuances. PPL had no such contracts at March 31, 2025.

Cash flow hedges are discontinued if it is no longer probable that the original forecasted transaction will occur by the end of the originally specified time period and any amounts previously recorded in AOCI are reclassified into earnings once it is determined that the hedged transaction is not probable of occurring.

For the three months ended March 31, 2025 and 2024, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges.

At March 31, 2025, the amount of accumulated net unrecognized after-tax gains (losses) on qualifying derivatives expected to be reclassified into earnings during the next 12 months is insignificant. Amounts are reclassified as the hedged interest expense is recorded.

Economic Activity (PPL and LG&E)

LG&E enters into interest rate swap contracts that economically hedge interest payments. Because realized gains and losses from the swaps, including terminated swap contracts, are recoverable through regulated rates, any subsequent changes in fair value of these derivatives are included in regulatory assets or liabilities until they are realized as interest expense. Realized gains and losses are recognized in "Interest Expense" on the Statements of Income at the time the underlying hedged interest expense is recorded. At March 31, 2025, LG&E held contracts with a notional amount of $64 million that mature in 2033.

Commodity Price Risk (PPL)

Economic Activity

RIE enters into derivative contracts that economically hedge natural gas purchases. Realized gains and losses from the derivatives are recoverable through regulated rates, therefore subsequent changes in fair value are included in regulatory assets or liabilities until they are realized as purchased gas. Realized gains and losses are recognized in "Energy Purchases" on the Statements of Income upon settlement of the contracts. At March 31, 2025, RIE held contracts with notional volumes of 40 Bcf that range in maturity from 2025 through 2029.

Accounting and Reporting

(All Registrants)

All derivative instruments are recorded at fair value on the Balance Sheet as an asset or liability unless the NPNS is elected. NPNS contracts include certain full requirement purchase contracts and other physical purchase contracts. Changes in the fair value of derivatives not designated as NPNS are recognized in earnings unless specific hedge accounting criteria are met and designated as such, except for the changes in fair values of LG&E's interest rate swaps that are recognized as regulatory assets or regulatory liabilities. See Note 6 for amounts recorded in regulatory assets and regulatory liabilities at March 31, 2025 and December 31, 2024.

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See Note 1 in each Registrant's 2024 Form 10-K for additional information on accounting policies related to derivative instruments.

(PPL)

The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments.

	March 31, 2025				December 31, 2024
	Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management Assets/Liabilities (a):
Interest rate swaps	$	—	$	1	$	—	$	—
Gas contracts	16		1		7		10
Total current	16		2		7		10
Noncurrent:
Price Risk Management Assets/Liabilities (a):
Interest rate swaps	—		4		—		3
Gas contracts	6		5		2		3
Total noncurrent	6		9		2		6
Total derivatives	$	22	$	11	$	9	$	16

(a)Current portion is included in "Other current assets" and "Other current liabilities" and noncurrent portion is included in "Other noncurrent assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets. Excludes accrued interest, if applicable.

The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities for the period ended March 31, 2025.

		Three Months
Derivative Relationships	Location of Gain (Loss) Recognized in Income on Derivative	Gain (Loss) Reclassified from AOCI into Income
Cash Flow Hedges:
Interest rate swaps	Interest expense	$	(1)

Derivatives Not Designated as Hedging Instruments	Location of Gain (Loss) Recognized in Income on Derivative	Three Months
Gas contracts	Energy purchases	$	(5)
	Total	$	(5)
Derivatives Not Designated as Hedging Instruments	Location of Gain (Loss) Recognized as Regulatory Liabilities/Assets	Three Months
Interest rate swaps	Regulatory assets - noncurrent	$	(1)
Gas contracts	Regulatory liabilities - current	18
	Regulatory liabilities - noncurrent	1
	Total	$	18

The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities for the period ended March 31, 2024.

	Three Months			Three Months
Derivative Relationships	Derivative Gain (Loss) Recognized in OCI		Location of Gain (Loss) Recognized in Income on Derivative	Gain (Loss) Reclassified from AOCI into Income
Cash Flow Hedges:
Interest rate swaps	$	—	Interest expense	$	(1)

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Derivatives Not Designated as Hedging Instruments	Location of Gain (Loss) Recognized in Income on Derivative	Three Months
Gas contracts	Energy purchases	$	(16)
	Total	$	(16)
Derivatives Not Designated as Hedging Instruments	Location of Gain (Loss) Recognized as Regulatory Liabilities/Assets	Three Months
Interest rate swaps	Regulatory assets - noncurrent	$	2
Gas contracts	Regulatory assets - current	22
	Regulatory assets - noncurrent	4
	Total	$	28

The following table presents the effect of cash flow hedge activity on the Statement of Income for the period ended March 31, 2025.

	Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships
	Three Months
	Interest Expense
Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded	$	190
The effects of cash flow hedges:
Gain (Loss) on cash flow hedging relationships:
Interest rate swaps:
Amount of gain (loss) reclassified from AOCI to income	(1)

The following table presents the effect of cash flow hedge activity on the Statement of Income for the period ended March 31, 2024.

	Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships
	Three Months
	Interest Expense
Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded	$	179
The effects of cash flow hedges:
Gain (Loss) on cash flow hedging relationships:
Interest rate swaps:
Amount of gain (loss) reclassified from AOCI to income	(1)

(LG&E)

The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments.

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	March 31, 2025				December 31, 2024
	Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management Assets/Liabilities:
Interest rate swaps	$	—	$	1	$	—	$	—
Total current	—		1		—		—
Noncurrent:
Price Risk Management Assets/Liabilities:
Interest rate swaps	—		4		—		3
Total noncurrent	—		4		—		3
Total derivatives	$	—	$	5	$	—	$	3

The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets for the period ended March 31, 2025.

	Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months
Interest rate swaps	Interest expense	$	—
	Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months
Interest rate swaps	Regulatory assets - noncurrent	$	(1)

The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets for the period ended March 31, 2024. 

	Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months
Interest rate swaps	Interest expense	$	—
	Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months
Interest rate swaps	Regulatory assets - noncurrent	$	2

(PPL, LG&E and KU)

Offsetting Derivative Instruments

PPL, LG&E and KU or certain of their subsidiaries have master netting arrangements in place and also enter into agreements pursuant to which they purchase or sell certain energy and other products. Under the agreements, upon termination of the agreement as a result of a default or other termination event, the non-defaulting party typically would have a right to set off amounts owed under the agreement against any other obligations arising between the two parties (whether under the agreement or not), whether matured or contingent and irrespective of the currency, place of payment or place of booking of the obligation.

PPL, LG&E and KU have elected not to offset derivative assets and liabilities and not to offset net derivative positions against the right to reclaim cash collateral pledged (an asset) or the obligation to return cash collateral received (a liability) under derivatives agreements. The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged.

	Assets								Liabilities
			Eligible for Offset								Eligible for Offset
	Gross		Derivative Instruments		Cash Collateral Received		Net		Gross		Derivative Instruments		Cash Collateral Pledged		Net
March 31, 2025
Derivatives
PPL	$	22	$	1	$	—	$	21	$	11	$	1	$	—	$	10
LG&E	—		—		—		—		5		—		—		5

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	Assets								Liabilities
			Eligible for Offset								Eligible for Offset
	Gross		Derivative Instruments		Cash Collateral Received		Net		Gross		Derivative Instruments		Cash Collateral Pledged		Net
December 31, 2024
Derivatives
PPL	$	9	$	5	$	—	$	4	$	16	$	5	$	—	$	11
LG&E	—		—		—		—		3		—		—		3

Credit Risk-Related Contingent Features

Certain derivative contracts contain credit risk-related contingent features which, when in a net liability position, would permit the counterparties to require the transfer of additional collateral upon a decrease in the credit ratings of PPL, LG&E and KU or certain of their subsidiaries. Most of these features would require the transfer of additional collateral or permit the counterparty to terminate the contract if the applicable credit rating were to fall below investment grade. Some of these features also would allow the counterparty to require additional collateral upon each downgrade in credit rating at levels that remain above investment grade. In either case, if the applicable credit rating were to fall below investment grade, and assuming no assignment to an investment grade affiliate were allowed, most of these credit contingent features require either immediate payment of the net liability as a termination payment or immediate and ongoing full collateralization on derivative instruments in net liability positions.

Additionally, certain derivative contracts contain credit risk-related contingent features that require adequate assurance of performance be provided if the other party has reasonable concerns regarding the performance of PPL's, LG&E's and KU's obligations under the contracts. A counterparty demanding adequate assurance could require a transfer of additional collateral or other security, including letters of credit, cash and guarantees from a creditworthy entity. This would typically involve negotiations among the parties. However, amounts disclosed below represent assumed immediate payment or immediate and ongoing full collateralization for derivative instruments in net liability positions with "adequate assurance" features.

(PPL)

At March 31, 2025, there were no derivative contracts in a net liability position that contain credit risk-related contingent features. At March 31, 2025, there were no additional collateral requirements in the event of a credit downgrade below investment grade.

15. Asset Retirement Obligations

(PPL, LG&E and KU)

PPL's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 10 for information on the CCR rule. LG&E and RIE also have AROs related to natural gas mains and wells. LG&E's and KU's transmission and distribution lines largely operate under perpetual property easement agreements, which do not generally require restoration upon removal of the property. Therefore, no material AROs are recorded for transmission and distribution assets. For LG&E, KU and RIE, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal.

The changes in the carrying amounts of AROs were as follows.

	PPL		LG&E		KU
Balance at December 31, 2024	$	157	$	84	$	64
Accretion	2		1		1
Changes in estimated timing or cost	(1)		—		(1)
Obligations settled	(4)		(1)		(3)
Balance at March 31, 2025	$	154	$	84	$	61

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16. Accumulated Other Comprehensive Income (Loss)

(PPL)

The after-tax changes in AOCI by component for the periods ended March 31 were as follows.

	Unrealized gains (losses)  on qualifying derivatives				Defined benefit plans
			Equity investees' AOCI		Prior service costs		Actuarial gain (loss)		Total
PPL
December 31, 2024	$	9	$	4	$	(3)	$	(194)	$	(184)
Reclassifications from AOCI	1		—		—		(1)		—
Net OCI during the period	1		—		—		(1)		—
March 31, 2025	$	10	$	4	$	(3)	$	(195)	$	(184)
December 31, 2023	$	6	$	3	$	(4)	$	(168)	$	(163)
Amounts arising during the period	—		1		—		—		1
Reclassifications from AOCI	1		—		—		—		1
Net OCI during the period	1		1		—		—		2
March 31, 2024	$	7	$	4	$	(4)	$	(168)	$	(161)

The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the periods ended March 31.

	Three Months				Affected Line Item on the
Details about AOCI	2025		2024		Statements of Income
Qualifying derivatives
Interest rate swaps	$	(1)	$	(1)	Interest Expense
Total Pre-tax	(1)		(1)
Income Taxes	—		—
Total After-tax	(1)		(1)
Defined benefit plans
Net actuarial loss (a)	1		—
Total Pre-tax	1		—
Income Taxes	—		—
Total After-tax	1		—
Total reclassifications during the period	$	—	$	(1)

(a)    These AOCI components are included in the computation of net periodic defined benefit cost. See Note 9 for additional information.

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17. New Accounting Guidance Pending Adoption

(All Registrants)

Improvements to Income Tax Disclosures

In December 2023, the FASB issued ASU 2023-09 which requires public business entities to provide additional income tax disclosures, including a disaggregated rate reconciliation as well as information on income taxes paid.

For public business entities, this guidance will be applied on a prospective basis. Retrospective application is permitted. This guidance will be effective for annual periods beginning after December 15, 2024. Early adoption is permitted for annual financial statements that have not yet been issued or made available for issuance.

The Registrants are currently assessing the impact of adopting this guidance.

Disaggregation of Income Statement Expenses

In November 2024, the FASB issued guidance which requires public business entities to provide in the notes to financial statements specified information about certain costs and expenses. This includes the disclosure of amounts of (a) purchases of inventory, (b) employee compensation, (c) depreciation, (d) intangible asset amortization, and (e) depreciation, depletion, and amortization recognized as part of oil and gas-producing activities included in each relevant income statement expense caption. A relevant expense caption is an expense caption included on the face of the income statement within continuing operations that contains any of the specified expense categories (a)-(e). A qualitative description of the amounts remaining in relevant expense captions that are not separately disaggregated must also be disclosed. Additionally, public business entities must disclose the total amount of selling expenses and, in annual reporting periods, the entity’s definition of selling expenses.

For public business entities, this guidance will be applied on a prospective basis. Retrospective application is permitted. This guidance will be effective for annual periods beginning after December 15, 2026, and interim periods beginning after December 15, 2027. Early adoption is permitted.

The Registrants are currently assessing the impact of adopting this guidance.

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Item 2. Combined Management's Discussion and Analysis of Financial Condition and

Results of Operations

(All Registrants)

This "Item 2. 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' Condensed Consolidated Financial Statements and the accompanying Notes and with the Registrants' 2024 Form 10-K. 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 the three months ended March 31, 2025 with the same period in 2024. The 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 rating agency actions.

•"Financial Condition - Risk Management" provides an explanation of the Registrants' risk management programs relating to market and credit risk.

Overview

Introduction

(PPL)

PPL, headquartered in Allentown, Pennsylvania, is a utility holding company. PPL, through its regulated utility subsidiaries, delivers electricity to customers in Pennsylvania, Kentucky, Virginia, and Rhode Island; delivers natural gas to customers in Kentucky and Rhode Island; and generates electricity from power plants in Kentucky.

PPL's principal subsidiaries are shown below (* denotes a Registrant).

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			PPL Corporation*
					PPL Capital Funding Provides financing for the operations of PPL and certain subsidiaries
PPL Electric* Engages in the regulated transmission and distribution of electricity in Pennsylvania			LKE A holding company that owns regulated utility operations through its subsidiaries, LG&E and KU		RIE Engages in the regulated transmission, distribution and sale of electricity and regulated distribution and sale of natural gas in Rhode Island
	LG&E* Engages in the regulated generation, transmission, distribution and sale of electricity and regulated distribution and sale of natural gas in Kentucky			KU* Engages in the regulated generation, transmission, distribution and sale of electricity, primarily in Kentucky
Pennsylvania Regulated Segment		Kentucky Regulated Segment			Rhode Island Regulated Segment

In addition to PPL, the other Registrants included in this filing are as follows.

(PPL Electric)

PPL Electric, headquartered in Allentown, Pennsylvania, is a wholly-owned subsidiary of PPL and a regulated public utility that is an electricity transmission and distribution service provider in eastern and central Pennsylvania. PPL Electric is subject to regulation as a public utility by the PAPUC, and certain of its transmission activities are subject to the jurisdiction of the FERC under the Federal Power Act. PPL Electric delivers electricity in its Pennsylvania service area and provides electricity supply to retail customers in that area as a PLR under the Customer Choice Act. PPL Electric was organized in 1920 as Pennsylvania Power & Light Company.

(LG&E)

LG&E, headquartered in Louisville, Kentucky, is a wholly-owned subsidiary of LKE and a regulated utility engaged in the generation, transmission, distribution and sale of electricity and distribution and sale of natural gas in Kentucky. LG&E is subject to regulation as a public utility by the KPSC, and certain of its transmission activities are subject to the jurisdiction of the FERC under the Federal Power Act.

(KU)

KU, headquartered in Lexington, Kentucky, is a wholly-owned subsidiary of LKE and a regulated utility engaged in the generation, transmission, distribution and sale of electricity in Kentucky and Virginia. KU is subject to regulation as a public utility by the KPSC and the VSCC, and certain of its transmission and wholesale power activities are subject to the jurisdiction of the FERC under the Federal Power Act. KU serves its Kentucky customers under the KU name and its Virginia customers under the Old Dominion Power name.

Segment Information (PPL)

PPL is organized into three reportable segments as depicted in the chart above: Kentucky Regulated, which primarily represents the results of LG&E and KU, Pennsylvania Regulated, which primarily represents the results of PPL Electric, and Rhode Island Regulated, which primarily represents the results of RIE. "Corporate and Other" primarily consists of corporate level financing

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costs, certain unallocated costs and certain non-recoverable costs incurred in conjunction with the acquisition of Rhode Island Energy.

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

Regulatory Requirements

(All Registrants)

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

(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 6, 10 and 15 to the Financial Statements for a discussion of these significant environmental matters. These and other environmental requirements led PPL, LG&E and KU to retire approximately 1,500 MW of coal-fired generating plants in Kentucky since 2010. As part of the long-term generation planning process, LG&E and KU evaluate a range of factors including the impact of potential stricter environmental regulations, fuel price scenarios, the cost of replacement generation, continued operations and major maintenance costs and the risk of major equipment failures in determining when to retire generation assets.

As a result of environmental requirements and aging infrastructure, LG&E has sought and obtained approval to retire two older coal-fired units at the Mill Creek Plant. Mill Creek Unit 1, with 300 MW of capacity, was retired in 2024. Mill Creek Unit 2, with 297 MW of capacity, is expected to be retired in 2027, subject to certain conditions.

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 rider. On February 24, 2025, the KPSC issued an order approving LG&E’s cost recovery for Mill Creek Unit 1 under the RAR rider. See Note 6 to the Financial Statements for additional information on the Mill Creek Unit 1 RAR rider application.

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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 are intended to serve anticipated load growth, including from potential data center demand in LG&E's or KU’s service territory. The proposals do 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 are currently expected to be $3.7 billion over the 2025 to 2031 period. Projected capital expenditures related to these proposals for the years 2025 through 2027 were included in PPL's, LG&E's and KU's projections in “Management Discussion and Analysis – Financial Condition - Liquidity and Capital Resources - Forecasted Uses of Cash – Capital Expenditures” in the 2024 Form 10-K. The application includes proposals:

•to build a 645 MW natural gas combined cycle (NGCC) generation unit at KU's E.W. Brown station,

•to build a 645 MW NGCC generation unit at LG&E's Mill Creek station,

•to build a four-hour 400 MW (1,600 MWh total) battery energy storage system (BESS) at LG&E's Cane Run station, and

•to build a selective catalytic reduction (SCR) environmental facility at KU’s Ghent station 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 NGCC unit is in addition to a new NGCC unit currently under construction at that location.

The filing also notes projected in service dates for the projects, including the E.W. Brown NGCC unit in 2030, the Mill Creek NGCC unit in 2031, the Cane Run BESS in 2028 and the Ghent SCR facility in 2028.

LG&E and KU anticipate a ruling from the KPSC during the fourth quarter of 2025. LG&E and KU cannot predict the outcome of the proceedings.

2025 Kentucky Rate Cases

On April 4, 2025, LG&E and KU filed with the KPSC respective Notices of Intent to file, on or after May 30, 2025, applications for a general adjustment in their electric and gas rates following a four-year stay out provision included in the base rate cases that became effective July 1, 2021. These applications will be supported by a fully forecasted test period ending December 31, 2026. The applications will request an adjustment of their electric and gas rates and charges, request other changes to their electric and gas tariffs, including terms and conditions of service, and address certain regulatory and accounting treatments. In addition, pursuant to prior orders of the KPSC, LG&E and KU are required to include an assessment of a potential legal merger of LG&E and KU in each rate case proceeding. If LG&E and KU conclude a legal merger may be appropriate, LG&E and KU would formally seek regulatory approval for a merger in a future proceeding. There is no assurance that LG&E and KU would receive regulatory approval for a potential merger.

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

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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. Oral argument before the D.C. Circuit Court of Appeals occurred on January 21, 2025. 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 base rates increases, provided, however, that increases associated with the FERC's May 18, 2023 order are expected to be subject to future rate proceedings.

(PPL)

FY 2026 Gas ISR Plan

On December 31, 2024, RIE filed its FY 2026 Gas ISR Plan with the RIPUC with a budget that included $187 million of capital investment spend and up to $15 million of additional contingency plan spend in connection with the PHMSA's potential enactment of regulations during FY 2026 that, if enacted, would significantly alter RIE's leak detection and repair obligations under federal regulations. The Plan also included proposed spending on curb-to-curb paving of $22 million. On March 28, 2025, the RIPUC approved a FY 2026 Gas ISR Plan of $165 million of which $147 million is for capital investment spend and $18 million spend for paving costs as operations and maintenance (O&M), plus a potential additional $15 million is available if the above-mentioned regulations are implemented by the PHMSA. On March 31, 2025, the RIPUC approved RIE's compliance filing for rates effective April 1, 2025.

FY 2026 Electric ISR Plan

On December 23, 2024, RIE filed its FY 2026 Electric ISR Plan with the RIPUC with a budget that included $248 million of capital investment spend (including $88 million for Advanced Metering Functionality (AMF)), $14 million of vegetation operation and maintenance (O&M) spend and $1 million of Other O&M spend. On March 28, 2025, the RIPUC approved a FY 2026 Electric ISR Plan of $219 million for capital investment spend (including $88 million for AMF), $14 million for vegetation management O&M spend, and $1 million for Other O&M spend. On March 31, 2025, the RIPUC approved RIE's compliance filing for rates effective April 1, 2025.

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 the three months ended March 31, 2025 with the same period in 2024. The "Segment Earnings" discussion provides 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.

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(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 the three months ended March 31, 2025 with the same period in 2024.

(All Registrants)

The results for interim periods can be disproportionately influenced by numerous factors and developments and by seasonal variations. As such, the results of operations for interim periods do not necessarily indicate results or trends for the year or future periods.

PPL: Statement of Income Analysis and Segment Earnings

Statement of Income Analysis

Net income for the periods ended March 31 includes the following results:

	Three Months
	2025		2024		$ Change
Operating Revenues	$	2,504	$	2,304	$	200
Operating Expenses
Operation
Fuel	234		209		25
Energy purchases	559		520		39
Other operation and maintenance	598		626		(28)
Depreciation	322		316		6
Taxes, other than income	113		88		25
Total Operating Expenses	1,826		1,759		67
Operating Income	678		545		133
Other Income (Expense) - net	28		22		6
Interest Expense	190		179		11
Income Before Income Taxes	516		388		128
Income Taxes	102		81		21
Net Income	$	414	$	307	$	107

Operating Revenues

The increase (decrease) in operating revenues was due to:

	Three Months
PPL Electric distribution price (a)	$	(6)
PPL Electric distribution volume (b)	22
PPL Electric PLR (c)	18
PPL Electric transmission formula rate (d)	15
LG&E volumes (b)	10
LG&E fuel and other energy purchases (e)	25
KU volumes (b)	18
KU fuel and other energy purchases (f)	8
KU off-system sales (g)	9
RIE energy purchases and other recoveries (h)	28
RIE net metering presentation (i)	41
RIE capital investments	10
Other	2
Total	$	200

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(a)The decrease was primarily due to reconcilable cost recovery mechanisms approved by the PAPUC.

(b)The increases were primarily due to weather, along with other higher usage in 2025 at PPL Electric.

(c)The increase was primarily the result of higher customer volumes due to weather and other higher usage, partially offset by lower energy prices and fewer PLR customers.

(d)The increase was primarily due to returns on additional transmission capital investments and return of depreciation, partially offset by O&M expenses.

(e)The increase was primarily due to higher recoveries of energy purchases.

(f)The increase was primarily due to higher recoveries of fuel expenses.

(g)The increase was primarily due to higher volumes.

(h)The increase was primarily due to higher transmission costs, higher recoveries of gas related maintenance expenses and higher gross earnings taxes, partially offset by lower recoveries of commodity costs.

(i)In conjunction with the completion of the transition services agreement associated with the RIE acquisition, PPL conformed the presentation of RIE’s net metering charges beginning in the fourth quarter of 2024 with the presentation of the other operating companies, resulting in an increase in Operating Revenues and a corresponding increase in Energy purchases. See Note 3 to the Financial Statements for additional information.

Fuel

Fuel increased $25 million for the three months ended March 31, 2025 compared with 2024, primarily due to an increase in volumes due to weather.

Energy Purchases

The increase (decrease) in energy purchases was due to:

	Three Months
PPL Electric PLR volumes	$	25
PPL Electric PLR prices	(15)
LG&E volumes	12
RIE commodity costs	(35)
RIE net metering presentation (a)	41
Other	11
Total	$	39

(a)In conjunction with the completion of the transition services agreement associated with the RIE acquisition, PPL conformed the presentation of RIE’s net metering charges beginning in the fourth quarter of 2024 with the presentation of the other operating companies, resulting in an increase in Operating Revenues and a corresponding increase in Energy purchases. See Note 3 to the Financial Statements for additional information.

Other Operation and Maintenance

The increase (decrease) in other operation and maintenance was due to:

	Three Months
PPL Electric bad debt expenses	$	(21)
RIE gas maintenance expenses	15
RIE transmission expenses	24
RIE bad debt expenses	6
Transition costs associated with RIE	(64)
Other	12
Total	$	(28)

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Taxes, Other Than Income

The increase (decrease) in taxes, other than income was due to:

	Three Months
State gross earnings and gross receipts tax (a)	$	26
Other	(1)
Total	$	25

(a)The increase was primarily due to the RIE Gross Earnings Tax Holiday Credit that took place in 2024.

Interest Expense

The increase (decrease) in interest expense was due to:

	Three Months
Long-term debt (a)	$	15
Other	(4)
Total	$	11

(a)    The increase was primarily due to increased borrowings.

Income Taxes

The increase (decrease) in income taxes was due to:

	Three Months
Change in pre-tax income	$	30
Utility rate-making tax adjustments (a)	(5)
Other	(4)
Total	$	21

(a)    Primarily consists of tax impacts of AFUDC equity and related depreciation across PPL utilities and flow through tax impacts. Flow through occurs when the regulator excludes deferred tax expense or benefit from recoverable costs when determining income tax expense.    

See Note 5 to the Financial Statements for additional information on income taxes.

Segment Earnings

PPL's Net Income (Loss) by reportable segment for the periods ended March 31 were as follows:

	Three Months
	2025		2024		$ Change
Kentucky Regulated	$	223	$	190	$	33
Pennsylvania Regulated	184		149		35
Rhode Island Regulated	70		64		6
Corporate and Other (a)	(63)		(96)		33
Net Income (Loss)	$	414	$	307	$	107

(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.

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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.

• Significant losses on early extinguishment of debt.

• 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 for the periods ended March 31 were as follows:

	Three Months
	2025		2024		$ Change
Kentucky Regulated	$	225	$	191	$	34
Pennsylvania Regulated	185		161		24
Rhode Island Regulated	72		78		(6)
Corporate and Other	(38)		(28)		(10)
Earnings from Ongoing Operations	$	444	$	402	$	42

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 primarily consists of the regulated electricity generation, transmission and distribution operations conducted by LG&E and KU, as well as LG&E's regulated transmission, distribution and sale of natural gas.

Net Income and Earnings from Ongoing Operations for the periods ended March 31 include the following results:

	Three Months
	2025		2024		$ Change
Operating Revenues	$	1,059	$	984	$	75
Fuel	234		209		25
Energy purchases	96		77		19
Other operation and maintenance	200		202		(2)
Depreciation	176		176		—
Taxes, other than income	25		25		—
Total Operating Expenses	731		689		42
Other Income (Expense) - net	8		3		5
Interest Expense	60		60		—
Income Taxes	53		48		5
Net Income	223		190		33
Less: Special Items	(2)		(1)		(1)
Earnings from Ongoing Operations	$	225	$	191	$	34

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 during the periods ended March 31.

	Income Statement Line Item	Three Months
		2025		2024
Strategic corporate initiatives, net of tax of $0 (a)	Other operation and maintenance	$	—	$	(1)
IT transformation, net of tax of $1 (b)	Other operation and maintenance	(1)		—
Office relocation and related costs, net of tax of $0 (c)	Other operation and maintenance	(1)		—
Total Special Items		$	(2)	$	(1)

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(a)Costs incurred related to PPL's corporate centralization efforts.

(b)Costs associated with PPL's restructuring and rebuilding of its IT infrastructure, organization and systems.

(c)Certain costs related to the relocation of corporate offices.

The changes in the components of the Kentucky Regulated segment's results between these periods are due to the factors set forth below, which exclude the items that management considers special.

	Three Months
Operating Revenues	$	75
Fuel	(25)
Energy purchases	(19)
Other operation and maintenance	4
Depreciation	—
Taxes, other than income	—
Other Income (Expense) - net	5
Interest Expense	—
Income Taxes	(6)
Earnings from Ongoing Operations	34
Special Items, after-tax	(1)
Net Income	$	33

•Higher operating revenues primarily due to a $34 million increase in recoveries of fuel and energy purchases, a $28 million increase in sales volumes due to weather and a $14 million increase in off-system sales.

•Higher fuel expense primarily due to an increase in volumes due to weather.

•Higher energy purchases primarily due to an increase in volumes primarily due to weather.

Pennsylvania Regulated Segment

The Pennsylvania Regulated segment consists of the regulated electricity transmission and distribution operations of PPL Electric.

Net Income and Earnings from Ongoing Operations for the periods ended March 31 include the following results:

	Three Months
	2025		2024		$ Change
Operating Revenues	$	819	$	770	$	49
Energy purchases	229		214		15
Other operation and maintenance	162		181		(19)
Depreciation	102		99		3
Taxes, other than income	41		36		5
Total Operating Expenses	534		530		4
Other Income (Expense) - net	11		9		2
Interest Income from Affiliate	2		10		(8)
Interest Expense	60		62		(2)
Income Taxes	54		48		6
Net Income	184		149		35
Less: Special Items	(1)		(12)		11
Earnings from Ongoing Operations	$	185	$	161	$	24

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 during the periods ended March 31.

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	Income Statement Line Item	Three Months
		2025		2024
PPL Electric billing issue, net of tax of $4 (a)	Other operation and maintenance	$	—	$	(11)
Strategic corporate initiatives, net of tax of $0 (b)	Other operation and maintenance	—		(1)
Office relocation and related costs, net of tax of $1 (c)	Other operation and maintenance	(1)		—
Total Special Items		$	(1)	$	(12)

(a)Certain expenses related to billing issues.

(b)Costs incurred related to PPL's corporate centralization and other strategic efforts.

(c)Certain costs related to the relocation of corporate offices.

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.

	Three Months
Operating Revenues	$	49
Energy purchases	(15)
Other operation and maintenance	4
Depreciation	(3)
Taxes, other than income	(5)
Other Income (Expense) - net	2
Interest Income from Affiliate	(8)
Interest Expense	2
Income Taxes	(2)
Earnings from Ongoing Operations	24
Special Items, after-tax	11
Net Income	$	35

•Higher operating revenues primarily due to a $22 million increase in distribution volumes primarily due to weather, $18 million of higher PLR and a $15 million increase in transmission formula rate returns, partially offset by a $6 million decrease in distribution prices.

•Higher energy purchases primarily due to $25 million of higher PLR volumes, partially offset by $15 million of lower PLR prices.

Rhode Island Regulated Segment

The Rhode Island Regulated segment consists of the regulated electricity transmission and distribution and natural gas distribution operations of RIE.

Net Income and Earnings from Ongoing Operations for the periods ended March 31 include the following results:

	Three Months
	2025		2024		$ Change
Operating Revenues	$	626	$	549	$	77
Energy purchases	235		229		6
Other operation and maintenance	200		156		44
Depreciation	42		41		1
Taxes, other than income	47		27		20
Total Operating Expenses	524		453		71
Other Income (Expense) - net	7		7		—
Interest Income from Affiliate	2		—		2
Interest Expense	23		24		(1)
Income Taxes	18		15		3
Net Income	70		64		6
Less: Special Items	(2)		(14)		12
Earnings from Ongoing Operations	$	72	$	78	$	(6)

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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 during the periods ended March 31.

	Income Statement Line Item	Three Months
		2025		2024
Acquisition integration, net of tax of $0, $4 (a)	Other operation and maintenance	$	(2)	$	(14)
Acquisition integration, net of tax of ($2) (b)	Other Income (Expense)	9		—
IT transformation, net of tax of $0 (c)	Other operation and maintenance	(1)		—
Energy efficiency programs settlement, net of tax of $0 (d)	Other Income (Expense)	(8)		—
Total Special Items		$	(2)	$	(14)

(a)2025 costs are related to distributed generation projects that PPL will not seek regulatory recovery of. 2024 primarily includes certain transition services agreement costs for IT systems that will not be part of PPL's ongoing operations.

(b)Costs associated with a final transition services agreement settlement.

(c)Costs associated with PPL's restructuring and rebuilding of its IT infrastructure, organization and systems.

(d)See Note 10 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.

	Three Months
Operating Revenues	$	77
Energy purchases	(6)
Other operation and maintenance	(57)
Depreciation	(1)
Taxes, other than income	(20)
Other Income (Expense) - net	(1)
Interest Income from Affiliate	2
Interest Expense	1
Income Taxes	(1)
Earnings from Ongoing Operations	(6)
Special Items, after-tax	12
Net Income	$	6

•Higher operating revenues primarily due to a $41 million increase related to the effects of conforming the presentation of RIE's net metering charges to that of PPL's other operating utilities beginning in the fourth quarter of 2024, a $24 million increase in recovery of transmission expenses, a $22 million increase in recovery of gross earnings taxes, a $15 million increase in recovery of gas maintenance expenses and a $10 million increase related to capital investments, partially offset by a $35 million decrease in recovery of commodity costs.

•Higher energy purchases primarily due to a $41 million increase due to the effects of conforming the presentation of RIE's net metering charges to that of PPL's other operating utilities beginning in the fourth quarter of 2024, partially offset by a $35 million decrease in commodity costs.

•Higher operation and maintenance expense primarily due to a $24 million increase in transmission expenses, a $15 million increase in gas maintenance expenses, a $6 million increase in bad debt expenses and an $11 million increase of other items that were not individually significant.

•Higher taxes, other than income primarily due to an increase in gross earnings taxes.

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 periods ended March 31.

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	2025 Three Months
	KY Regulated		PA Regulated		RI Regulated		Corporate and Other		Total
Net Income (Loss)	$	223	$	184	$	70	$	(63)	$	414
Less: Special Items (expense) benefit:
Talen litigation costs, net of tax of $0 (a)	—		—		—		(1)		(1)
Acquisition integration, net of tax of ($2), $4 (b)	—		—		7		(14)		(7)
IT transformation, net of tax of $1, $0, $3 (c)	(1)		—		(1)		(10)		(12)
Energy efficiency programs settlement, net of tax of $0 (d)	—		—		(8)		—		(8)
Office relocation and related costs, net of tax of $0, $1 (e)	(1)		(1)		—		—		(2)
Total Special Items	(2)		(1)		(2)		(25)		(30)
Earnings from Ongoing Operations	$	225	$	185	$	72	$	(38)	$	444

(a)PPL incurred legal expenses 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. 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 10 to the Financial Statements for additional information.

(e)Certain costs related to the relocation of corporate offices.

	2024 Three Months
	KY Regulated		PA Regulated		RI Regulated		Corporate and Other		Total
Net Income (Loss)	$	190	$	149	$	64	$	(96)	$	307
Less: Special Items (expense) benefit:
Strategic corporate initiatives, net of tax of $0, $0, $1 (a)	(1)		(1)		—		(2)		(4)
Acquisition integration, net of tax of $4, $17 (b)	—		—		(14)		(66)		(80)
PPL Electric billing issue, net of tax of $4 (c)	—		(11)		—		—		(11)
Total Special Items	(1)		(12)		(14)		(68)		(95)
Earnings from Ongoing Operations	$	191	$	161	$	78	$	(28)	$	402

(a)Represents costs primarily related to PPL's centralization efforts and other strategic efforts.

(b)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. See Note 8 to the Financial Statements for additional information.

(c)Certain expenses related to billing issues.

PPL Electric: Statement of Income Analysis

Net income for the periods ended March 31 includes the following results:

	Three Months
	2025		2024		$ Change
Operating Revenues	$	819	$	770	$	49
Operating Expenses
Operation
Energy purchases	229		214		15
Other operation and maintenance	162		181		(19)
Depreciation	102		99		3
Taxes, other than income	41		36		5
Total Operating Expenses	534		530		4
Operating Income	285		240		45
Other Income (Expense) - net	11		9		2
Interest Income from Affiliate	2		10		(8)
Interest Expense	60		62		(2)
Income Before Income Taxes	238		197		41
Income Taxes	54		48		6
Net Income	$	184	$	149	$	35

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Operating Revenues

The increase (decrease) in operating revenues was due to:

	Three Months
Distribution price (a)	$	(6)
Distribution volume (b)	22
PLR (c)	18
Transmission formula rate (d)	15
Total	$	49

(a)The decrease was primarily due to reconcilable cost recovery mechanisms approved by the PAPUC.

(b)The increase was primarily due to weather, along with other higher usage in 2025.

(c)The increase was primarily the result of higher customer volumes due to weather and other higher usage, partially offset by lower energy prices and fewer PLR customers.

(d)The increase was primarily due to returns on additional transmission capital investments and return of depreciation, partially offset by O&M expenses.

Energy Purchases

Energy purchases increased $15 million for the three months ended March 31, 2025 compared with 2024, primarily due to higher PLR volumes of $25 million, partially offset by lower PLR prices of $15 million.

Other Operation and Maintenance

Other operation and maintenance decreased $19 million for the three months ended March 31, 2025 compared with 2024, primarily due to lower bad debt expenses.

LG&E: Statement of Income Analysis

Net income for the periods ended March 31 includes the following results:

	Three Months
	2025		2024		$ Change
Operating Revenues
Retail and wholesale	$	500	$	460	$	40
Electric revenue from affiliate	5		16		(11)
Total Operating Revenues	505		476		29
Operating Expenses
Operation
Fuel	82		86		(4)
Energy purchases	88		71		17
Energy purchases from affiliate	5		1		4
Other operation and maintenance	89		88		1
Depreciation	74		76		(2)
Taxes, other than income	13		13		—
Total Operating Expenses	351		335		16
Operating Income	154		141		13
Other Income (Expense) - net	3		2		1
Interest Expense	26		26		—
Income Before Income Taxes	131		117		14
Income Taxes	26		24		2
Net Income	$	105	$	93	$	12

Operating Revenues

The increase (decrease) in operating revenues was due to:

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	Three Months
Fuel and other energy purchases (a)	$	12
Volumes (b)	10
Off-system sales (c)	7
Total	$	29

(a)The increase was primarily due to higher recoveries of energy purchases and lower revenues from affiliates due to timing of plant outages and retirements.

(b)The increase was primarily due to weather.

(c)The increase was primarily due to higher volumes.

Energy Purchases

Energy purchases increased $17 million for the three months ended March 31, 2025 compared with 2024, primarily due to an increase in volumes due to weather.

KU: Statement of Income Analysis

Net income for the periods ended March 31 includes the following results:

	Three Months
	2025		2024		$ Change
Operating Revenues
Retail and wholesale	$	559	$	524	$	35
Electric revenue from affiliate	5		1		4
Total Operating Revenues	564		525		39
Operating Expenses
Operation
Fuel	152		123		29
Energy purchases	7		6		1
Energy purchases from affiliate	5		16		(11)
Other operation and maintenance	100		102		(2)
Depreciation	102		99		3
Taxes, other than income	12		12		—
Total Operating Expenses	378		358		20
Operating Income	186		167		19
Other Income (Expense) - net	5		2		3
Interest Expense	35		34		1
Income Before Income Taxes	156		135		21
Income Taxes	31		27		4
Net Income	$	125	$	108	$	17

Operating Revenues

The increase (decrease) in operating revenues was due to:

	Three Months
Fuel and other energy purchases (a)	$	12
Volumes (b)	18
Off-system sales (c)	9
Total	$	39

(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.

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Fuel

Fuel expense increased $29 million for the three months ended March 31, 2025 compared with 2024, primarily due to an increase in volumes due to weather and lower energy purchases from affiliates.

Energy Purchases from affiliate

Energy purchases from affiliate decreased $11 million for the three months ended March 31, 2025 compared with 2024, primarily due to a decrease in volumes due to the timing and scope of plant outages and retirements.

Financial Condition

The remainder of this Item 2 in this Form 10-Q is presented on a combined basis, providing information for each of the Registrants as applicable.

Liquidity and Capital Resources

(All Registrants)

The Registrants had the following at:

	PPL		PPL Electric		LG&E		KU
March 31, 2025
Cash and cash equivalents	$	312	$	27	$	10	$	14
Short-term debt	778		55		89		208
Long-term debt due within one year	569		—		300		268
Notes payable to affiliates			—		—		8
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 to affiliates			—		43		73

(All Registrants)

Net cash provided by (used in) operating, investing and financing activities for the three month periods ended March 31, and the changes between periods, were as follows.

	PPL		PPL Electric		LG&E		KU
2025
Operating activities	$	513	$	134	$	199	$	253
Investing activities	(783)		(97)		(122)		(174)
Financing activities	271		(34)		(78)		(81)
2024
Operating activities	$	282	$	28	$	166	$	252
Investing activities	(591)		(780)		(120)		(148)
Financing activities	248		722		(60)		(108)
Change - Cash Provided (Used)
Operating activities	$	231	$	106	$	33	$	1
Investing activities	(192)		683		(2)		(26)
Financing activities	23		(756)		(18)		27

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Operating Activities

The components of the change in cash provided by (used in) operating activities for the three months ended March 31, 2025 compared with 2024 were as follows.

	PPL		PPL Electric		LG&E		KU
Change - Cash Provided (Used)
Net income	$	107	$	35	$	12	$	17
Non-cash components	(23)		(4)		(3)		5
Working capital	202		89		56		(3)
Other operating activities	(55)		(14)		(32)		(18)
Total	$	231	$	106	$	33	$	1

(PPL)

PPL's cash provided by operating activities in 2025 increased $231 million compared with 2024.

•Net income increased $107 million between the periods and included a decrease in non-cash components of $23 million. The decrease in non-cash components was primarily due to a decrease in deferred income taxes and investment tax credits.

•The $202 million increase in cash from changes in working capital was primarily due to increases in accounts payable and taxes payable (primarily due to timing of payments), a decrease in net regulatory assets (primarily due to the timing of rate recovery mechanisms), a decrease in unbilled revenues (primarily due to weather) and a decrease in prepayments (primarily due to the timing of payments), partially offset by an increase in accounts receivable (primarily due to timing of payments).

•The $55 million decrease in cash provided by other operating activities was driven primarily by an increase in other assets (primarily related to preliminary survey costs for new generation projects) and an increase in noncurrent regulatory assets (primarily related to deferred storm costs recorded as noncurrent regulatory assets).

(PPL Electric)

PPL Electric's cash provided by operating activities in 2025 increased $106 million compared with 2024.

•Net income increased $35 million between the periods and included a decrease in non-cash components of $4 million.

•The $89 million increase in cash from changes in working capital was primarily due to increases in accounts payable and taxes payable (primarily due to timing of payments), a decrease in net regulatory assets (primarily due to the timing of rate recovery mechanisms) and a decrease in prepayments (primarily due to the timing of payments), partially offset by an increase in accounts receivable (primarily due to timing of payments).

•The $14 million decrease in cash provided by other operating activities was driven primarily by an increase in noncurrent regulatory assets (primarily related to deferred storm costs recorded as noncurrent regulatory assets).

(LG&E)

LG&E's cash provided by operating activities in 2025 increased $33 million compared with 2024.

•Net income increased $12 million between the periods and included a decrease in non-cash components of $3 million.

•The $56 million increase in cash from changes in working capital was primarily due to a decrease in accounts receivable from affiliates (primarily due to timing of payments), an increase in accounts payable (primarily due to timing of payments) and decreases in fuel, materials and supplies and accounts receivable (primarily due to weather).

•The $32 million decrease in cash provided by other operating activities was driven by an increase in other assets (primarily related to preliminary survey costs for new generation projects).

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(KU)

KU's cash provided by operating activities in 2025 increased $1 million compared with 2024.

•Net income increased $17 million between the periods and included an increase in non-cash components of $5 million.

•The $3 million decrease in cash from changes in working capital was primarily due to a decrease in accounts payable to affiliates (primarily due to timing of payments) and an increase in accounts receivable (primarily due to weather), partially offset by a decrease in unbilled revenues (primarily due to weather) and an increase in accounts payable (primarily due to timing of payments).

•The $18 million decrease in cash provided by other operating activities was driven by an increase in other assets (primarily related to higher deferred storm costs recorded as noncurrent regulatory assets).

Investing Activities

(All Registrants)

The components of the change in cash provided by (used in) investing activities for the three months ended March 31, 2025 compared with 2024 were as follows.

	PPL		PPL Electric		LG&E		KU
Change - Cash Provided (Used)
Expenditures for PP&E	$	(197)	$	(99)	$	(25)	$	(26)
Notes receivable from affiliate	—		776		23		—
Other investing activities	5		6		—		—
Total	$	(192)	$	683	$	(2)	$	(26)

For PPL, the increase in expenditures for PP&E was due to an increase in project expenditures at PPL Electric, RIE, LG&E and KU. The increase in expenditures at PPL Electric was primarily due to increases in transmission and distribution projects. The increase in expenditures at LG&E and KU was primarily due to Mill Creek Unit 5 and increases in the Advanced Metering Infrastructure initiative.

For PPL Electric, the change in "Notes receivable from affiliate" activity resulted from payments received of $776 million from an affiliate. See Note 11 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 for the three months ended March 31, 2025 compared with 2024 were as follows.

	PPL		PPL Electric		LG&E		KU
Change - Cash Provided (Used)
Debt issuance/retirement, net	$	(1,148)	$	(649)	$	—	$	—
Dividends	(13)		—		(6)		1
Capital contributions/distributions, net	—		(675)		(4)		13
Change in short-term debt, net	1,176		564		36		116
Net increase (decrease) in notes payable with affiliate	—		—		(43)		(102)
Other financing activities	8		4		(1)		(1)
Total	$	23	$	(756)	$	(18)	$	27

See Note 7 to the Financial Statements in this Form 10-Q for information on 2025 short-term and long-term debt activity, equity transactions and PPL dividends. See Note 8 to the Financial Statements in the Registrants' 2024 Form 10-K for information on 2024 activity.

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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 March 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		Unused Capacity
PPL Capital Funding Credit Facilities (a)	$	1,600	$	—	$	427	$	1,173
PPL Electric Credit Facility	750		—		56		694
LG&E Credit Facility	600		—		89		511
KU Credit Facility	600		—		209		391
Total Credit Facilities (b)	$	3,550	$	—	$	781	$	2,769

(a)Includes a $1.5 billion syndicated credit facility with a $250 million borrowing sublimit for RIE and a $1.25 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 March 31, 2025, PPL Capital Funding had $427 million of commercial paper outstanding and RIE had no commercial paper outstanding. RIE's obligations under the facility are not guaranteed by PPL.

(b)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%.

See Note 7 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	$	—	$	89	$	661
KU Money Pool (a)	650		8		209		433

(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 issued, at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on SOFR.

See Note 11 to the Financial Statements for further discussion of intercompany credit facilities.

Commercial Paper (All Registrants)

The Registrants, and 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 facility, with PPL Capital Funding and RIE’s issuances supported by PPL Capital Funding’s syndicated credit facility. The following commercial paper programs were in place at March 31, 2025:

	Capacity		Commercial Paper Issuances		Unused Capacity
PPL Capital Funding (a)	$	1,350	$	427	$	923
RIE (a)	250		—		250
PPL Electric	650		55		595
LG&E	500		89		411
KU	400		209		191
Total PPL	$	3,150	$	780	$	2,370

(a)Issuances under the PPL Capital Funding and RIE commercial paper programs are supported by the PPL Capital Funding syndicated credit facility, which has a total capacity of $1.5 billion, currently with a $250 million borrowing sublimit for RIE and a $1.25 billion sublimit for PPL Capital Funding. PPL Capital Funding's Commercial paper program is also backed by a separate bilateral credit facility for $100 million.

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Long-term Debt (All Registrants)

See Note 7 to the Financial Statements for information regarding the Registrants’ long-term debt activities.

(PPL)

Equity Security Activities

ATM Program

In February 2025, PPL entered into an equity distribution agreement, pursuant to which PPL may sell, from time to time, up to an aggregate of $2 billion of its common stock through an ATM Program, including an optional forward sales component. Each forward contract under the agreement must be settled within 24 months. The compensation paid to the selling agents by PPL may be up to 2% of the gross offering proceeds of the shares. During the three months ended March 31, 2025, PPL entered into a forward contract to sell approximately 2.0 million shares of its common stock at an initial forward price of $34.49 per share. The forward sale price may be adjusted based on changes in daily interest rates, for certain stock loan fees as determined by a third-party agent, and will be subject to predetermined reductions based on expected dividends. This forward contract must be settled on or before December 30, 2025. PPL may elect, at its discretion, to physically settle, net share settle or net cash settle the forward contracts. At March 31, 2025, PPL could have settled the forward sale contract with physical delivery of 2.0 million shares of common stock for proceeds of approximately $70 million. In April 2025, PPL entered into forward contracts to sell approximately 2.8 million additional shares at a blended initial forward price of approximately $35.22 per share. The forward contracts under the ATM program are classified as equity transactions.

Common Stock Dividends

In February 2025, PPL declared a quarterly common stock dividend, payable April 1, 2025, of 27.25 cents per share. Future dividends, declared at the discretion of the Board of Directors, will depend upon future earnings, cash flows, financial and legal requirements and other factors.

Rating Agency Actions

(All Registrants)

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.

Since June 2023, the rating agencies have taken no ratings 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 14 to the Financial Statements for a discussion of "Credit Risk-Related

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Contingent Features," including a discussion of the potential additional collateral requirements for PPL for derivative contracts in a net liability position at March 31, 2025.

(All Registrants)

For additional information on the Registrants' liquidity and capital resources, see "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations," in the Registrants' 2024 Form 10-K.

Risk Management (All Registrants)

Market Risk

See Notes 13 and 14 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 March 31, 2025.

	Exposure Hedged		Fair Value, Net - Asset (Liability) (a)		Effect of a 10% Adverse Movement in Rates (b)		Maturities Ranging Through
PPL and LG&E
Economic hedges
Interest rate swaps (c)	$	64	$	(5)	$	(1)	2033

(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 the fair value of debt at March 31, 2025 is shown below.

	10% Adverse Movement in Rates on Fair Value of Debt
PPL	$	601
PPL Electric	257
LG&E	86
KU	127

Commodity Price Risk

PPL is exposed to commodity price risk through its subsidiaries as described below.

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•PPL Electric is required to purchase electricity to fulfill its obligation as a PLR. Potential commodity price risk is mitigated through its PAPUC-approved cost recovery mechanism and full-requirement supply agreements to serve its PLR customers which transfer the risk to energy suppliers.

•LG&E's and KU's rates include certain mechanisms for fuel, fuel-related expenses and energy purchases. In addition, LG&E's rates include a mechanism for natural gas supply costs. These mechanisms generally provide for timely recovery of market price fluctuations associated with these costs.

•RIE utilizes derivative instruments pursuant to its RIPUC-approved plan to manage commodity price risk associated with its natural gas purchases. RIE's commodity price risk management strategy is to reduce fluctuations in firm gas sales prices to its customers. RIE's costs associated with derivatives instruments are recoverable through its RIPUC-approved cost recovery mechanisms. RIE is also required to purchase electricity to fulfill its obligation to provide Last Resort Service (LRS). Potential commodity price risk is mitigated through its RIPUC-approved cost recovery mechanisms and full requirements service agreements to serve LRS customers, which transfer the risk to energy suppliers. Additionally, RIE is required to contract through long-term agreements for clean energy supply under the Rhode Island Renewable Energy Growth program and Long-term Clean Energy Standard. Potential commodity price risk is mitigated through its RIPUC-approved cost recovery mechanisms, which true-up cost differences between contract prices and market prices.

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 exposed to volumetric risk, which is significantly mitigated by regulatory mechanisms. RIE's electric and gas distribution rates both have a revenue decoupling mechanism, which allows for annual adjustments to RIE's delivery rates.

Inflation and Supply Chain Related Risk

PPL and its subsidiaries continue to monitor the impact of inflation and supply chain disruptions. PPL and its subsidiaries monitor the cost of fuel, construction, regulatory and environmental compliance costs and other costs, including as a result of tariffs. Mechanisms are in place to mitigate the risk of inflationary effects and supply chain disruptions, to the extent possible, but increased costs and supply chain disruptions may directly or indirectly affect our ongoing operations. These mechanisms include pricing strategies, productivity improvements and cost reductions in order to ensure that the Registrants are able to procure the necessary materials and other resources needed to maintain services in a safe and reliable manner, and to invest in infrastructure consistent with the capital expenditure plan. For additional information see "Forward-looking Information” at the beginning of this report and “Item 1A. Risk Factors" of the Registrants' 2024 Form 10-K.

Credit Risk

See Notes 13 and 14 to the Financial Statements in this Form 10-Q and "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations - Financial Condition - Risk Management - Credit Risk" in the Registrants' 2024 Form 10-K for additional information.

Related Party Transactions (All Registrants)

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 11 to the Financial Statements for additional information on related party transactions for PPL Electric, LG&E and KU.

Acquisitions, Development and Divestitures (All Registrants)

The Registrants from time to time evaluate opportunities for potential acquisitions, divestitures and development projects. 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. See Note 8 to the Financial Statements for additional information on acquisition, development, and divestiture activity.

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Environmental Matters (All Registrants)

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 "Environmental Matters" in Item 1. "Business" in the Registrants' 2024 Form 10-K for information about environmental laws and regulations affecting the Registrants' business. See "Financial Condition - Liquidity and Capital Resources - Forecasted Uses of Cash - Capital Expenditures" in "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" in the Registrants' 2024 Form 10-K for information on projected environmental capital expenditures for 2025 through 2027. See "Legal Matters" in Note 10 to the Financial Statements for a discussion of the more significant environmental claims. See Note 15 to the Financial Statements for information related to the impacts of CCRs on AROs.

The information below represents an update to “Item 1. Business – Environmental Matters” in the Registrants' 2024 Form 10-K.

(PPL, LG&E and KU)

EPA Deregulatory Initiative

On March 12, 2025, the EPA announced a plan to reconsider 31 environmental rules including the Section 111 performance standards and emissions limits for greenhouse gases, the endangerment finding for greenhouse gases, the Good Neighbor Plan, the Mercury and Air Toxics Standards, revisions to the fine particulate matter standard, the ELGs, and the CCRs Rule. Supplementing previous Executive Orders directing various regulatory changes, on April 9, 2025, President Trump issued an Executive Order and Presidential Memorandum directing review of existing rules, repeal of unlawful rules, and initiation of a zero-based budgeting process by which certain rules would automatically expire unless extended. While the administration may seek to implement some regulatory changes outside of the rulemaking process, changes to existing rules are generally expected to require formal rulemaking proceedings. Any final EPA actions repealing or revising current rules will likely result in legal challenges. PPL, LG&E, and KU are unable to predict future regulatory changes, if any, that may result from the EPA’s deregulatory plan or the outcome of any associated legal challenges. PPL, LG&E, and KU will closely monitor the ongoing EPA initiative and any related litigation for the impact to our business including planned capital expenditures to comply with the EPA rules.

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Air

NAAQS

The Clean Air Act has a significant impact on the operation of fossil fuel generation plants. The Clean Air Act requires the EPA periodically to establish and review NAAQS for six pollutants including ozone (contributed to by nitrogen oxide emissions) and particulate matter, which are particularly relevant for fossil fuel generation plants. On February 2, 2024, the D.C. Circuit Court granted the EPA’s motion for voluntary remand, without vacatur, of the ozone rule, which was under legal challenge. The EPA will complete a new review to incorporate new studies and updated analyses to determine the adequacy of the existing ozone standard. On March 6, 2024, the EPA finalized revisions to the particulate matter standard that lowers the primary standard for fine particulates. Several states and trade groups challenged the EPA’s finalized revisions to the particulate matter standard in the D.C. Circuit Court. In March 2025, the EPA announced that it would reconsider the revised fine particulate standard. Nonattainment designations for counties in which LG&E and KU generation is located, including Jefferson County, Kentucky, could potentially require additional particulate matter and nitrogen oxide reductions from sources including LG&E’s Mill Creek Station, and more stringent requirements for new generation. PPL, LG&E, and KU are unable to predict future implementation actions or the outcome of future evaluations by the EPA and the states with respect to the NAAQS standards.

In March 2021, the EPA released final revisions to the Cross-State Air Pollution Rule (CSAPR), aimed at ensuring compliance with the 2008 ozone NAAQS and providing for reductions in ozone season nitrogen oxide emissions for 2021 and subsequent years. In March 2023, the EPA released a final Federal Implementation Plan under the Good Neighbor provisions of the Clean Air Act providing for significant additional nitrogen oxide emission reductions for compliance with the revised 2015 ozone NAAQS. The reductions in Kentucky state-wide nitrogen oxide budgets were scheduled to commence in 2023, with the largest reductions planned for 2026. The rules provide for reduced availability of nitrogen oxide allowances that have historically permitted operational flexibility for fossil units and could potentially result in constraints that may require implementation of additional emission controls or accelerate implementation of lower emission generation technologies. In June 2024, the U.S. Supreme Court issued a stay of the Good Neighbor Plan while the D.C. Circuit Court considers legal challenges to the rule. On December 10, 2024, EPA published in the Federal Register a supplement to the record. In March 2025, the EPA announced that it would reconsider the Good Neighbor Plan. On December 6, 2024, the U.S. Court of Appeals for the Sixth Circuit vacated and remanded the EPA’s disapproval of Kentucky’s state implementation plan for the ozone NAAQS. PPL, LG&E, and KU are monitoring ongoing legal and regulatory developments.

PPL, LG&E, and KU are unable to predict the ultimate outcome of pending litigation or future emission reductions that may be required by future federal rules or state implementation actions. Compliance with the NAAQS, CSAPR, Good Neighbor Plan, and related requirements may require installation of additional pollution controls or other compliance actions, inclusive of retirements, the costs of which PPL, LG&E and KU believe would be subject to rate recovery.

Modification of Mercury and Air Toxics Standards

In 2012, the EPA issued the Mercury and Air Toxics Standards (MATS) rule requiring reductions in mercury and other hazardous air pollutants from fossil fuel-fired power plants. LG&E and KU installed significant controls to achieve compliance with MATS and other rules. On May 7, 2024, the EPA issued a final rule increasing the stringency of MATS and further reducing emissions of certain hazardous air pollutants to reflect perceived developments in control technologies. Legal challenges to the rule have been filed in the D.C. Circuit Court. PPL, LG&E, and KU have reviewed the final rule and do not expect significant operational changes or additional controls to be required. In March 2025, the EPA announced that it would reconsider the final rule.

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Greenhouse Gas Standards

On May 9, 2024, the EPA issued a final rule under Section 111 of the Clean Air Act, which establishes performance standards and emissions limits aimed at reducing GHG emissions from certain new, existing, and modified fossil fuel-fired electric generating units (EGUs). In the final rule, the EPA announced it would set performance standards for existing natural gas-fired turbines in a future rule. The standards require phased implementation of carbon mitigation technologies including state-of-the-art efficiency requirements, carbon capture and sequestration, and natural gas co-firing. New natural gas EGUs would be immediately subject to the stricter efficiency standard. Legal challenges to the rule have been filed in the D.C. Circuit Court. PPL, LG&E, and KU are unable to predict the impact of new GHG reduction requirements until completion of a comprehensive review and resolution of related legal and regulatory proceedings. While the impact of new GHG reduction requirements on operations and financial results of operations could potentially be substantial, the cost of complying with such requirements is expected to be subject to rate recovery. In March 2025, the EPA announced that it would reconsider the final rule.

New Accounting Guidance (All Registrants)

There has been no new accounting guidance adopted in 2025. See Note 17 to the Financial Statements for discussion of significant accounting guidance pending adoption as of March 31, 2025.

Application of Critical Accounting Policies (All Registrants)

Financial condition and results of operations are impacted by the methods, assumptions and estimates used in the application of critical accounting policies. The following table summarizes the accounting policies by Registrant that 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. See "Item 7. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations" in the Registrants' 2024 Form 10-K for a discussion of each critical accounting policy.

		PPL
	PPL	Electric	LG&E	KU
Defined Benefits	X	X	X	X
Income Taxes	X	X	X	X
Regulatory Assets and Liabilities	X	X	X	X
Price Risk Management	X
Goodwill Impairment	X		X	X
AROs			X	X
Revenue Recognition - Unbilled Revenue	X		X	X

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PPL Corporation

PPL Electric Utilities Corporation

Louisville Gas and Electric Company

Kentucky Utilities Company

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Reference is made to "Risk Management" in "Item 2. Combined Management's Discussion and Analysis of Financial Condition and Results of Operations."

Item 4. Controls and Procedures

(a) Evaluation of disclosure controls and procedures.

The Registrants' principal executive officers and principal financial officers, based on their evaluation of the Registrants' disclosure controls and procedures (as defined in Rules 13a-15(e) or 15d-15(e) of the Securities Exchange Act of 1934) have concluded that, as of March 31, 2025, the Registrants' disclosure controls and procedures are effective to ensure that material information relating to the Registrants and their consolidated subsidiaries is recorded, processed, summarized and reported within the time periods specified by the SEC's rules and forms, particularly during the period for which this quarterly report has been prepared. The principal officers have concluded that the disclosure controls and procedures are also effective to ensure that information required to be disclosed in reports filed under the Exchange Act is accumulated and communicated to management, including the principal executive and principal financial officers, to allow for timely decisions regarding required disclosure.

(b) Change in internal controls over financial reporting.

The Registrants' principal executive officers and principal financial officers have concluded that there were no changes in the Registrants' internal controls over financial reporting during the Registrants' first fiscal quarter that have materially affected, or are reasonably likely to materially affect, the Registrants' internal control over financial reporting.

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

For information regarding legal, tax, regulatory, environmental or other administrative proceedings that became reportable events or were pending in the first quarter of 2025 see:

•"Item 3. Legal Proceedings" in each Registrant's 2024 Form 10-K; and

•Notes 5, 6, 8 and 10 to the Financial Statements.

Item 1A. Risk Factors

There have been no material changes in the Registrants' risk factors from those disclosed in "Item 1A. Risk Factors" of the Registrants' 2024 Form 10-K.

Item 4. Mine Safety Disclosures

Not applicable.

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Item 5. Other Information

Securities Trading Plans of Directors and Executive Officers

On February 21, 2025, Ms. Angela K. Gosman, Executive Vice President and Chief HR Officer of PPL, adopted a trading arrangement for the sale of shares of PPL’s common stock (a Rule 10b5-1 Trading Plan) that is intended to satisfy the affirmative defense conditions of Rule 10b5-1(c) under the Securities Exchange Act of 1934. Ms. Gosman’s Rule 10b5-1 Trading Plan, which terminates on the earlier of (i) December 31, 2025 and (ii) the date all trades specified under the plan have been executed or all orders under the plan have expired, provides for the sale of up to 6,533 shares of common stock of PPL, plus dividends on such shares prior to sale, pursuant to the terms of the plan.

Item 6. Exhibits

The following Exhibits indicated by an asterisk preceding the Exhibit number are filed herewith. The balance of the Exhibits has heretofore been filed with the Commission and pursuant to Rule 12(b)-23 are incorporated herein by reference. Exhibits indicated by a [_] are filed or listed pursuant to Item 601(b)(10)(iii) of Regulation S-K.

1.1	-	Equity Distribution Agreement, dated February 14, 2025, by and among PPL Corporation and Barclays Capital Inc., BofA Securities, Inc., Goldman Sachs & Co. LLC, J.P. Morgan Securities LLC, Mizuho Securities USA LLC, Morgan Stanley & Co. LLC, MUFG Securities Americas Inc., RBC Capital Markets, LLC, Scotia Capital (USA) Inc. and Wells Fargo Securities, LLC, acting as managers, Barclays Bank PLC, Bank of America, N.A., Goldman Sachs & Co. LLC, JPMorgan Chase Bank, National Association, Mizuho Markets Americas LLC, Morgan Stanley & Co. LLC, Royal Bank of Canada, The Bank of Nova Scotia and Wells Fargo Bank, National Association, acting as forward purchasers, and Barclays Capital Inc., BofA Securities, Inc., Goldman Sachs & Co. LLC, J.P. Morgan Securities LLC, Mizuho Securities USA LLC, Morgan Stanley & Co. LLC, RBC Capital Markets, LLC, Scotia Capital (USA) Inc. and Wells Fargo Securities, LLC acting as forward sellers, including the Form of Master Forward Confirmation attached thereto as Exhibit B. (Exhibit 1.1 to PPL Corporation Form 8-K Report (File No. 1-11459) filed February 14, 2025)
3(g)-1	-	Amended and Restated Articles of Incorporation of Louisville Gas and Electric Company, effective as of November 6, 1996 (Exhibit 3(a) to Registration Statement filed on Form S-4 (File No. 333-173676))
3(g)-2	-	Articles of Amendment to Articles of Incorporation of Louisville Gas and Electric Company, effective as of April 6, 2004 (Exhibit 3(b) to Registration Statement filed on Form S-4 (File No. 333-173676))
*3(g)-3	-	Statement of Change of Principal Office Address: an amendment, dated March 28, 2025, to the Amended and Restated Articles of Incorporation of Louisville Gas and Electric Company, effective November 6, 1996, as amended, effective April 6, 2004
10.1	-	Amendment No.3, dated January 2, 2025, to the Amended and Restated Revolving Credit Agreement, dated as of December 6, 2021, among PPL Capital Funding, Inc., as Borrower, The Narragansett Electric Company, as Designated Borrower, PPL Corporation, as Guarantor, the Lenders party thereto and Wells Fargo Bank, National Association, as Administrative Agent, Issuing Lender and Swingline Lender. (Exhibit 10.1 to PPL Corporation Form 8-K Report (File No. 1-11459) filed January 6, 2025)
10.2	-	Amendment No.3, dated January 2, 2025, to the Amended and Restated Revolving Credit Agreement, dated as of December 6, 2021, among PPL Electric Utilities Corporation, as Borrower, the Lenders party thereto and Wells Fargo Bank, National Association, as Administrative Agent, Issuing Lender and Swingline Lender. (Exhibit 10.2 to PPL Corporation Form 8-K Report (File No. 1-11459) filed January 6, 2025)
10.3	-	Amendment No.3, dated January 2, 2025, to the Amended and Restated Revolving Credit Agreement, dated as of December 6, 2021, among Louisville Gas and Electric Company, as Borrower, the Lenders party thereto and Wells Fargo Bank, National Association, as Administrative Agent, Issuing Lender and Swingline Lender. (Exhibit 10.3 to PPL Corporation Form 8-K Report (File No. 1-11459) filed January 6, 2025)
10.4	-	Amendment No.3, dated January 2, 2025, to the Amended and Restated Revolving Credit Agreement, dated as of December 6, 2021, among Kentucky Utilities Company, as Borrower, the Lenders party thereto and Wells Fargo Bank, National Association, as Administrative Agent, Issuing Lender and Swingline Lender. (Exhibit 10.4 to PPL Corporation Form 8-K Report (File No. 1-11459) filed January 6, 2025)

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10.5[_]	-	Separation Agreement between Francis X. Sullivan and PPL Services Corporation, dated January 14, 2025. (Exhibit 10.1 to PPL Corporation Form 8-K Report (File No. 1-11459) filed January 15, 2025)
10.6[_]	-	Form of Change in Control Severance Protection Agreement entered into between PPL Corporation and Joseph P. Bergstein, Jr., David J. Bonenberger, John Gregory Cornett, John R. Crockett III, Dean A. Del Vecchio, Angela K. Gosman, Christine M. Martin, Stephanie R. Raymond, Vincent Sorgi, Francis X. Sullivan, Wendy E. Stark and Lonnie E. Bellar. (Exhibit [_]10(s) to PPL Corporation Form 10-K Report (File No. 1-11459) for the year ended December 31, 2023)
Certifications pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, for the quarterly period ended March 31, 2025, filed by the following officers for the following companies:
*31(a)	-	PPL Corporation's principal executive officer
*31(b)	-	PPL Corporation's principal financial officer
*31(c)	-	PPL Electric Utilities Corporation's principal executive officer
*31(d)	-	PPL Electric Utilities Corporation's principal financial officer
*31(e)	-	Louisville Gas and Electric Company's principal executive officer
*31(f)	-	Louisville Gas and Electric Company's principal financial officer
*31(g)	-	Kentucky Utilities Company's principal executive officer
*31(h)	-	Kentucky Utilities Company's principal financial officer
Certifications pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, for the quarterly period ended March 31, 2025, furnished by the following officers for the following companies:
*32(a)	-	PPL Corporation's principal executive officer and principal financial officer
*32(b)	-	PPL Electric Utilities Corporation's principal executive officer and principal financial officer
*32(c)	-	Louisville Gas and Electric Company's principal executive officer and principal financial officer
*32(d)	-	Kentucky Utilities Company's principal executive officer and principal financial officer
101.INS	-	XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
101.SCH	-	XBRL Taxonomy Extension Schema
101.CAL	-	XBRL Taxonomy Extension Calculation Linkbase
101.DEF	-	XBRL Taxonomy Extension Definition Linkbase
101.LAB	-	XBRL Taxonomy Extension Label Linkbase
101.PRE	-	XBRL Taxonomy Extension Presentation Linkbase
104	-	The Cover Page Interactive Data File is formatted as Inline XBRL and contained in Exhibits 101.

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SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrants have duly caused this report to be signed on their behalf by the undersigned thereunto duly authorized. The signature for each undersigned company shall be deemed to relate only to matters having reference to such company or its subsidiaries.

		PPL Corporation
		(Registrant)
Date:	April 30, 2025	/s/  Marlene C. Beers
		Marlene C. Beers Vice President and Controller
		(Principal Accounting Officer)
		PPL Electric Utilities Corporation
		(Registrant)
Date:	April 30, 2025	/s/  Marlene C. Beers
		Marlene C. Beers Vice President and Controller
		(Principal Accounting and Financial Officer)
		Louisville Gas and Electric Company
		(Registrant)
		Kentucky Utilities Company
		(Registrant)
Date:	April 30, 2025	/s/  Christopher M. Garrett
		Christopher M. Garrett Vice President-Finance and Accounting
		(Principal Accounting and Financial Officer)

88

EX-3.G3

3/28/2025Commonwealth of Kentucky Michael G. Adams, Secretary of State Michael G. Adams Secretary of State P. O. Box 718 Frankfort, KY 40602-0718 (502) 564-3490 http://www.sos.ky.gov Statement of Change of Principal Office Address POC 00 2196 Pursuant to the provisions of KRS 14A.5-010, the undersigned hereby applies to change the principal office on behalf of LOUISVILLE GAS AND ELECTRIC COMPANY and for that purpose submits the following statements: 1. Address of current principal office 220 W. MAIN ST., LGE-11 LEGAL DEPARTMENT LOUISVILLE, KY 40202 2. Principal office is hereby changed to: 820 WEST BROADWAY LOUISVILLE, KY 40202 3. Authorized Signature of Entity Deborah C Gregor, Asst Corporate Secretary Signature and Title Deborah C Gregor, Asst Corporate Secretary Type or print name and title 3/28/2025 8:38 AM Date PPOC 0032196 Michael G. Adams KY Secretary of State Received and Filed 3/28/2025 8:38:00 AM Fee receipt: $10.00 Exhibit 3g-3

EX-31.A

Exhibit 31(a)

CERTIFICATION

I, VINCENT SORGI, certify that:

1.I have reviewed this quarterly report on Form 10-Q of PPL Corporation (the "registrant");

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:	April 30, 2025	/s/  Vincent Sorgi
		Vincent Sorgi
		President and Chief Executive Officer
		(Principal Executive Officer)
		PPL Corporation

EX-31.B

Exhibit 31(b)

CERTIFICATION

I, JOSEPH P. BERGSTEIN, JR., certify that:

1.I have reviewed this quarterly report on Form 10-Q of PPL Corporation (the "registrant");

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:	April 30, 2025	/s/  Joseph P. Bergstein, Jr.
		Joseph P. Bergstein, Jr.
		Executive Vice President and Chief Financial Officer
		(Principal Financial Officer)
		PPL Corporation

EX-31.C

Exhibit 31(c)

CERTIFICATION

I, CHRISTINE M. MARTIN, certify that:

1.I have reviewed this quarterly report on Form 10-Q of PPL Electric Utilities Corporation (the "registrant");

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:	April 30, 2025	/s/  Christine M. Martin
		Christine M. Martin
		President
		(Principal Executive Officer)
		PPL Electric Utilities Corporation

EX-31.D

Exhibit 31(d)

CERTIFICATION

I, MARLENE C. BEERS, certify that:

1.I have reviewed this quarterly report on Form 10-Q of PPL Electric Utilities Corporation (the "registrant");

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:	April 30, 2025	/s/  Marlene C. Beers
		Marlene C. Beers
		Vice President and Controller
		(Principal Financial Officer)
		PPL Electric Utilities Corporation

EX-31.E

Exhibit 31(e)

CERTIFICATION

I, JOHN R. CROCKETT III, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Louisville Gas and Electric Company (the "registrant");

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:	April 30, 2025	/s/  John R. Crockett III
		John R. Crockett III
		President
		(Principal Executive Officer)
		Louisville Gas and Electric Company

EX-31.F

Exhibit 31(f)

CERTIFICATION

I, CHRISTOPHER M. GARRETT, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Louisville Gas and Electric Company (the "registrant");

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:	April 30, 2025	/s/  Christopher M. Garrett
		Christopher M. Garrett
		Vice President-Finance and Accounting
		(Principal Financial Officer)
		Louisville Gas and Electric Company

EX-31.G

Exhibit 31(g)

CERTIFICATION

I, JOHN R. CROCKETT III, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Kentucky Utilities Company (the "registrant");

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:	April 30, 2025	/s/  John R. Crockett III
		John R. Crockett III
		President
		(Principal Executive Officer)
		Kentucky Utilities Company

EX-31.H

Exhibit 31(h)

CERTIFICATION

I, CHRISTOPHER M. GARRETT, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Kentucky Utilities Company (the "registrant");

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a.Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b.Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c.Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d.Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

a.All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

b.Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

Date:	April 30, 2025	/s/  Christopher M. Garrett
		Christopher M. Garrett
		Vice President-Finance and Accounting
		(Principal Financial Officer)
		Kentucky Utilities Company

EX-32.A

Exhibit 32(a)

CERTIFICATE PURSUANT TO 18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

FOR PPL CORPORATION'S FORM 10-Q FOR THE QUARTER ENDED MARCH 31, 2025

    In connection with the quarterly report on Form 10-Q of PPL Corporation (the "Company") for the quarter ended March 31, 2025, as filed with the Securities and Exchange Commission on the date hereof (the "Covered Report"), we, Vincent Sorgi, the Principal Executive Officer of the Company, and Joseph P. Bergstein, Jr., the Principal Financial Officer of the Company, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, hereby certify that:

•The Covered Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

•The information contained in the Covered Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:	April 30, 2025	/s/  Vincent Sorgi
		Vincent Sorgi
		President and Chief Executive Officer
		(Principal Executive Officer)
		PPL Corporation
		/s/  Joseph P. Bergstein, Jr.
		Joseph P. Bergstein, Jr.
		Executive Vice President and Chief Financial Officer
		(Principal Financial Officer)
		PPL Corporation

    A signed original of this written statement required by Section 906 has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.B

Exhibit 32(b)

CERTIFICATE PURSUANT TO 18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

FOR PPL ELECTRIC UTILITIES CORPORATION'S FORM 10-Q FOR THE QUARTER ENDED MARCH 31, 2025

    In connection with the quarterly report on Form 10-Q of PPL Electric Utilities Corporation (the "Company") for the quarter ended March 31, 2025, as filed with the Securities and Exchange Commission on the date hereof (the "Covered Report"), we, Christine M. Martin, the Principal Executive Officer of the Company, and Marlene C. Beers, the Principal Financial Officer of the Company, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, hereby certify that:

•The Covered Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

•The information contained in the Covered Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:	April 30, 2025	/s/  Christine M. Martin
		Christine M. Martin
		President
		(Principal Executive Officer)
		PPL Electric Utilities Corporation
		/s/  Marlene C. Beers
		Marlene C. Beers
		Vice President and Controller
		(Principal Financial Officer)
		PPL Electric Utilities Corporation

    A signed original of this written statement required by Section 906 has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.C

Exhibit 32(c)

CERTIFICATE PURSUANT TO 18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

FOR LOUISVILLE GAS AND ELECTRIC COMPANY'S FORM 10-Q FOR THE QUARTER ENDED MARCH 31, 2025

    In connection with the quarterly report on Form 10-Q of Louisville Gas and Electric Company (the "Company") for the quarter ended March 31, 2025, as filed with the Securities and Exchange Commission on the date hereof (the "Covered Report"), we, John R. Crockett III, the Principal Executive Officer of the Company, and Christopher M. Garrett, the Principal Financial Officer of the Company, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, hereby certify that:

•The Covered Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

•The information contained in the Covered Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:	April 30, 2025	/s/  John R. Crockett III
		John R. Crockett III
		President
		(Principal Executive Officer)
		Louisville Gas and Electric Company
		/s/  Christopher M. Garrett
		Christopher M. Garrett
		Vice President-Finance and Accounting
		(Principal Financial Officer)
		Louisville Gas and Electric Company

    A signed original of this written statement required by Section 906 has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

EX-32.D

Exhibit 32(d)

CERTIFICATE PURSUANT TO 18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

FOR KENTUCKY UTILITIES COMPANY'S FORM 10-Q FOR THE QUARTER ENDED MARCH 31, 2025

    In connection with the quarterly report on Form 10-Q of Kentucky Utilities Company (the "Company") for the quarter ended March 31, 2025, as filed with the Securities and Exchange Commission on the date hereof (the "Covered Report"), we, John R. Crockett III, the Principal Executive Officer of the Company, and Christopher M. Garrett, the Principal Financial Officer of the Company, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, hereby certify that:

•The Covered Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

•The information contained in the Covered Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:	April 30, 2025	/s/  John R. Crockett III
		John R. Crockett III
		President
		(Principal Executive Officer)
		Kentucky Utilities Company
		/s/  Christopher M. Garrett
		Christopher M. Garrett
		Vice President-Finance and Accounting
		(Principal Financial Officer)
		Kentucky Utilities Company

    A signed original of this written statement required by Section 906 has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission or its staff upon request.

XML

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2025	Apr. 25, 2025
Document Entity Information [Line Items]
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entity File Number	1-11459
Entity Incorporation, State or Country Code	PA
Entity Address, Address Line One	645 Hamilton Street
Entity Address, City or Town	Allentown,
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	18101
City Area Code	(610)
Local Phone Number	774-5151
Document Type	10-Q
Amendment Flag	false
Entity Registrant Name	PPL Corporation
Entity Tax Identification Number	23-2758192
Entity Central Index Key	0000922224
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding		739,263,912
Document Fiscal Year Focus	2025
Document Fiscal Period Focus	Q1
Document Quarterly Report	true
Document Transition Report	false
Common Stock [Member]
Document Entity Information [Line Items]
Title of 12(b) Security	Common Stock of PPL Corporation
Trading Symbol	PPL
Security Exchange Name	NYSE
2007 Series A Junior Subordinated Notes due 2067 [Member]
Document Entity Information [Line Items]
Title of 12(b) Security	2007 Series A due 2067
Trading Symbol	PPL/67
Security Exchange Name	NYSE
PPL Electric Utilities Corp [Member]
Document Entity Information [Line Items]
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entity File Number	1-905
Entity Incorporation, State or Country Code	PA
Entity Address, Address Line One	827 Hausman Road
Entity Address, City or Town	Allentown,
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	18104-9392
City Area Code	(610)
Local Phone Number	774-5151
Amendment Flag	false
Entity Registrant Name	PPL Electric Utilities Corporation
Entity Tax Identification Number	23-0959590
Entity Central Index Key	0000317187
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding		66,368,056
Louisville Gas And Electric Co [Member]
Document Entity Information [Line Items]
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entity File Number	1-2893
Entity Incorporation, State or Country Code	KY
Entity Address, Address Line One	820 West Broadway
Entity Address, City or Town	Louisville,
Entity Address, State or Province	KY
Entity Address, Postal Zip Code	40202
City Area Code	(502)
Local Phone Number	627-2000
Amendment Flag	false
Entity Registrant Name	Louisville Gas and Electric Company
Entity Tax Identification Number	61-0264150
Entity Central Index Key	0000060549
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding		21,294,223
Kentucky Utilities Co [Member]
Document Entity Information [Line Items]
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entity File Number	1-3464
Entity Incorporation, State or Country Code	KY
Entity Incorporation, State or Country Code	VA
Entity Address, Address Line One	One Quality Street
Entity Address, City or Town	Lexington,
Entity Address, State or Province	KY
Entity Address, Postal Zip Code	40507-1462
City Area Code	(502)
Local Phone Number	627-2000
Amendment Flag	false
Entity Registrant Name	Kentucky Utilities Company
Entity Tax Identification Number	61-0247570
Entity Central Index Key	0000055387
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding		37,817,878

XML

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (Unaudited) - USD ($) shares in Thousands, $ in Millions		3 Months Ended
		Mar. 31, 2025		Mar. 31, 2024
Operating Revenues
Operating Revenues		$ 2,504		$ 2,304
Operation
Fuel		234		209
Energy purchases		559		520
Other operation and maintenance		598		626
Depreciation		322		316
Taxes, other than income		113		88
Total Operating Expenses		1,826		1,759
Operating Income		678		545
Other Income (Expense) - net		28		22
Interest Expense		190		179
Income Taxes		102		81
Income from continuing operations after income taxes		414
Net Income (Loss)		$ 414		$ 307
Net Income:
Diluted (in dollars per share)		$ 0.56		$ 0.42
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic (in shares)		738,691		737,512
Diluted (in shares)		741,400		738,820
Income from Continuing Operations Before Income Taxes		$ 516		$ 388
Income (Loss) from Continuing Operations After Income Taxes, Basic		$ 0.56		$ 0.42
Income (Loss) from Continuing Operations after income taxes, Diluted		$ 0.56		$ 0.42
PPL Electric Utilities Corp [Member]
Operating Revenues
Operating Revenues		$ 819		$ 770
Operation
Energy purchases		229		214
Other operation and maintenance		162		181
Depreciation		102		99
Taxes, other than income		41		36
Total Operating Expenses		534		530
Operating Income		285		240
Other Income (Expense) - net		11		9
Interest Expense		60		62
Income Taxes		54		48
Net Income (Loss)	[1]	184		149
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Income from Continuing Operations Before Income Taxes		238		197
PPL Electric Utilities Corp [Member] | Related Party
Operation
Interest Income from affiliate		2		10
Louisville Gas And Electric Co [Member]
Operating Revenues
Operating Revenues		505		476
Operation
Fuel		82		86
Energy purchases		88		71
Energy purchases from affiliate		5		1
Other operation and maintenance		89		88
Depreciation		74		76
Taxes, other than income		13		13
Total Operating Expenses		351		335
Operating Income		154		141
Other Income (Expense) - net		3		2
Interest Expense		26		26
Income Taxes		26		24
Net Income (Loss)		105	[2]	93
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Income from Continuing Operations Before Income Taxes		131		117
Louisville Gas And Electric Co [Member] | Related Party
Operating Revenues
Retail and wholesale		5		16
Louisville Gas And Electric Co [Member] | Nonrelated Party
Operating Revenues
Retail and wholesale		500		460
Kentucky Utilities Co [Member]
Operating Revenues
Operating Revenues		564		525
Operation
Fuel		152		123
Energy purchases		7		6
Energy purchases from affiliate		5		16
Other operation and maintenance		100		102
Depreciation		102		99
Taxes, other than income		12		12
Total Operating Expenses		378		358
Operating Income		186		167
Other Income (Expense) - net		5		2
Interest Expense		35		34
Income Taxes		31		27
Net Income (Loss)	[3]	125		108
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Income from Continuing Operations Before Income Taxes		156		135
Kentucky Utilities Co [Member] | Related Party
Operating Revenues
Retail and wholesale		5		1
Kentucky Utilities Co [Member] | Nonrelated Party
Operating Revenues
Retail and wholesale		$ 559		$ 524

[1] Net income equals comprehensive income.

[2] Net income equals comprehensive income.

[3] Net income equals comprehensive income.

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2025	Mar. 31, 2024
Net income (loss)	$ 414	$ 307
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Equity investees' other comprehensive income (loss), net of tax	0	1
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Qualifying derivatives, net of tax	1	1
Other Comprehensive (Income) Loss, Defined Benefit Plans, after Reclassification Adjustment, after Tax [Abstract]
Defined benefit plans, Net actuarial (gain) loss, net of tax	(1)	0
Total other comprehensive income (loss)	0	2
Comprehensive income (loss)	$ 414	$ 309

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2025	Mar. 31, 2024
Tax effect of qualifying derivatives reclassified from AOCI	$ 0	$ 0
Tax effect of net actuarial (gain) loss reclassified from AOCI	0	0
Tax effect of equity investee's other comprehensive income (loss)	$ 0	$ 0

XML

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2025		Mar. 31, 2024
Cash Flows from Operating Activities
Net income (loss)		$ 414		$ 307
Income from continuing operations (net of income taxes)		414
Depreciation		322		316
Amortization		20		24
Defined benefit plans - (income) expense		(16)		(15)
Deferred income taxes and investment tax credits		38		72
Other		13		3
Change in current assets and current liabilities
Accounts receivable		(277)		(75)
Accounts payable		(120)		(221)
Unbilled revenues		108		57
Fuel, materials and supplies		37		33
Prepayments		(87)		(108)
Taxes payable		40		(47)
Regulatory assets and liabilities, net		79		(61)
Accrued interest		67		90
Other		(80)		(103)
Other operating activities
Defined benefit plans - funding		(5)		(5)
Other assets		(50)		(1)
Other liabilities		10		16
Net cash provided by operating activities		513		282
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(793)		(596)
Other investing activities		10		5
Net cash used in investing activities		(783)		(591)
Cash Flows from Financing Activities
Issuance of long-term debt		0		1,148
Payment of common stock dividends		(190)		(177)
Net increase (decrease) in short-term debt		475		(701)
Other financing activities		(14)		(22)
Net cash provided by financing activities		271		248
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		1		(61)
Cash and Cash Equivalents at Beginning of Period		306
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		339		382
Cash and Cash Equivalents at End of Period		312
Cash, Cash Equivalents and Restricted Cash at End of Period		340		321
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at March 31,		397		253
PPL Electric Utilities Corp [Member]
Cash Flows from Operating Activities
Net income (loss)	[1]	184		149
Depreciation		102		99
Amortization		11		12
Defined benefit plans - (income) expense		(7)		(11)
Deferred income taxes and investment tax credits		20		32
Other		(5)		(7)
Change in current assets and current liabilities
Accounts receivable		(132)		(33)
Accounts payable		(7)		(59)
Unbilled revenues		43		30
Fuel, materials and supplies		(8)		(4)
Prepayments		(90)		(110)
Taxes payable		(2)		(48)
Regulatory assets and liabilities, net		36		(28)
Accrued interest		19		35
Other		(13)		(26)
Other operating activities
Other assets		(18)		0
Other liabilities		1		(3)
Net cash provided by operating activities		134		28
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(328)		(229)
Expenditures for intangible assets		(1)		(1)
Notes receivable from affiliates		222		(554)
Other investing activities		10		4
Net cash used in investing activities		(97)		(780)
Cash Flows from Financing Activities
Issuance of long-term debt		0		649
Payment of common stock dividends to parent		(88)		(88)
Net increase (decrease) in short-term debt		55		(509)
Contributions from parent		0		675
Debt Issuance Costs		(1)		(5)
Net cash provided by financing activities		(34)		722
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		3		(30)
Cash and Cash Equivalents at Beginning of Period		24
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		24		51
Cash and Cash Equivalents at End of Period		27
Cash, Cash Equivalents and Restricted Cash at End of Period		27		21
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at March 31,		185		146
Louisville Gas And Electric Co [Member]
Cash Flows from Operating Activities
Net income (loss)		105	[2]	93
Depreciation		74		76
Amortization		4		3
Deferred income taxes and investment tax credits		1		2
Other		0		1
Change in current assets and current liabilities
Accounts receivable		(11)		(19)
Accounts receivable from affiliates		12		(11)
Accounts payable		23		6
Increase (Decrease) in Accounts Payable, Related Parties		26		34
Unbilled revenues		19		16
Fuel, materials and supplies		23		13
Taxes payable		(23)		(26)
Regulatory assets and liabilities, net		(21)		(21)
Accrued interest		23		23
Other		(19)		(19)
Other operating activities
Expenditures for asset retirement obligations		(2)		(2)
Other assets		(32)		0
Other liabilities		(3)		(3)
Net cash provided by operating activities		199		166
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(117)		(92)
Notes receivable from affiliates		(5)		(28)
Net cash used in investing activities		(122)		(120)
Cash Flows from Financing Activities
Increase Decrease In Notes Payable To Affiliates		(43)		0
Payment of common stock dividends to parent		(43)		(37)
Net increase (decrease) in short-term debt		64		28
Return of capital to parent		(55)		(51)
Debt Issuance Costs		(1)		0
Net cash provided by financing activities		(78)		(60)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(1)		(14)
Cash and Cash Equivalents at Beginning of Period		8
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		24		44
Cash and Cash Equivalents at End of Period		10
Cash, Cash Equivalents and Restricted Cash at End of Period		23		30
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at March 31,		72		35
Kentucky Utilities Co [Member]
Cash Flows from Operating Activities
Net income (loss)	[3]	125		108
Depreciation		102		99
Amortization		4		5
Deferred income taxes and investment tax credits		3		(1)
Other		(3)		(2)
Change in current assets and current liabilities
Accounts receivable		(29)		(21)
Accounts payable		(3)		(13)
Increase (Decrease) in Accounts Payable, Related Parties		29		52
Unbilled revenues		18		6
Fuel, materials and supplies		7		8
Taxes payable		(18)		(17)
Regulatory assets and liabilities, net		5		1
Accrued interest		32		32
Other		(3)		(7)
Other operating activities
Expenditures for asset retirement obligations		(2)		(2)
Other assets		(9)		8
Other liabilities		(5)		(4)
Net cash provided by operating activities		253		252
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(174)		(148)
Other investing activities		0		0
Net cash used in investing activities		(174)		(148)
Cash Flows from Financing Activities
Increase Decrease In Notes Payable To Affiliates		(65)		37
Payment of common stock dividends to parent		(46)		(47)
Net increase (decrease) in short-term debt		68		(48)
Return of capital to parent		(37)		(50)
Debt Issuance Costs		(1)		0
Net cash provided by financing activities		(81)		(108)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(2)		(4)
Cash and Cash Equivalents at Beginning of Period		13
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		29		38
Cash and Cash Equivalents at End of Period		14
Cash, Cash Equivalents and Restricted Cash at End of Period		27		34
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at March 31,		$ 74		$ 44

[1] Net income equals comprehensive income.

[2] Net income equals comprehensive income.

[3] Net income equals comprehensive income.

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Millions		Mar. 31, 2025	Dec. 31, 2024
Assets, Current [Abstract]
Cash and cash equivalents		$ 312	$ 306
Accounts receivable (less reserve:)
Customer		1,208	961
Other		93	76
Unbilled revenues		377	485
Fuel, materials and supplies		476	511
Prepayments		223	136
Regulatory Assets, Current		274	320
Other current assets		133	85
Total Current Assets		3,096	2,880
Property, Plant and Equipment
Regulated utility plant		40,648	40,391
Less: accumulated depreciation - regulated utility plant		9,751	9,682
Regulated utility plant, net		30,897	30,709
Non-regulated property, plant and equipment		80	79
Less: accumulated depreciation - non-regulated property, plant and equipment		30	29
Non-regulated property, plant and equipment, net		50	50
Construction work in progress		2,695	2,390
Property, Plant and Equipment, net		33,642	33,149
Other Noncurrent Assets
Regulatory assets		2,049	2,060
Goodwill		2,247	2,247
Other intangibles		312	314
Other noncurrent assets		463	419
Assets, Noncurrent		5,071	5,040
Total Assets		41,809	41,069
Current Liabilities
Short-term debt		778	303
Long-term debt due within one year		569	551
Accounts payable		1,097	1,196
Taxes		143	103
Interest		224	157
Dividends		197	186
Regulatory liabilities		274	223
Other current liabilities		545	614
Liabilities, Current, Total		3,827	3,333
Long-term Debt, Unclassified [Abstract]
Long-term Debt		15,938	15,952
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		3,421	3,356
Investment tax credits		111	111
Accrued pension obligations		298	317
Asset retirement obligations		130	136
Regulatory liabilities		3,338	3,335
Other deferred credits and noncurrent liabilities		449	452
Total Deferred Credits and Other Noncurrent Liabilities		7,747	7,707
Commitments and Contingent Liabilities
Equity
Common stock	[1]	8	8
Additional paid-in capital		12,330	12,346
Treasury Stock		(904)	(928)
Earnings reinvested		3,047	2,835
Accumulated other comprehensive loss		(184)	(184)
Total Equity		14,297	14,077
Total Liabilities and Equity		41,809	41,069
PPL Electric Utilities Corp [Member]
Assets, Current [Abstract]
Cash and cash equivalents		27	24
Accounts receivable (less reserve:)
Other		21	8
Unbilled revenues		116	159
Notes Receivable from affiliates			222
Fuel, materials and supplies		110	104
Prepayments		164	74
Regulatory Assets, Current		94	133
Other current assets		43	30
Total Current Assets		1,043	1,117
Property, Plant and Equipment
Regulated utility plant		16,503	16,469
Less: accumulated depreciation - regulated utility plant		3,983	4,052
Regulated utility plant, net		12,520	12,417
Construction work in progress		1,032	898
Property, Plant and Equipment, net		13,552	13,315
Other Noncurrent Assets
Regulatory assets		685	673
Other intangibles		274	274
Other noncurrent assets		100	96
Assets, Noncurrent		1,059	1,043
Total Assets		15,654	15,475
Current Liabilities
Short-term debt		55	0
Interest		74	55
Regulatory liabilities		54	57
Other current liabilities		77	85
Liabilities, Current, Total		870	806
Long-term Debt, Unclassified [Abstract]
Long-term Debt		5,214	5,214
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,756	1,726
Regulatory liabilities		835	839
Other deferred credits and noncurrent liabilities		153	160
Total Deferred Credits and Other Noncurrent Liabilities		2,744	2,725
Commitments and Contingent Liabilities
Equity
Common stock	[2]	364	364
Additional paid-in capital		4,668	4,668
Earnings reinvested		1,794	1,698
Total Equity		6,826	6,730
Total Liabilities and Equity		15,654	$ 15,475
Financing Receivable, after Allowance for Credit Loss, Related Party, Type [Extensible Enumeration]			CEP Reserves, Inc
PPL Electric Utilities Corp [Member] | Related Party
Accounts receivable (less reserve:)
Customer		11	$ 10
Notes Receivable from affiliates		0	222
Current Liabilities
Accounts payable		133	44
PPL Electric Utilities Corp [Member] | Nonrelated Party
Accounts receivable (less reserve:)
Customer		457	353
Current Liabilities
Accounts payable		477	565
Louisville Gas And Electric Co [Member]
Assets, Current [Abstract]
Cash and cash equivalents		10	8
Accounts receivable (less reserve:)
Other		31	23
Unbilled revenues		68	87
Fuel, materials and supplies		134	157
Prepayments		9	9
Regulatory Assets, Current		31	8
Other current assets		11	2
Total Current Assets		468	468
Property, Plant and Equipment
Regulated utility plant		7,787	7,748
Less: accumulated depreciation - regulated utility plant		1,696	1,643
Regulated utility plant, net		6,091	6,105
Construction work in progress		515	443
Property, Plant and Equipment, net		6,606	6,548
Other Noncurrent Assets
Regulatory assets		491	491
Goodwill		389	389
Other intangibles		11	12
Other noncurrent assets		116	84
Assets, Noncurrent		1,007	976
Total Assets		8,081	7,992
Current Liabilities
Short-term debt		89	25
Long-term debt due within one year		$ 300	$ 300
Notes Payable, Related Party, Type [Extensible Enumeration]		Affiliated Entity [Member]	Related Party
Notes Payable to affiliates		$ 0	$ 43
Taxes		17	40
Interest		44	21
Current Customer Deposits		36	36
Regulatory liabilities		16	14
Asset Retirement Obligation, Current		10	11
Other current liabilities		41	50
Liabilities, Current, Total		836	762
Long-term Debt, Unclassified [Abstract]
Long-term Debt		2,171	2,171
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		809	803
Investment tax credits		29	30
Asset retirement obligations		74	73
Regulatory liabilities		814	815
Price risk management liabilities		4	3
Other deferred credits and noncurrent liabilities		66	64
Total Deferred Credits and Other Noncurrent Liabilities		1,796	1,788
Commitments and Contingent Liabilities
Equity
Common stock	[3]	424	424
Additional paid-in capital		1,927	1,982
Earnings reinvested		927	865
Total Equity		3,278	3,271
Total Liabilities and Equity		8,081	7,992
Louisville Gas And Electric Co [Member] | Related Party
Accounts receivable (less reserve:)
Customer		28	40
Notes Receivable from affiliates		5	0
Current Liabilities
Accounts payable		90	64
Louisville Gas And Electric Co [Member] | Nonrelated Party
Accounts receivable (less reserve:)
Customer		141	134
Current Liabilities
Accounts payable		193	158
Kentucky Utilities Co [Member]
Assets, Current [Abstract]
Cash and cash equivalents		14	13
Accounts receivable (less reserve:)
Customer		180	160
Other		28	22
Unbilled revenues		84	102
Fuel, materials and supplies		166	173
Prepayments		10	11
Regulatory Assets, Current		0	1
Other current assets		16	9
Total Current Assets		498	491
Property, Plant and Equipment
Regulated utility plant		10,454	10,419
Less: accumulated depreciation - regulated utility plant		2,721	2,652
Regulated utility plant, net		7,733	7,767
Construction work in progress		679	567
Property, Plant and Equipment, net		8,412	8,334
Other Noncurrent Assets
Regulatory assets		460	458
Goodwill		607	607
Other intangibles		27	28
Other noncurrent assets		157	155
Assets, Noncurrent		1,251	1,248
Total Assets		10,161	10,073
Current Liabilities
Short-term debt		208	140
Long-term debt due within one year		$ 268	$ 250
Notes Payable, Related Party, Type [Extensible Enumeration]		Affiliated Entity [Member]	Related Party
Notes Payable to affiliates		$ 8	$ 73
Taxes		19	37
Interest		56	24
Current Customer Deposits		39	39
Regulatory liabilities		26	22
Asset Retirement Obligation, Current		14	10
Other current liabilities		61	58
Liabilities, Current, Total		917	849
Long-term Debt, Unclassified [Abstract]
Long-term Debt		2,798	2,816
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		934	924
Investment tax credits		81	81
Asset retirement obligations		47	54
Regulatory liabilities		1,007	1,009
Other deferred credits and noncurrent liabilities		36	41
Total Deferred Credits and Other Noncurrent Liabilities		2,105	2,109
Commitments and Contingent Liabilities
Equity
Common stock	[4]	308	308
Additional paid-in capital		3,019	3,056
Earnings reinvested		1,014	935
Total Equity		4,341	4,299
Total Liabilities and Equity		10,161	10,073
Kentucky Utilities Co [Member] | Related Party
Current Liabilities
Accounts payable		129	100
Kentucky Utilities Co [Member] | Nonrelated Party
Current Liabilities
Accounts payable		$ 89	$ 96

[1] 1,560,000 shares authorized, 770,415 shares issued and 739,066 shares outstanding at March 31, 2025. 1,560,000 shares authorized, 770,215 shares issued and 738,033 shares outstanding at December 31, 2024.

[2] 170,000 shares authorized; 66,368 shares issued and outstanding at March 31, 2025 and December 31, 2024.

[3] 75,000 shares authorized; 21,294 shares issued and outstanding at March 31, 2025 and December 31, 2024.

[4] 80,000 shares authorized; 37,818 shares issued and outstanding at March 31, 2025 and December 31, 2024.

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CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - USD ($) shares in Thousands, $ in Millions	Mar. 31, 2025	Dec. 31, 2024
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 166	$ 147
Unbilled revenues, reserve	4	6
Reserve for accounts receivable (noncurrent)	$ 2	$ 1
Equity
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock shares authorized (in shares)	1,560,000	1,560,000
Common stock shares issued (in shares)	770,415	770,215
Common stock shares outstanding (in shares)	739,066	738,033
PPL Electric Utilities Corp [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 39	$ 37
Unbilled revenues, reserve	2	3
Reserve for accounts receivable (noncurrent)	$ 2	$ 1
Equity
Common stock, no par value (in dollars per share)	$ 0	$ 0
Common stock shares authorized (in shares)	170,000	170,000
Common stock shares issued (in shares)	66,368	66,368
Common stock shares outstanding (in shares)	66,368	66,368
Louisville Gas And Electric Co [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 5	$ 3
Unbilled revenues, reserve	$ 0	$ 0
Equity
Common stock, no par value (in dollars per share)	$ 0	$ 0
Common stock shares authorized (in shares)	75,000	75,000
Common stock shares issued (in shares)	21,294	21,294
Common stock shares outstanding (in shares)	21,294	21,294
Kentucky Utilities Co [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 2	$ 2
Unbilled revenues, reserve	$ 0	$ 0
Equity
Common stock, no par value (in dollars per share)	$ 0	$ 0
Common stock shares authorized (in shares)	80,000	80,000
Common stock shares issued (in shares)	37,818	37,818
Common stock shares outstanding (in shares)	37,818	37,818

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CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (Unaudited) - USD ($) shares in Thousands, $ in Millions	Total		Common Stock [Member]		Additional Paid-in Capital [Member]	Earnings Reinvested [Member]		Accumulated Other Comprehensive Loss [Member]	Treasury Stock, Common	PPL Electric Utilities Corp [Member]		PPL Electric Utilities Corp [Member] Common Stock [Member]		PPL Electric Utilities Corp [Member] Additional Paid-in Capital [Member]	PPL Electric Utilities Corp [Member] Earnings Reinvested [Member]	Louisville Gas And Electric Co [Member]		Louisville Gas And Electric Co [Member] Common Stock [Member]		Louisville Gas And Electric Co [Member] Additional Paid-in Capital [Member]	Louisville Gas And Electric Co [Member] Earnings Reinvested [Member]	Kentucky Utilities Co [Member]		Kentucky Utilities Co [Member] Common Stock [Member]		Kentucky Utilities Co [Member] Additional Paid-in Capital [Member]	Kentucky Utilities Co [Member] Earnings Reinvested [Member]
Total Equity	$ 13,933		$ 8		$ 12,326	$ 2,710		$ (163)	$ (948)	$ 5,903		$ 364		$ 4,040	$ 1,499	$ 3,172		$ 424		$ 1,993	$ 755	$ 4,152		$ 308		$ 3,033	$ 811
Dividends Declared Per Share of Common Stock (in dollars per share)	$ 0.2575
Balance at beginning of period - shares at Dec. 31, 2023			737,130	[1]								66,368	[2]					21,294	[3]					37,818	[4]
Stock Issued During Period, Value, Treasury Stock Reissued	$ 17				0				$ 17
Stock Issued During Period, Shares, Treasury Stock Reissued									606
APIC, Share-Based Payment Arrangement, Recognition and Exercise	(12)				(12)
Net income (loss)	307					307				149	[5]				149	93					93	108	[6]				108
Contributions from parent										675				675
Payments of Capital Distribution																(51)				(51)		(50)				(50)
Dividends and dividend equivalents	(189)	[7]				(189)	[7]			(88)					(88)	(37)					(37)	(47)					(47)
Other comprehensive income (loss)	2							2
Balance at end of period - shares at Mar. 31, 2024			737,736	[1]								66,368	[2]					21,294	[3]					37,818	[4]
Total Equity	14,058		$ 8		12,314	2,828		(161)	$ (931)	6,639		$ 364		4,715	1,560	3,177		$ 424		1,942	811	4,163		$ 308		2,983	872
Total Equity	$ 14,077		$ 8		12,346	2,835		(184)	(928)	$ 6,730		$ 364		4,668	1,698	$ 3,271		$ 424		1,982	865	$ 4,299		$ 308		3,056	935
Dividends Declared Per Share of Common Stock (in dollars per share)	$ 0.2725
Balance at beginning of period - shares at Dec. 31, 2024	738,033		738,033	[1]						66,368		66,368	[2]			21,294		21,294	[3]			37,818		37,818	[4]
Common stock shares issued			200
Common stock issued	$ 0				0
Stock Issued During Period, Value, Treasury Stock Reissued	24				0				$ 24
Stock Issued During Period, Shares, Treasury Stock Reissued									833
APIC, Share-Based Payment Arrangement, Recognition and Exercise	(16)				(16)
Net income (loss)	414					414				$ 184	[5]				184	$ 105	[8]				105	$ 125	[6]				125
Contributions from parent										0
Payments of Capital Distribution																(55)				(55)		(37)				(37)
Dividends and dividend equivalents	(202)	[7]				(202)	[7]			$ (88)					(88)	$ (43)					(43)	$ (46)					(46)
Other comprehensive income (loss)	$ 0							0
Balance at end of period - shares at Mar. 31, 2025	739,066		739,066							66,368		66,368	[2]			21,294		21,294	[3]			37,818		37,818	[4]
Total Equity	$ 14,297		$ 8		$ 12,330	$ 3,047		$ (184)	$ (904)	$ 6,826		$ 364		$ 4,668	$ 1,794	$ 3,278		$ 424		$ 1,927	$ 927	$ 4,341		$ 308		$ 3,019	$ 1,014

[1] Shares in thousands. Each share entitles the holder to one vote on any question presented at any shareowners' meeting.

[2] Shares in thousands. All common shares of PPL Electric stock are owned by PPL Energy Holdings.

[3] Shares in thousands. All common shares of LG&E stock are owned by LKE.

[4] Shares in thousands. All common shares of KU stock are owned by LKE.

[5] Net income equals comprehensive income.

[6] Net income equals comprehensive income.

[7] Dividends declared per share of common stock were $0.2725 and $0.2575 for the three months ended March 31, 2025 and March 31, 2024.

[8] Net income equals comprehensive income.

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CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (Unaudited) (Parenthetical)	3 Months Ended
	Mar. 31, 2025 vote $ / shares	Mar. 31, 2024 vote $ / shares
Vote per share of PPL's common stock | vote	1	1
Dividends Declared Per Share of Common Stock (in dollars per share) | $ / shares	$ 0.2725	$ 0.2575

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Segment and Related Information

3 Months Ended

Mar. 31, 2025

Segment Reporting [Abstract]

Segment and Related Information

2. Segment and Related Information

(PPL)

PPL is organized into three segments, broken down by geographic location: Kentucky Regulated, Pennsylvania Regulated and Rhode Island Regulated.

The Kentucky Regulated segment primarily consists of the regulated electricity generation, transmission and distribution operations conducted by LG&E and KU, as well as LG&E's regulated transmission, distribution and sale of natural gas.

The Pennsylvania Regulated segment consists of the regulated electricity transmission and distribution operations of PPL Electric.

The Rhode Island Regulated segment consists of the regulated electricity transmission and distribution and natural gas distribution operations of RIE.

"Corporate and Other" primarily consists of corporate level financing costs, certain unallocated costs and certain non-recoverable costs incurred in conjunction with the acquisition of Rhode Island Energy. "Corporate and Other" is presented to reconcile segment information to PPL's consolidated results and is not a reportable segment.

The table below provides information about PPL’s segments and includes the reconciliation to consolidated net income for the three months ended March 31, 2025:

	Kentucky Regulated		Pennsylvania Regulated		Rhode Island Regulated		Total
Operating Revenues from external customers (a)	$	1,059	$	819	$	626	$	2,504
Reconciliation of revenue
Corporate and Other revenues							—
Total consolidated revenues							$	2,504
Less:
Fuel	234		—		—		234
Energy Purchases	96		229		235		560
Other operation and maintenance	200		162		200		562
Depreciation	176		102		42		320
Taxes, other than income	25		41		47		113
Other (income) expense - net	(8)		(11)		(7)		(26)
Interest (income) from affiliate	—		(2)		(2)		(4)
Interest expense	60		60		23		143
Income taxes	53		54		18		125
Segment net income	$	223	$	184	$	70	$	477
Reconciliation of segment profit or loss to consolidated net income
Corporate and Other net loss							(63)
Net Income							$	414

(a)See Note 3 for additional information on Operating Revenues.

Other information for the segments and reconciliation to PPL's Consolidated results for the three months ended March 31, 2025 are as follows:

	Kentucky Regulated		Pennsylvania Regulated		Rhode Island Regulated		Total Segments		Corporate and Other		Consolidated Total
Other Segment Disclosures
Amortization (a)	$	5	$	11	$	—	$	16	$	4	$	20
Deferred income taxes and investment tax credits (b)	8		20		(7)		21		17		38
Expenditures for long lived assets	290		328		172		790		3		793

(a)Represents non-cash expense items that include amortization of operating lease right-of-use assets, regulatory assets and liabilities, debt discounts and premiums and debt issuance costs.

(b)Represents a non-cash expense item that is also included in "Income Taxes."

The table below provides information about PPL’s segments and includes the reconciliation to consolidated net income for the three months ended March 31, 2024:

	Kentucky Regulated		Pennsylvania Regulated		Rhode Island Regulated		Total
Operating Revenues from external customers (a)	$	984	$	770	$	549	$	2,303
Reconciliation of revenue
Corporate and Other revenues							1
Total consolidated revenues							$	2,304
Less:
Fuel	209		—		—		209
Energy Purchases	77		214		229		520
Other operation and maintenance	202		181		156		539
Depreciation	176		99		41		316
Taxes, other than income	25		36		27		88
Other (income) expense - net	(3)		(9)		(7)		(19)
Interest (income) from affiliate	—		(10)		—		(10)
Interest expense	60		62		24		146
Income taxes	48		48		15		111
Segment net income	$	190	$	149	$	64	$	403
Reconciliation of segment profit or loss to consolidated net income
Corporate and Other net loss							(96)
Net Income							$	307

(a)See Note 3 for additional information on Operating Revenues.

Other information for the segments and reconciliation to PPL's Consolidated results for the three months ended March 31, 2024 are as follows:

	Kentucky Regulated		Pennsylvania Regulated		Rhode Island Regulated		Total Segments		Corporate and Other		Consolidated Total
Other Segment Disclosures
Amortization (a)	$	8	$	12	$	—	$	20	$	4	$	24
Deferred income taxes and investment tax credits (b)	4		32		18		54		18		72
Expenditures for long lived assets	241		229		125		595		1		596

(a)Represents non-cash expense items that include amortization of operating lease right-of-use assets, regulatory assets and liabilities, debt discounts and premiums and debt issuance costs.

(b)Represents a non-cash expense item that is also included in "Income Taxes."

The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated Balance Sheets as of:

	March 31, 2025		December 31, 2024
Total Assets
Kentucky Regulated	$	17,789	$	17,626
Pennsylvania Regulated	15,654		15,475
Rhode Island Regulated	7,194		7,055
Corporate and Other (a)	1,172		913
Total	$	41,809	$	41,069

(a)Primarily consists of unallocated items, including cash, PP&E, goodwill and the elimination of inter-segment transactions.

(PPL Electric)

PPL Electric has two operating segments, distribution and transmission, which are aggregated into a single reportable segment.

The measure of segment assets is reported on PPL Electric's Balance Sheets as total consolidated assets. The measures of significant segment expenses are reported on PPL Electric's Statements of Income. The measures of significant non-cash segment expenses as well as expenditures for long lived assets are reported on PPL Electric's Statements of Cash Flows.

(LG&E and KU)

Each of LG&E and KU operates as a single operating and reportable segment.

The measures of segment assets are reported on the Balance Sheets of LG&E and KU as total assets. The measures of significant segment expenses are reported on the Statements of Income of LG&E and KU. The measures of significant non-cash segment expenses as well as expenditures for long lived assets are reported on the Statements of Cash Flows of LG&E and KU.

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Earnings Per Share

3 Months Ended

Mar. 31, 2025

Earnings Per Share [Abstract]

Earnings Per Share

4. Earnings Per Share

(PPL)

Basic EPS is computed by dividing income available to PPL common shareowners by the weighted-average number of common shares outstanding during the applicable period. Diluted EPS is computed by dividing income available to PPL common shareowners by the weighted-average number of common shares outstanding, increased by the number of incremental shares that would be outstanding if potentially dilutive share-based payment awards were converted to common shares as calculated using the Two-Class Method or Treasury Stock Method. Incremental non-participating securities that have a dilutive impact are detailed in the table below. In 2025, these securities also included forward sales of PPL common stock issued through an ATM Program. See Note 7 for additional information on the ATM Program. The forward sale agreements are dilutive under the Treasury Stock Method to the extent the average stock price of PPL's common shares exceeds the forward sale price prescribed in the agreements.

Reconciliations of the amounts of income and shares of PPL common stock (in thousands) for the periods ended March 31 used in the EPS calculation are:

	Three Months
	2025		2024
Income (Numerator)
Net income attributable to PPL	$	414	$	307
Less amounts allocated to participating securities	1		—
Net income available to PPL common shareowners - Basic and Diluted	$	413	$	307
Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS	738,691		737,512
Add: Dilutive share-based payment awards (a)	2,709		1,308
Weighted-average shares - Diluted EPS	741,400		738,820
Basic and Diluted EPS
Net Income available to PPL common shareowners	$	0.56	$	0.42

(a)    The Treasury Stock Method was applied to non-participating share-based payment awards.

For the periods ended March 31, PPL issued common stock related to stock-based compensation plans as follows (in thousands):

	Three Months
	2025	2024
DRIP	200	—

For the periods ended March 31, the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive.

	Three Months
	2025	2024
Stock-based compensation awards	175	—
Forward sale agreements	2,033	—

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Income Taxes

3 Months Ended

Mar. 31, 2025

Income Tax Disclosure [Abstract]

Income Taxes

5. Income Taxes

Reconciliations of income tax expense (benefit) for the periods ended March 31 are as follows.

(PPL)
	Three Months
	2025		2024
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	108	$	81
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	20		17
Utility rate-making tax adjustments (a)	(10)		(5)
Amortization of excess deferred federal and state income taxes	(15)		(13)
Other	(1)		1
Total increase (decrease)	(6)		—
Total income tax expense (benefit)	$	102	$	81

(a)     Primarily consists of tax impacts of AFUDC equity and related depreciation across PPL's regulated utility subsidiaries and flow through tax impacts of Pennsylvania utility ratemaking. Flow through occurs when the regulator excludes deferred tax expense or benefit from recoverable costs when determining income tax expense.

(PPL Electric)
	Three Months
	2025		2024
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	50	$	41
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	15		14
Utility rate-making tax adjustments (a)	(6)		(4)
Amortization of excess deferred federal and state income taxes	(3)		(2)
Other	(2)		(1)
Total increase (decrease)	4		7
Total income tax expense (benefit)	$	54	$	48

(a)     Primarily consists of tax impacts of AFUDC equity and related depreciation and flow through tax impacts of Pennsylvania utility ratemaking. Flow through occurs when the regulator excludes deferred tax expense or benefit from recoverable costs when determining income tax expense.

(LG&E)
	Three Months
	2025		2024
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	27	$	25
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	5		4
Amortization of excess deferred federal and state income taxes	(4)		(3)
Other	(2)		(2)
Total increase (decrease)	(1)		(1)
Total income tax expense (benefit)	$	26	$	24

(KU)
	Three Months
	2025		2024
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	33	$	28
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	6		5
Amortization of excess deferred federal and state income taxes	(5)		(5)
Other	(3)		(1)
Total increase (decrease)	(2)		(1)
Total income tax expense (benefit)	$	31	$	27

Other

IRS Revenue Procedure 2023-15 (PPL and LG&E)

On April 14, 2023, the IRS issued Revenue Procedure 2023-15, which provides a safe harbor method of accounting that taxpayers may use to determine whether expenses to repair, maintain, replace, or improve natural gas transmission and distribution property must be capitalized for tax purposes. PPL and LG&E are currently reviewing the revenue procedure to determine what impact the guidance may have on their financial statements.

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Utility Rate Regulation

3 Months Ended

Mar. 31, 2025

Regulated Operations [Abstract]

Utility Rate Regulation

6. Utility Rate Regulation

(All Registrants)

The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations.

	PPL				PPL Electric				LG&E				KU
	March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024
Current Regulatory Assets:
Rate adjustment mechanisms	$	74	$	95	$	—	$	—	$	—	$	—	$	—	$	—
Renewable energy certificates	16		14		—		—		—		—		—		—
Storm damage expense rider	46		68		46		68		—		—		—		—
Gas supply clause	23		3		—		—		23		3		—		—
Transmission service charge	35		44		—		27		—		—		—		—
Transmission formula rate	13		14		3		2		—		—		—		—
DSIC	9		8		9		8		—		—		—		—
TCJA customer refund and recovery	28		21		28		21		—		—		—		—
ISR deferral	10		22		—		—		—		—		—		—
Gas line tracker	5		4		—		—		5		4		—		—
Other	15		27		8		7		3		1		—		1
Total current regulatory assets	$	274	$	320	$	94	$	133	$	31	$	8	$	—	$	1

	PPL				PPL Electric				LG&E				KU
	March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024
Noncurrent Regulatory Assets:
Defined benefit plans	$	962	$	967	$	472	$	473	$	223	$	226	$	147	$	149
Plant outage costs	29		30		—		—		7		7		22		23
Net metering	147		147		—		—		—		—		—		—
Environmental cost recovery	96		96		—		—		—		—		—		—
Storm costs	116		113		41		22		22		20		36		29
Unamortized loss on debt	20		20		3		3		9		9		6		6
Terminated interest rate swaps	51		53		—		—		30		31		21		22
Accumulated cost of removal of utility plant	165		173		165		173		—		—		—		—
AROs	278		280		—		—		76		75		202		205
Retired asset recovery	83		83		—		—		83		83		—		—
Gas line inspections	24		24		—		—		22		22		2		2
Advanced metering infrastructure	31		28		—		—		15		14		16		14
Other	47		46		4		2		4		4		8		8
Total noncurrent regulatory assets	$	2,049	$	2,060	$	685	$	673	$	491	$	491	$	460	$	458

	PPL				PPL Electric				LG&E				KU
	March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024
Current Regulatory Liabilities:
Generation supply charge	$	45	$	52	$	45	$	52	$	—	$	—	$	—	$	—
Environmental cost recovery	9		12		—		—		4		6		5		6
Rate adjustment mechanisms	63		71		—		—		—		—		—		—
Energy efficiency	24		25		—		—		—		—		—		—
DSM	24		17		—		—		10		7		14		10
Revenue decoupling mechanism	40		10		—		—		—		—		—		—
Deferred revenue	25		—		—		—		—		—		—		—
Derivative instruments	15		—		—		—		—		—		—		—
Other	29		36		9		5		2		1		7		6
Total current regulatory liabilities	$	274	$	223	$	54	$	57	$	16	$	14	$	26	$	22
Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	1,027	$	1,022	$	—	$	—	$	318	$	314	$	409	$	408
Net deferred taxes	1,875		1,899		729		739		434		439		491		498
Defined benefit plans	296		294		106		100		24		24		66		65
Terminated interest rate swaps	54		54		—		—		27		27		27		27
Energy efficiency	28		16		—		—		—		—		—		—
Other	58		50		—		—		11		11		14		11
Total noncurrent regulatory liabilities	$	3,338	$	3,335	$	835	$	839	$	814	$	815	$	1,007	$	1,009

Regulatory Matters

Rhode Island Activities (PPL)

FY 2026 Gas ISR Plan

On December 31, 2024, RIE filed its FY 2026 Gas ISR Plan with the RIPUC with a budget that included $187 million of capital investment spend and up to $15 million of additional contingency plan spend in connection with the PHMSA's potential

enactment of regulations during FY 2026 that, if enacted, would significantly alter RIE's leak detection and repair obligations under federal regulations. The Plan also included proposed spending on curb-to-curb paving of $22 million. On March 28, 2025, the RIPUC approved a FY 2026 Gas ISR Plan of $165 million of which $147 million is for capital investment spend and $18 million spend for paving costs as operations and maintenance (O&M), plus a potential additional $15 million is available if the above-mentioned regulations are implemented by the PHMSA. On March 31, 2025, the RIPUC approved RIE's compliance filing for rates effective April 1, 2025.

FY 2026 Electric ISR Plan

On December 23, 2024, RIE filed its FY 2026 Electric ISR Plan with the RIPUC with a budget that included $248 million of capital investment spend (including $88 million for Advanced Metering Functionality (AMF)), $14 million of vegetation operation and maintenance (O&M) spend and $1 million of Other O&M spend. On March 28, 2025, the RIPUC approved a FY 2026 Electric ISR Plan of $219 million for capital investment spend (including $88 million for AMF), $14 million for vegetation management O&M spend, and $1 million for Other O&M spend. On March 31, 2025, the RIPUC approved RIE's compliance filing for rates effective April 1, 2025.

Kentucky Activities

(PPL, LG&E and KU)

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 are intended to serve anticipated load growth, including from potential data center demand in LG&E's or KU’s service territory. The proposals do 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 are currently expected to be $3.7 billion over the 2025 to 2031 period. The application includes proposals:

•to build a 645 MW natural gas combined cycle (NGCC) generation unit at KU's E.W. Brown station,

•to build a 645 MW NGCC generation unit at LG&E's Mill Creek station,

•to build a four-hour 400 MW (1,600 MWh total) battery energy storage system (BESS) at LG&E's Cane Run station, and

•to build a selective catalytic reduction (SCR) environmental facility at KU’s Ghent station 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 NGCC unit is in addition to a new NGCC unit currently under construction at that location.

The filing also notes projected in service dates for the projects, including the E.W. Brown NGCC unit in 2030, the Mill Creek NGCC unit in 2031, the Cane Run BESS in 2028 and the Ghent SCR facility in 2028.

LG&E and KU anticipate a ruling from the KPSC during the fourth quarter of 2025. LG&E and KU cannot predict the outcome of the proceedings.

Kentucky January 2025 Storm

In January 2025, LG&E and KU experienced snow, ice, sleet and freezing rain in their service territories, resulting in substantial damage to certain of LG&E's and KU's assets. On January 31, 2025, LG&E and KU submitted a filing with the KPSC requesting regulatory asset treatment of the extraordinary operations and maintenance (O&M) expenses portion of the costs incurred related to the storm. On March 19, 2025, the KPSC issued an order authorizing LG&E and KU to establish, for accounting purposes only, regulatory assets based on the jurisdictional incremental costs of extraordinary O&M expense incurred by LG&E and KU as a result of the 2025 Winter Storm, with recovery amounts and amortization thereof to be determined in subsequent base rate proceedings. LG&E and KU cannot predict the outcome of this matter. As of March 31, 2025, LG&E and KU recorded regulatory assets related to the storm of $2 million and $7 million.

Mill Creek Unit 1 and Unit 2 Retired Asset Recovery (RAR) Application (PPL and LG&E)

In 2023, the KPSC issued an order approving, among other items, the requested retirement of Mill Creek Units 1 and 2.

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 rider. LG&E expects these costs to be approximately $125 million and proposed to begin application of the RAR rider with bills issued in May 2025. On February 24, 2025, the KPSC issued an order approving LG&E’s cost recovery for Mill Creek Unit 1 under the RAR rider.

Mill Creek Unit 2 is expected to be retired in 2027. LG&E anticipates the recovery of associated costs, including the remaining net book value, for Mill Creek Unit 2 through the RAR rider. The remaining net book value of Mill Creek Unit 2 was approximately $215 million at March 31, 2025 and LG&E is continuing to depreciate using the current approved rates through its retirement date in 2027. LG&E expects to reclassify the net book value remaining at retirement, which is expected to total approximately $161 million, to a regulatory asset to be amortized over a period of ten years in accordance with the RAR. There can be no assurance that these costs will be recovered in the amounts or at the time that LG&E expects.

Pennsylvania Activities (PPL and PPL Electric)

DSIC Petition

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%.

Federal Matters

FERC Transmission Rate Filing (PPL, LG&E and KU)

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. Oral argument before the D.C. Circuit Court of Appeals occurred on January 21, 2025. 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 base rates increases, provided, however, that increases associated with the FERC's May 18, 2023 order are expected to be subject to future rate proceedings.

Recovery of Transmission Costs (PPL)

Until December 2022, RIE's transmission facilities were operated in combination with the transmission facilities of National Grid USA's New England affiliates, Massachusetts Electric Company (MECO) and New England Power (NEP), as a single integrated system with NEP designated as the combined operator. As of January 1, 2023, RIE operates its own transmission facilities. NE-ISO allocates RIE's costs among transmission customers in New England, in accordance with the ISO Open Access Transmission Tariff (ISO-NE OATT). According to the FERC orders, RIE is compensated for its actual monthly transmission costs, with its authorized maximum return on equity (ROE) of 11.74% on its transmission assets.

The ROE for transmission rates under the ISO-NE OATT is the subject of four complaints that are pending before the FERC. On October 16, 2014, the FERC issued an order on the first complaint, Opinion No. 531-A, resetting the base ROE applicable to transmission assets under the ISO-NE OATT from 11.14% to 10.57% effective as of October 16, 2014 and establishing a maximum ROE of 11.74%. On April 14, 2017, this order was vacated and remanded by the D. C. Circuit Court of Appeals (Court of Appeals). After the remand, the FERC issued an order on October 16, 2018 applicable to all four pending cases where it proposed a new base ROE methodology that, with subsequent input and support from the New England Transmission Owners (NETO), yielded a base ROE of 10.41%. Subsequent to the FERC's October 2018 order in the New England Transmission Owners cases, the FERC further refined its ROE methodology in another proceeding and has applied that refined methodology to transmission owners’ ROEs in other jurisdictions, and the NETOs filed further information in the New England matters to distinguish their case. Those determinations in other jurisdictions have recently been vacated and remanded back to the FERC for further proceedings by the D.C. Circuit Court of Appeals. The proceeding and the final base rate ROE determination in the New England matters remain open, pending a final order from the FERC. PPL cannot predict the outcome of this matter, and an estimate of the impact cannot be determined.

Other

Purchase of Receivables Program

(PPL and PPL Electric)

In accordance with RIPUC-approved and PAPUC-approved purchase of accounts receivable programs, RIE and PPL Electric purchase certain accounts receivable from alternative electricity suppliers at a discount, which reflects a provision for uncollectible accounts. The alternative electricity suppliers have no continuing involvement or interest in the purchased accounts receivable. Accounts receivable that are acquired are initially recorded at fair value on the date of acquisition.

During the three months ended March 31, 2025 and 2024, RIE purchased $87 million and $51 million of accounts receivable from alternative suppliers.

During the three months ended March 31, 2025 and 2024, PPL Electric purchased $466 million and $419 million of accounts receivable from alternative suppliers.

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Financing Activities

3 Months Ended

Mar. 31, 2025

Debt Disclosure [Abstract]

Financing Activities

7. Financing Activities

Credit Arrangements and Short-term Debt

(All Registrants)

The Registrants maintain credit facilities to enhance liquidity, provide credit support and provide a backstop to commercial paper programs. For reporting purposes, on a consolidated basis, the credit facilities and commercial paper programs of PPL Electric, LG&E and KU are attributable to PPL. The amounts listed in the borrowed column below are recorded as "Short-term debt" on the Balance Sheets. The following credit facilities were in place at:

	March 31, 2025									December 31, 2024
	Expiration Date	Capacity		Borrowed		Letters of Credit and Commercial Paper Issued (c)		Unused Capacity		Borrowed		Letters of Credit and Commercial Paper Issued (c)
PPL
PPL Capital Funding (a)
Syndicated Credit Facility (b)	Dec. 2029	$	1,500	$	—	$	427	$	1,073	$	—	$	138
Bilateral Credit Facility	Feb. 2026	100		—		—		100		—		—
Bilateral Credit Facility	Feb. 2026	100		—		55		45		—		15
Total PPL Capital Funding Credit Facilities		$	1,700	$	—	$	482	$	1,218	$	—	$	153
PPL Electric
Syndicated Credit Facility	Dec. 2029	$	750	$	—	$	56	$	694	$	—	$	1
Total PPL Electric Credit Facilities		$	750	$	—	$	56	$	694	$	—	$	1
LG&E
Syndicated Credit Facility	Dec. 2029	$	600	$	—	$	89	$	511	$	—	$	25
Total LG&E Credit Facilities		$	600	$	—	$	89	$	511	$	—	$	25
KU
Syndicated Credit Facility	Dec. 2029	$	600	$	—	$	209	$	391	$	—	$	140
Total KU Credit Facilities		$	600	$	—	$	209	$	391	$	—	$	140

(a)PPL Capital Funding's obligations are fully and unconditionally guaranteed by PPL.

(b)In January 2025, PPL Capital Funding increased the borrowing capacity of this facility from $1.25 billion to $1.50 billion. At March 31, 2025, the facility included a $250 million borrowing sublimit for RIE and a $1.25 billion sublimit for PPL Capital Funding. At December 31, 2024, the facility included a $250 million borrowing sublimit for RIE and a $1 billion borrowing sublimit for PPL Capital Funding. RIE’s borrowing sublimit is adjustable, at the borrowers’ option, from $0 to $600 million, with the remaining balance available under the facility allocated to PPL Capital Funding. At March 31, 2025, PPL Capital Funding had $427 million of commercial paper outstanding and RIE had no commercial paper outstanding. At December 31, 2024, PPL Capital Funding had $138 million of commercial paper outstanding and RIE had no commercial paper outstanding. RIE's obligations under the facility are not guaranteed by PPL.

(c)Commercial paper issued reflects the undiscounted face value of the issuance.

(PPL)

In January 2025, PPL Capital Funding amended its existing $1.25 billion syndicated credit facility to extend the termination date from December 6, 2028 to December 6, 2029 and to increase the borrowing capacity under the facility to $1.50 billion.

(PPL and PPL Electric)

In January 2025, PPL Electric amended its existing $650 million syndicated credit facility to extend the termination date from December 6, 2028 to December 6, 2029 and to increase the borrowing capacity under the facility to $750 million.

(PPL and LG&E)

In January 2025, LG&E amended its existing $500 million syndicated credit facility to extend the termination date from December 6, 2028 to December 6, 2029 and to increase the borrowing capacity under the facility to $600 million.

(PPL and KU)

In January 2025, KU amended its existing $400 million syndicated credit facility to extend the termination date from December 6, 2028 to December 6, 2029 and to increase the borrowing capacity under the facility to $600 million.

(All Registrants)

The Registrants maintain commercial paper programs to provide an additional financing source to fund short-term liquidity needs. 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:

	March 31, 2025							December 31, 2024
	Weighted - Average Interest Rate	Capacity		Commercial Paper Issuances (c)		Unused Capacity		Weighted - Average Interest Rate	Commercial Paper Issuances (c)
PPL Capital Funding (a)(b)	4.71%	$	1,350	$	427	$	923	4.76%	$	138
RIE (b)		250		—		250			—
PPL Electric	4.68%	650		55		595			—
LG&E	4.67%	500		89		411		4.72%	25
KU	4.71%	400		209		191		4.71%	140
Total		$	3,150	$	780	$	2,370		$	303

(a)PPL Capital Funding's obligations are fully and unconditionally guaranteed by PPL.

(b)Issuances under the PPL Capital Funding and RIE commercial paper programs are supported by the PPL Capital Funding syndicated credit facility. At March 31, 2025, the borrowing sublimits were $250 million for RIE and $1.25 billion for PPL Capital Funding. At December 31, 2024, the borrowing sublimits were $250 million for RIE and $1 billion for PPL Capital Funding. PPL Capital Funding’s commercial paper program is also backed by a separate bilateral credit facility for $100 million.

(c)Commercial paper issued reflects the undiscounted face value of the issuance.

(PPL Electric, LG&E, and KU)

See Note 11 for discussion of intercompany borrowings.

(PPL)

Equity Securities

ATM Program

In February 2025, PPL entered into an equity distribution agreement, pursuant to which PPL may sell, from time to time, up to an aggregate of $2 billion of its common stock through an ATM Program, including an optional forward sales component. Each forward contract under the agreement must be settled within 24 months. The compensation paid to the selling agents by PPL may be up to 2% of the gross offering proceeds of the shares. During the three months ended March 31, 2025, PPL entered into a forward contract to sell approximately 2.0 million shares of its common stock at an initial forward price of $34.49 per share. The forward sale price may be adjusted based on changes in daily interest rates, for certain stock loan fees as determined by a third-party agent, and will be subject to predetermined reductions based on expected dividends. This forward contract must be settled on or before December 30, 2025. PPL may elect, at its discretion, to physically settle, net share settle or net cash settle the forward contracts. At March 31, 2025, PPL could have settled the forward sale contract with physical delivery of 2.0 million shares of common stock for proceeds of approximately $70 million. In April 2025, PPL entered into forward contracts to sell approximately 2.8 million additional shares at a blended initial forward price of approximately $35.22 per share. The forward contracts under the ATM program are classified as equity transactions.

Dividends

In February 2025, PPL declared a quarterly cash dividend on its common stock, payable April 1, 2025, of 27.25 cents per share (equivalent to $1.09 per annum).

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Defined Benefits

3 Months Ended

Mar. 31, 2025

Retirement Benefits [Abstract]

Defined Benefits

9. Defined Benefits

(PPL)

Certain net periodic defined benefit costs are applied to accounts that are further distributed among capital, expense, regulatory assets and regulatory liabilities, including certain costs allocated to applicable subsidiaries for plans sponsored by PPL Services and LKE. Following are the net periodic defined benefit costs (credits) of the plans sponsored by PPL and its subsidiaries for the periods ended March 31:

	Pension Benefits
	Three Months
	2025		2024
PPL
Service cost	$	8	$	9
Interest cost	45		46
Expected return on plan assets	(72)		(75)
Amortization of:
Prior service cost	—		1
Actuarial loss	5		2
Net periodic defined benefit costs (credits)	$	(14)	$	(17)

	Other Postretirement Benefits
	Three Months
	2025		2024
PPL
Service cost	$	2	$	1
Interest cost	7		7
Expected return on plan assets	(8)		(7)
Amortization of:
Actuarial loss	(1)		(1)
Net periodic defined benefit costs (credits)	$	—	$	—

(All Registrants)

The non-service cost components of net periodic defined benefit costs (credits) (interest cost, expected return on plan assets, amortization of prior service cost and amortization of actuarial gain and loss) are presented in "Other Income (Expense) - net" on the Statements of Income. See Note 12 for additional information.

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2025

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

10. Commitments and Contingencies

Legal Matters

(All Registrants)

PPL and its subsidiaries are involved in legal proceedings, claims and litigation in the ordinary course of business. PPL and its subsidiaries cannot predict the outcome of such matters, or whether such matters may result in material liabilities, unless otherwise noted.

Narragansett Electric Litigation (PPL)

Energy Efficiency Programs Investigation

Narragansett Electric, while under the ownership of National Grid, performed an internal investigation into conduct associated with its energy efficiency programs. On June 27, 2022, the RIPUC opened a new docket (RIPUC Docket No. 22-05-EE) to investigate RIE’s actions and the actions of employees of National Grid USA and affiliates during the time RIE was a National Grid USA affiliate being provided services by National Grid USA Service Company, Inc. relating to the manipulation of the reporting of invoices affecting the calculation of past energy efficiency shareholder incentives and the resulting impact on customers. The Rhode Island Attorney General and National Grid USA intervened in the docket and the Rhode Island Division of Public Utilities and Carriers (the Division) is an automatic party in the docket.

On February 21, 2025, the Division filed testimony confirming its initial testimony that $12 million is the appropriate amount to be refunded to the energy efficiency program. On March 4, 2025, a Settlement Agreement between RIE, the Division, and the Rhode Island Attorney General was filed with the RIPUC requiring refunds of $10 million. Of this amount, $2 million has already been refunded through the energy efficiency mechanism with the remaining $8 million to reduce the storm cost regulatory asset recorded on PPL's balance sheet. The settlement also included reimbursement of minor consulting fees and various other compliance actions. On March 5, 2025, the RIPUC approved the Settlement Agreement.

E.W. Brown Environmental Assessment (PPL and KU)

KU is undertaking extensive remedial measures at the E.W. Brown plant including closure of the former ash pond, implementation of a groundwater remedial action plan and performance of a corrective action plan including aquatic study of adjacent surface waters and risk assessment. The aquatic study and risk assessment are being undertaken pursuant to a 2017 Agreed Order with the Kentucky Energy and Environment Cabinet (KEEC). KU conducted sampling of Herrington Lake in 2017 and 2018. In June 2019, KU submitted to the KEEC the required aquatic study and risk assessment, conducted by an independent third-party consultant, finding that discharges from the E.W. Brown plant have not had any significant impact on Herrington Lake and that the water in the lake is safe for recreational use and meets safe drinking water standards. On May 31, 2021, the KEEC approved the report and released a response to public comments. On August 6, 2021, KU submitted a Supplemental Remedial Alternatives Analysis report to the KEEC that outlines proposed additional fish, water, and sediment testing. On February 18, 2022, the KEEC provided approval to KU to proceed with the proposed sampling, which commenced in the spring of 2022. On November 17, 2022, KU submitted a Supplemental Performance Monitoring Report to the KEEC finding that there are no significant unaddressed risks to human health or the environment at the plant. KU revised the Supplemental Performance Monitoring Report on June 8, 2023, in response to KEEC comments from April 24, 2023. On September 1, 2023, the KEEC requested KU to propose additional monitoring or remedial measures. KU submitted a revised Supplemental Performance Monitoring and Corrective Action Completion on December 28, 2023. In August 2024, KU submitted a proposed environmental covenant to the KEEC specifying certain site restrictions. Discussions between KU and the KEEC are ongoing, but KU cannot predict the outcome of this matter.

(PPL, LG&E and KU)

EPA Deregulatory Initiative

On March 12, 2025, the EPA announced a plan to reconsider 31 environmental rules including the Section 111 performance standards and emissions limits for greenhouse gases, the endangerment finding for greenhouse gases, the Good Neighbor Plan, the Mercury and Air Toxics Standards, revisions to the fine particulate matter standard, the ELGs, and the CCRs Rule. Supplementing previous Executive Orders directing various regulatory changes, on April 9, 2025, President Trump issued an Executive Order and Presidential Memorandum directing review of existing rules, repeal of unlawful rules, and initiation of a zero-based budgeting process by which certain rules would automatically expire unless extended. While the administration may seek to implement some regulatory changes outside of the rulemaking process, changes to existing rules are generally expected to require formal rulemaking proceedings. Any final EPA actions repealing or revising current rules will likely result in legal challenges. PPL, LG&E, and KU are unable to predict future regulatory changes, if any, that may result from the EPA’s deregulatory plan or the outcome of any associated legal challenges. PPL, LG&E, and KU will closely monitor the ongoing EPA initiative and any related litigation for the impact to our business including planned capital expenditures to comply with the EPA rules.

Water/Waste

ELGs

In 2015, the EPA finalized ELGs for wastewater discharge permits for new and existing steam electricity generating facilities. These guidelines require deployment of additional control technologies providing physical, chemical and biological treatment and mandate operational changes including "zero discharge" requirements for certain wastewaters. The implementation date for individual generating stations was to be determined by the states on a case-by-case basis according to criteria provided by the EPA. In September 2017, the EPA issued a rule to postpone the compliance date for certain requirements. In October 2020, the EPA issued revisions to its best available technology standards for certain wastewaters and potential extensions to compliance dates (the Reconsideration Rule). On May 9, 2024, the EPA issued a final rule modifying the 2020 ELG revisions. The rule increases the stringency of previous control technology and zero discharge requirements, revises certain exemptions for generating units planned for retirement, and requires case-by-case limitations for legacy wastewaters based on the best professional judgment of the state regulators. Legal challenges to the final rule have been consolidated before the U.S. Court of Appeals for the Eighth Circuit. The final rule could potentially result in significant operational changes and additional controls for LG&E and KU plants, but in March 2025 the EPA announced its plan to reconsider the rule. The ELGs are expected to be implemented by the states or applicable permitting authorities in the course of their normal permitting activities. Certain costs are included in the Registrants' capital plans and expected to be recovered from customers through rate recovery mechanisms, but additional costs and recovery will depend on further regulatory developments at the state level.

CCRs

In 2015, the EPA issued a final rule governing management of CCRs, which include fly ash, bottom ash and sulfur dioxide scrubber wastes (2015 CCR Rule). The 2015 CCR Rule imposed extensive new requirements for certain CCR impoundments and landfills, including public notifications, location restrictions, design and operating standards, groundwater monitoring and corrective action requirements, and closure and post-closure care requirements, and specifies restrictions relating to the beneficial use of CCRs. In January 2022, the EPA issued several proposed regulatory determinations, facility notifications, and public announcements which indicate increased scrutiny by the EPA to determine the adequacy of measures taken by facility owners and operators to achieve closure of CCR surface impoundments and landfills. In particular, the agency indicated that it will focus on certain practices which it views as posing a threat of continuing groundwater contamination. On May 8, 2024, the EPA issued a final rule (2024 CCR Rule) establishing regulatory requirements for inactive surface impoundments at inactive electricity generation facilities (legacy impoundments). The 2024 CCR Rule also establishes identification, groundwater monitoring, corrective action, closure, and post-closure care requirements for all CCR management units, as defined in the rule, at regulated CCR facilities regardless of how or when the CCR was placed. The rule also requires LG&E and KU to complete applicability determinations, implement site security measures, initiate weekly inspections and monthly monitoring of the impoundment, create a website, and complete hazard assessments and reports for its legacy impoundments. Additionally, the rule could potentially subject CCR management units that have previously completed remedial action and closure and certain beneficial use projects to additional federal regulatory requirements. Legal challenges to the rule have been filed in the D.C. Circuit Court. In March 2025, the EPA announced its plan to update the rule.

In connection with the 2015 CCR Rule, LG&E and KU recorded adjustments to existing AROs beginning in 2015. In connection with the 2024 CCR Rule, in the second quarter of 2024, LG&E and KU recognized ARO obligations related to preliminary risk assessments, facility evaluations, feasibility studies and sampling. See Note 15 for additional information. The results of those evaluations, as well as future guidance, regulatory determinations, rulemakings, implementation determinations and other developments could potentially require revisions to current LG&E and KU compliance plans including additional monitoring and remediation at surface impoundments and landfills, the cost of which could be material. PPL, LG&E and KU are unable to predict the outcome of the ongoing litigation, rulemaking, and regulatory determinations or potential impacts on current LG&E and KU compliance plans. PPL, LG&E and KU are currently finalizing or revising closure plans and schedules in accordance with applicable regulations and further material changes to AROs, current capital plans or operating costs may be required as estimates are refined based on closure developments, groundwater monitoring results, and regulatory or legal proceedings. Costs relating to this rule are expected to be subject to rate recovery.

LG&E and KU received KPSC approval for a compliance plan associated with the 2015 CCR Rule providing for the closure of impoundments at the Mill Creek, Trimble County, E.W. Brown, and Ghent stations, and construction of process water management facilities at those plants. In addition to the foregoing measures required for compliance with the federal CCR Rule, KU also received KPSC approval for its plans to close impoundments at the retired Green River, Pineville and Tyrone plants to comply with applicable state law. LG&E and KU have completed planned closure measures at most of the subject impoundments and have commenced post closure groundwater monitoring as required at those facilities. LG&E and KU generally expect to complete all impoundment closures within five years of commencement, although a longer period may be required to complete closure of some facilities. Associated costs are expected to be subject to rate recovery.

Superfund and Other Remediation

(All Registrants)

The Registrants are potentially responsible for investigating and remediating contamination under the federal Superfund program and similar state programs. Actions are under way at certain sites including former manufactured gas plants in Pennsylvania, Rhode Island and Kentucky previously owned or operated by, or currently owned by predecessors or affiliates of, PPL subsidiaries.

Depending on the outcome of investigations at identified sites where investigations have not begun or been completed, or developments at sites for which information is incomplete, additional costs of remediation could be incurred. PPL, PPL Electric, LG&E and KU lack sufficient information about such additional sites to estimate any potential liability or range of reasonably possible losses, if any, related to these sites. Such costs, however, are not currently expected to be significant.

The EPA is evaluating the risks associated with polycyclic aromatic hydrocarbons and naphthalene, chemical by-products of manufactured gas plant operations. As a result, individual states may establish stricter standards for water quality and soil cleanup, that could require several PPL subsidiaries to take more extensive assessment and remedial actions at former manufactured gas plants. The Registrants cannot reasonably estimate a range of possible losses, if any, related to these matters.

(PPL and PPL Electric)

PPL Electric is a potentially responsible party for a share of clean-up costs at certain sites. Cleanup actions have been or are being undertaken at these sites as requested by governmental agencies, the costs of which have not been and are not expected to be significant to PPL Electric.

As of March 31, 2025 and December 31, 2024, PPL Electric had a recorded liability of $8 million, representing its best estimate of the probable loss incurred to remediate these sites.

(PPL)

RIE is a potentially responsible party for a share of clean-up costs at certain sites including former manufactured gas plant facilities formerly owned by the Blackstone Valley Gas and Electric Company and the Rhode Island gas distribution assets of the New England Gas division of Southern Union Company and electric operations at certain RIE facilities. RIE is currently investigating and remediating, as necessary, those sites and certain other properties under agreements with governmental agencies, the costs of which have not been and are not expected to be significant to PPL.

As of March 31, 2025 and December 31, 2024, RIE had a recorded liability of $99 million and $98 million, representing its best estimate of the remaining costs of RIE's environmental remediation activities. These undiscounted costs are expected to be incurred over approximately 30 years and generally to be subject to rate recovery. However, remediation costs for each site may be materially higher than estimated, depending on changing technologies and regulatory standards, selected end uses for each site, and actual environmental conditions encountered. RIE has recovered amounts from certain insurers and potentially responsible parties, and, where appropriate, may seek additional recovery from other insurers and potentially responsible parties, but it is uncertain whether, and to what extent, such efforts will be successful.

The RIPUC has approved two settlement agreements that provide for rate recovery of qualified remediation costs of certain contaminated sites located in Rhode Island and Massachusetts. Rate-recoverable contributions for electric operations of approximately $3 million are added annually to RIE's Environmental Response Fund, established with RIPUC approval in March 2000 to address such costs, along with interest and any recoveries from insurance carriers and other third parties. In addition, RIE recovers approximately $1 million annually for gas operations under a distribution adjustment charge in which the qualified remediation costs are amortized over 10 years. See Note 6 for additional information on RIE's recorded environmental regulatory assets and liabilities.

Regulatory Issues

(All Registrants)

See Note 6 for information on regulatory matters related to utility rate regulation.

Electricity - Reliability Standards

The NERC is responsible for establishing and enforcing mandatory reliability standards (Reliability Standards) regarding the bulk electric system in North America. The FERC oversees this process and independently enforces the Reliability Standards.

The Reliability Standards have the force and effect of law and apply to certain users of the bulk electric system, including electric utility companies, generators and marketers. Under the Federal Power Act, the FERC may assess civil penalties for certain violations.

PPL Electric, LG&E, KU and RIE monitor their compliance with the Reliability Standards and self-report or self-log potential violations of applicable reliability requirements whenever identified, and submit accompanying mitigation plans, as required. The resolution of a small number of potential violations is pending. Penalties incurred to date have not been significant. Any Regional Reliability Entity determination concerning the resolution of violations of the Reliability Standards remains subject to the approval of the NERC and the FERC.

In the course of implementing their programs to ensure compliance with the Reliability Standards by those PPL affiliates subject to the standards, certain other instances of potential non-compliance may be identified from time to time. The Registrants cannot predict the outcome of these matters, and an estimate or range of possible losses cannot be determined.

Gas - Security Directives (PPL and LG&E)

In May and July of 2021, the Department of Homeland Security’s (DHS) Transportation Security Administration released two security directives applicable to certain notified owners and operators of natural gas pipeline facilities (including local distribution companies) that the Transportation Security Administration has determined to be critical. The Transportation Security Administration has determined that LG&E is within the scope of the directive, while RIE has not been notified of this distinction. The first security directive required notified owners/operators to implement cybersecurity incident reporting to the DHS, designate a cybersecurity coordinator, and perform a gap assessment of current entity cybersecurity practices against certain voluntary Transportation Security Administration security guidelines and report relevant results and proposed mitigation to applicable DHS agencies. The second security directive, revised in July of 2024, requires refinement of the cybersecurity implementation plan and the cybersecurity assessment plan. LG&E does not believe the security directives have had or will have a significant impact on LG&E’s operations or financial condition.

Other

Guarantees and Other Assurances

(All Registrants)

In the normal course of business, the Registrants enter into agreements that provide financial performance assurance to third parties on behalf of certain subsidiaries. Examples of such agreements include: guarantees, stand-by letters of credit issued by financial institutions and surety bonds issued by insurance companies. These agreements are entered into primarily to support or enhance the creditworthiness attributed to a subsidiary on a stand-alone basis or to facilitate the commercial activities in which these subsidiaries engage.

(PPL)

PPL fully and unconditionally guarantees all of the debt securities and loan obligations of PPL Capital Funding.

(All Registrants)

The table below details guarantees provided as of March 31, 2025. "Exposure" represents the estimated maximum potential amount of future payments that could be required to be made under the guarantee. The Registrants believe the probability of expected payment/performance under each of these guarantees is remote, except for the guarantees and indemnifications related to the sale of Safari Holdings, which PPL believes are reasonably possible but not probable of occurring. For reporting purposes, on a consolidated basis, the guarantees of PPL include the guarantees of its subsidiary Registrants.

	Exposure at March 31, 2025			Expiration Date
PPL
Indemnifications related to certain tax liabilities related to the sale of the U.K. utility business	£	50	(a)	2028
PPL guarantee of Safari payment obligations under certain sale/leaseback financing transactions related to the sale of Safari Holdings	$	97	(b)	2028
Indemnifications for losses suffered related to items not covered by Aspen Power's representation and warranty insurance associated with the sale of Safari Holdings	140		(c)	2028
LG&E and KU
LG&E and KU obligation of shortfall related to OVEC			(d)

(a)PPL WPD Limited entered into a Tax Deed dated June 9, 2021, in which it agreed to a tax indemnity regarding certain potential tax liabilities of the entities sold with respect to periods prior to the completion of the sale, subject to customary exclusions and limitations. Because National Grid Holdings One plc, the buyer, agreed to purchase indemnity insurance, the amount of the cap on the indemnity for these liabilities is £1, except with respect to certain surrenders of tax losses, for which the amount of the cap on the indemnity is £50 million.

(b)PPL guaranteed the payment obligations of Safari under certain sale/leaseback financing transactions executed by Safari. These guarantees will remain in place until Safari exercises its option to buy-out the projects under the sale/leaseback financings by the year 2028. Safari will indemnify PPL for any payments made by PPL or claims against PPL under the sale/leaseback transaction guarantees up to $25 million.

(c)Aspen Power has obtained representation and warranty insurance, therefore, PPL generally has no liability for its representations and warranties under the agreement except for losses suffered related to items not covered. Expiration of these indemnifications range from 18 months to 6 years from the date of the closing of the transaction, and PPL’s aggregate liability for these claims will not exceed $140 million, subject to certain adjustments.

(d)Pursuant to the OVEC power purchase contract, LG&E and KU are obligated to pay for their share of OVEC's excess debt service, post-retirement, and decommissioning costs, as well as any shortfall from amounts included within a demand charge designed and expected to cover these costs over the term of the contract. PPL's proportionate share of OVEC's outstanding debt was $77 million at March 31, 2025, consisting of LG&E's share of $53 million and KU's share of $24 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchase Commitments" in Note 12 in PPL's, LG&E's and KU's 2024 Form 10-K for additional information on the OVEC power purchase contract.

The Registrants provide other miscellaneous guarantees through contracts entered into in the normal course of business. These guarantees are primarily in the form of indemnification or warranties related to services or equipment and vary in duration. The amounts of these guarantees often are not explicitly stated, and the overall maximum amount of the obligation under such guarantees cannot be reasonably estimated. Historically, no significant payments have been made with respect to these types of guarantees and the probability of payment/performance under these guarantees is generally remote.

PPL, on behalf of itself and certain of its subsidiaries, maintains insurance that covers liability assumed under contract for bodily injury and property damage. The insurance provides maximum aggregate coverage of $231 million for non-wildfire liability losses and maximum aggregate coverage of $181 million for wildfire liability losses. This insurance may be applicable to obligations under certain of these contractual arrangements.

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Related Party Transactions

3 Months Ended

Mar. 31, 2025

PPL Electric Utilities Corp [Member]

Related Party Transactions [Line Items]

Related Party Transactions

11. Related Party Transactions

Support Costs (PPL Electric, LG&E and KU)

PPL Services and LKS provide the Registrants, their respective subsidiaries and each other with administrative, management and support services. For all services companies, the costs of directly assignable and attributable services are charged to the respective recipients as direct support costs. General costs that cannot be directly attributed to a specific entity are allocated and charged to the respective recipients as indirect support costs. PPL Services and LKS use a three-factor methodology that includes the applicable recipients' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. PPL Services and LKS charged the following amounts for the periods ended March 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable.

	Three Months
	2025		2024
PPL Electric from PPL Services	$	64	$	56
LG&E from LKS	30		29
LG&E from PPL Services	20		11
KU from LKS	38		38
KU from PPL Services	19		11

In addition to the charges for services noted above, LKS makes payments on behalf of LG&E and KU for fuel purchases and other costs for products or services provided by third parties. LG&E and KU also provide services to each other and to LKS. Billings between LG&E and KU relate to labor and overheads associated with union and hourly employees performing work for the other company, charges related to jointly-owned generating units and other miscellaneous charges. Tax settlements between PPL and LG&E and KU are reimbursed through LKS.

Intercompany Borrowings

(PPL Electric)

CEP Reserves maintains a $800 million revolving line of credit with a PPL Electric subsidiary. At March 31, 2025, CEP Reserves had an insignificant amount of borrowings outstanding. At December 31, 2024, CEP Reserves had borrowings outstanding of $222 million. The interest rates on borrowings are equal to an adjusted one-month SOFR plus a spread. Interest income is reflected in "Interest Income from Affiliate" on the PPL Electric Income Statements.

(LG&E and KU)

LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to the difference between LG&E's FERC borrowing limit and LG&E's commercial paper issued at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on SOFR. At March 31, 2025, LG&E's money pool unused capacity was $661 million. At March 31, 2025, LG&E had insignificant borrowings outstanding from KU and/or LKE. At December 31, 2024, LG&E had borrowings outstanding of $43 million from KU and/or LKE. These balances are reflected in "Notes payable to affiliates" on the LG&E Balance Sheets.

KU participates in an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to the difference between KU's FERC borrowing limit and KU's commercial paper issued at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on SOFR. At March 31, 2025, KU's money pool unused capacity was $433 million. At March 31, 2025, KU had borrowings outstanding from LG&E and/or LKE of $8 million. At December 31, 2024, KU had borrowings outstanding of $73 million from LG&E and/or LKE. These balances are reflected in "Notes payable to affiliates" on the KU Balance Sheets.

VEBA Funds Receivable

(PPL Electric)

In 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA, to be used to pay medical claims of active

bargaining unit employees. In 2024, additional excess funds were removed from the PPL Bargaining Unit Retiree Health Plan VEBA and deposited into the existing subaccount within the VEBA to be used to pay medical claims of active bargaining unit employees. Based on PPL Electric's participation in PPL’s Other Postretirement Benefit plan, PPL Electric was allocated a portion of the excess funds from PPL Services. These funds have been recorded as an intercompany receivable on PPL Electric's Balance Sheets. The receivable balance decreases as PPL Electric pays incurred medical claims and is reimbursed by PPL Services. The intercompany receivable balance associated with these funds was $4 million at March 31, 2025, which was reflected in "Accounts receivable from affiliates" on PPL Electric's Balance Sheets. The intercompany receivable balance associated with these funds was $7 million at December 31, 2024, of which $4 million was reflected in "Accounts receivable from affiliates" and $3 million was reflected in "Other noncurrent assets" on PPL Electric's Balance Sheets.

Louisville Gas And Electric Co [Member]

Related Party Transactions [Line Items]

Related Party Transactions

11. Related Party Transactions

Support Costs (PPL Electric, LG&E and KU)

PPL Services and LKS provide the Registrants, their respective subsidiaries and each other with administrative, management and support services. For all services companies, the costs of directly assignable and attributable services are charged to the respective recipients as direct support costs. General costs that cannot be directly attributed to a specific entity are allocated and charged to the respective recipients as indirect support costs. PPL Services and LKS use a three-factor methodology that includes the applicable recipients' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. PPL Services and LKS charged the following amounts for the periods ended March 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable.

	Three Months
	2025		2024
PPL Electric from PPL Services	$	64	$	56
LG&E from LKS	30		29
LG&E from PPL Services	20		11
KU from LKS	38		38
KU from PPL Services	19		11

In addition to the charges for services noted above, LKS makes payments on behalf of LG&E and KU for fuel purchases and other costs for products or services provided by third parties. LG&E and KU also provide services to each other and to LKS. Billings between LG&E and KU relate to labor and overheads associated with union and hourly employees performing work for the other company, charges related to jointly-owned generating units and other miscellaneous charges. Tax settlements between PPL and LG&E and KU are reimbursed through LKS.

Intercompany Borrowings

(PPL Electric)

CEP Reserves maintains a $800 million revolving line of credit with a PPL Electric subsidiary. At March 31, 2025, CEP Reserves had an insignificant amount of borrowings outstanding. At December 31, 2024, CEP Reserves had borrowings outstanding of $222 million. The interest rates on borrowings are equal to an adjusted one-month SOFR plus a spread. Interest income is reflected in "Interest Income from Affiliate" on the PPL Electric Income Statements.

(LG&E and KU)

LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to the difference between LG&E's FERC borrowing limit and LG&E's commercial paper issued at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on SOFR. At March 31, 2025, LG&E's money pool unused capacity was $661 million. At March 31, 2025, LG&E had insignificant borrowings outstanding from KU and/or LKE. At December 31, 2024, LG&E had borrowings outstanding of $43 million from KU and/or LKE. These balances are reflected in "Notes payable to affiliates" on the LG&E Balance Sheets.

KU participates in an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to the difference between KU's FERC borrowing limit and KU's commercial paper issued at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on SOFR. At March 31, 2025, KU's money pool unused capacity was $433 million. At March 31, 2025, KU had borrowings outstanding from LG&E and/or LKE of $8 million. At December 31, 2024, KU had borrowings outstanding of $73 million from LG&E and/or LKE. These balances are reflected in "Notes payable to affiliates" on the KU Balance Sheets.

VEBA Funds Receivable

(PPL Electric)

In 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA, to be used to pay medical claims of active

bargaining unit employees. In 2024, additional excess funds were removed from the PPL Bargaining Unit Retiree Health Plan VEBA and deposited into the existing subaccount within the VEBA to be used to pay medical claims of active bargaining unit employees. Based on PPL Electric's participation in PPL’s Other Postretirement Benefit plan, PPL Electric was allocated a portion of the excess funds from PPL Services. These funds have been recorded as an intercompany receivable on PPL Electric's Balance Sheets. The receivable balance decreases as PPL Electric pays incurred medical claims and is reimbursed by PPL Services. The intercompany receivable balance associated with these funds was $4 million at March 31, 2025, which was reflected in "Accounts receivable from affiliates" on PPL Electric's Balance Sheets. The intercompany receivable balance associated with these funds was $7 million at December 31, 2024, of which $4 million was reflected in "Accounts receivable from affiliates" and $3 million was reflected in "Other noncurrent assets" on PPL Electric's Balance Sheets.

Kentucky Utilities Co [Member]

Related Party Transactions [Line Items]

Related Party Transactions

11. Related Party Transactions

Support Costs (PPL Electric, LG&E and KU)

PPL Services and LKS provide the Registrants, their respective subsidiaries and each other with administrative, management and support services. For all services companies, the costs of directly assignable and attributable services are charged to the respective recipients as direct support costs. General costs that cannot be directly attributed to a specific entity are allocated and charged to the respective recipients as indirect support costs. PPL Services and LKS use a three-factor methodology that includes the applicable recipients' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. PPL Services and LKS charged the following amounts for the periods ended March 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable.

	Three Months
	2025		2024
PPL Electric from PPL Services	$	64	$	56
LG&E from LKS	30		29
LG&E from PPL Services	20		11
KU from LKS	38		38
KU from PPL Services	19		11

In addition to the charges for services noted above, LKS makes payments on behalf of LG&E and KU for fuel purchases and other costs for products or services provided by third parties. LG&E and KU also provide services to each other and to LKS. Billings between LG&E and KU relate to labor and overheads associated with union and hourly employees performing work for the other company, charges related to jointly-owned generating units and other miscellaneous charges. Tax settlements between PPL and LG&E and KU are reimbursed through LKS.

Intercompany Borrowings

(PPL Electric)

CEP Reserves maintains a $800 million revolving line of credit with a PPL Electric subsidiary. At March 31, 2025, CEP Reserves had an insignificant amount of borrowings outstanding. At December 31, 2024, CEP Reserves had borrowings outstanding of $222 million. The interest rates on borrowings are equal to an adjusted one-month SOFR plus a spread. Interest income is reflected in "Interest Income from Affiliate" on the PPL Electric Income Statements.

(LG&E and KU)

LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to the difference between LG&E's FERC borrowing limit and LG&E's commercial paper issued at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on SOFR. At March 31, 2025, LG&E's money pool unused capacity was $661 million. At March 31, 2025, LG&E had insignificant borrowings outstanding from KU and/or LKE. At December 31, 2024, LG&E had borrowings outstanding of $43 million from KU and/or LKE. These balances are reflected in "Notes payable to affiliates" on the LG&E Balance Sheets.

KU participates in an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to the difference between KU's FERC borrowing limit and KU's commercial paper issued at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on SOFR. At March 31, 2025, KU's money pool unused capacity was $433 million. At March 31, 2025, KU had borrowings outstanding from LG&E and/or LKE of $8 million. At December 31, 2024, KU had borrowings outstanding of $73 million from LG&E and/or LKE. These balances are reflected in "Notes payable to affiliates" on the KU Balance Sheets.

VEBA Funds Receivable

(PPL Electric)

In 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA, to be used to pay medical claims of active

bargaining unit employees. In 2024, additional excess funds were removed from the PPL Bargaining Unit Retiree Health Plan VEBA and deposited into the existing subaccount within the VEBA to be used to pay medical claims of active bargaining unit employees. Based on PPL Electric's participation in PPL’s Other Postretirement Benefit plan, PPL Electric was allocated a portion of the excess funds from PPL Services. These funds have been recorded as an intercompany receivable on PPL Electric's Balance Sheets. The receivable balance decreases as PPL Electric pays incurred medical claims and is reimbursed by PPL Services. The intercompany receivable balance associated with these funds was $4 million at March 31, 2025, which was reflected in "Accounts receivable from affiliates" on PPL Electric's Balance Sheets. The intercompany receivable balance associated with these funds was $7 million at December 31, 2024, of which $4 million was reflected in "Accounts receivable from affiliates" and $3 million was reflected in "Other noncurrent assets" on PPL Electric's Balance Sheets.

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Fair Value Measurements

3 Months Ended

Mar. 31, 2025

Fair Value Disclosures [Abstract]

Fair Value Measurements

13. Fair Value Measurements

(All Registrants)

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (an exit price). A market approach (generally, data from market transactions), an income approach (generally, present value techniques and option pricing models) and/or a cost approach (generally, replacement cost) are used to measure the fair value of an asset or liability, as appropriate. These valuation approaches incorporate inputs such as observable, independent market data and/or unobservable data that management believes are predicated on the assumptions market participants would use to price an asset or liability. These inputs may incorporate, as applicable, certain risks such as nonperformance risk, which includes credit risk. The fair value of a group of financial assets and liabilities is measured on a net basis. See Note 1 in each Registrant's 2024 Form 10-K for information on the levels in the fair value hierarchy.

Recurring Fair Value Measurements

The assets and liabilities measured at fair value were:

	March 31, 2025								December 31, 2024
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
PPL
Assets
Cash and cash equivalents	$	312	$	312	$	—	$	—	$	306	$	306	$	—	$	—
Restricted cash and cash equivalents (a)	28		28		—		—		33		33		—		—
Total Cash, Cash Equivalents and Restricted Cash (b)	340		340		—		—		339		339		—		—
Special use funds (a):
Money market fund	1		1		—		—		1		1		—		—
Commingled debt fund measured at NAV (c)	8		—		—		—		10		—		—		—
Commingled equity fund measured at NAV (c)	7		—		—		—		8		—		—		—
Total special use funds	16		1		—		—		19		1		—		—
Price risk management assets (d):
Gas contracts	22		—		22		—		9		—		4		5
Total assets	$	378	$	341	$	22	$	—	$	367	$	340	$	4	$	5
Liabilities
Price risk management liabilities (d):
Interest rate swaps	$	5	$	—	$	5	$	—	$	3	$	—	$	3	$	—
Gas contracts	6		—		—		6		13		—		10		3
Total price risk management liabilities	$	11	$	—	$	5	$	6	$	16	$	—	$	13	$	3
PPL Electric
Assets
Cash and cash equivalents	$	27	$	27	$	—	$	—	$	24	$	24	$	—	$	—
Total assets	$	27	$	27	$	—	$	—	$	24	$	24	$	—	$	—
LG&E
Assets
Cash and cash equivalents	$	10	$	10	$	—	$	—	$	8	$	8	$	—	$	—
Restricted cash and cash equivalents (a)	13		13		—		—		16		16		—		—
Total Cash, Cash Equivalents and Restricted Cash (b)	23		23		—		—		24		24		—		—
Total assets	$	23	$	23	$	—	$	—	$	24	$	24	$	—	$	—
Liabilities
Price risk management liabilities:
Interest rate swaps	$	5	$	—	$	5	$	—	$	3	$	—	$	3	$	—
Total price risk management liabilities	$	5	$	—	$	5	$	—	$	3	$	—	$	3	$	—
KU
Assets
Cash and cash equivalents	$	14	$	14	$	—	$	—	$	13	$	13	$	—	$	—
Restricted cash and cash equivalents (a)	13		13		—		—		16		16		—		—
Total Cash, Cash Equivalents and Restricted Cash (b)	27		27		—		—		29		29		—		—
Total assets	$	27	$	27	$	—	$	—	$	29	$	29	$	—	$	—

(a)Current portion is included in "Other current assets" and noncurrent portion is included in "Other noncurrent assets" on the Balance Sheets.

(b)Total Cash, Cash Equivalents and Restricted Cash provides a reconciliation of these items reported within the Balance Sheets to the sum shown on the Statements of Cash Flows.

(c)In accordance with accounting guidance, certain investments that are measured at fair value using net asset value per share (NAV), or its equivalent, have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the Balance Sheets.

(d)Current portion is included in "Other current assets" and "Other current liabilities" and noncurrent portion is included in "Other noncurrent assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets.

A reconciliation of net liabilities classified as Level 3 for the three months ended March 31 is as follows:

	Gas Contracts
2025
Balance at beginning of period	$	(2)
Total unrealized gains (losses) recognized as Regulatory Assets/Regulatory Liabilities:	8
Settlements	—
Balance at end of period	$	6

Special Use Funds (PPL)

The special use funds are investments restricted for paying active union employee medical costs. In 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA to be used to pay medical claims of active bargaining unit employees. In 2024, additional excess funds were removed from the PPL Bargaining Unit Retiree Health Plan VEBA and deposited in the existing subaccount within the VEBA to be used to pay medical claims of active bargaining unit employees. The funds are invested primarily in commingled debt and equity funds measured at NAV and are classified as investments in equity securities. Changes in the fair value of the funds are recorded to the Statements of Income.

Price Risk Management Assets/Liabilities

Interest Rate Swaps (PPL, LG&E and KU)

To manage interest rate risk, PPL, LG&E and KU use interest rate contracts such as treasury locks, forward-starting swaps, floating-to-fixed swaps and fixed-to-floating swaps. An income approach is used to measure the fair value of these contracts, utilizing readily observable inputs, such as forward interest rates (e.g., SOFR and government security rates), as well as inputs that may not be observable, such as credit valuation adjustments. In certain cases, market information cannot practicably be obtained to value credit risk and therefore internal models are relied upon. These models use projected probabilities of default and estimated recovery rates based on historical observances. When the credit valuation adjustment is significant to the overall valuation, the contracts are classified as Level 3.

Gas Contracts (PPL)

To manage gas commodity price risk associated with natural gas purchases, RIE utilizes over-the-counter (OTC) gas swaps contracts with pricing inputs obtained from the New York Mercantile Exchange (NYMEX) and the Intercontinental Exchange (ICE), except in cases where the ICE publishes seasonal averages or where there were no transactions within the last seven days. RIE may utilize discounting based on quoted interest rate curves, including consideration of non-performance risk, and may include a liquidity reserve calculated based on bid/ask spread. Substantially all of these price curves are observable in the marketplace throughout at least 95% of the remaining contractual quantity, or they could be constructed from market observable curves with correlation coefficients of 95% or higher. These contracts are classified as Level 2.

RIE also utilizes gas option and purchase and capacity transactions, which are valued based on internally developed models. Industry-standard valuation techniques, such as the Black-Scholes pricing model, are used for valuing such instruments. For valuations that include both observable and unobservable inputs, if the unobservable input is determined to be significant to the overall inputs, the entire valuation is classified as Level 3. This includes derivative instruments valued using indicative price quotations whose contract tenure extends into unobservable periods. In instances where observable data is unavailable, consideration is given to the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility, and contract duration. Such instruments are classified as Level 3 as the model inputs generally are not observable. RIE considers non-performance risk and liquidity risk in the valuation of derivative instruments classified as Level 2 and Level 3.

The significant unobservable inputs used in the fair value measurement of the gas derivative instruments are implied volatility and gas forward curves. A relative change in commodity price at various locations underlying the open positions can result in significantly different fair value estimates.

Financial Instruments Not Recorded at Fair Value (All Registrants)

Long-term debt is classified as Level 2. The effect of third-party credit enhancements is not included in the fair value measurement. The carrying amounts of long-term debt on the Balance Sheets and their estimated fair values are set forth below.

	March 31, 2025				December 31, 2024
	Carrying Amount (a)		Fair Value		Carrying Amount (a)		Fair Value
PPL	$	16,507	$	15,847	$	16,503	$	15,562
PPL Electric	5,214		4,931		5,214		4,862
LG&E	2,471		2,335		2,471		2,295
KU	3,066		2,804		3,066		2,750

(a)Amounts are net of debt issuance costs.

The carrying amounts of other current financial instruments (except for long-term debt due within one year) approximate their fair values because of their short-term nature.

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Derivative Instruments and Hedging Activities

3 Months Ended

Mar. 31, 2025

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments and Hedging Activities

14. Derivative Instruments and Hedging Activities

(All Registrants)

Risk Management Objectives

PPL has a risk management policy approved by the Board of Directors to manage market risk associated with commodities, interest rates on debt issuances (including price, liquidity and volumetric risk) and credit risk (including non-performance risk and payment default risk). The Risk Management Committee, comprised of senior management and chaired by the Vice President-Financial Strategy and Chief Risk Officer, oversees the risk management function. Key risk control activities designed to ensure compliance with the risk policy and detailed programs include, but are not limited to, credit review and approval, validation of transactions, verification of risk and transaction limits, value-at-risk analyses (VaR, a statistical model that attempts to estimate the value of potential loss over a given holding period under normal market conditions at a given confidence level) and the coordination and reporting of the Enterprise Risk Management program.

Market Risk

Market risk includes the potential loss that may be incurred as a result of price changes associated with a particular financial or commodity instrument as well as market liquidity and volumetric risks. Forward contracts, futures contracts, options, swaps and structured transactions are utilized as part of risk management strategies to minimize unanticipated fluctuations in earnings caused by changes in commodity prices and interest rates. Many of these contracts meet the definition of a derivative. All derivatives are recognized on the Balance Sheets at their fair value, unless NPNS is elected.

The following summarizes the market risks that affect PPL and its subsidiaries.

Interest Rate Risk

•PPL and its subsidiaries are exposed to interest rate risk associated with forecasted fixed-rate and existing floating-rate debt issuances. PPL and LG&E utilize over-the-counter interest rate swaps to limit exposure to market fluctuations on floating-rate debt. PPL, LG&E and KU utilize hedging instruments to limit exposure to fluctuations in benchmark interest rates, when appropriate, in connection with future debt issuance.

•PPL and its subsidiaries are exposed to interest rate risk associated with debt securities and derivatives held by defined benefit plans. This risk is significantly mitigated to the extent that the plans are sponsored at, or sponsored on behalf of, the regulated utilities due to the recovery methods in place.

Commodity Price Risk

PPL is exposed to commodity price risk through its subsidiaries as described below.

•PPL Electric is required to purchase electricity to fulfill its obligation as a PLR. Potential commodity price risk is mitigated through its PAPUC-approved cost recovery mechanism and full-requirement supply agreements to serve its PLR customers which transfer the risk to energy suppliers.

•LG&E's and KU's rates include certain mechanisms for fuel, fuel-related expenses and energy purchases. In addition, LG&E's rates include a mechanism for natural gas supply costs. These mechanisms generally provide for timely recovery of market price fluctuations associated with these costs.

•RIE utilizes derivative instruments pursuant to its RIPUC-approved plan to manage commodity price risk associated with its natural gas purchases. RIE's commodity price risk management strategy is to reduce fluctuations in firm gas sales prices to its customers. RIE's costs associated with derivatives instruments are recoverable through its RIPUC-approved cost recovery mechanisms. RIE is also required to purchase electricity to fulfill its obligation to provide Last Resort Service (LRS). Potential commodity price risk is mitigated through its RIPUC-approved cost recovery mechanisms and full requirements service agreements to serve LRS customers, which transfer the risk to energy suppliers. Additionally, RIE is required to contract through long-term agreements for clean energy supply under the Rhode Island Renewable Energy Growth program and Long-term Clean Energy Standard. Potential commodity price risk is mitigated through its RIPUC-approved cost recovery mechanisms, which true-up cost differences between contract prices and market prices.

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 exposed to volumetric risk, which is significantly mitigated by regulatory mechanisms. RIE's electric and gas distribution rates both have a revenue decoupling mechanism, which allows for annual adjustments to RIE's delivery rates.

Equity Securities Price Risk

•PPL and its subsidiaries are exposed to equity securities price risk associated with the fair value of the defined benefit plans' assets. This risk is significantly mitigated due to the recovery methods in place.

•PPL is exposed to equity securities price risk from future stock sales and/or purchases.

Credit Risk

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.

Master Netting Arrangements (PPL, LG&E and KU)

Net derivative positions on the balance sheets are not offset against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements.

PPL, LG&E and KU had no obligation to return or post cash collateral under master netting arrangements at March 31, 2025 and December 31, 2024.

See "Offsetting Derivative Instruments" below for a summary of derivative positions presented in the balance sheets where a right of setoff exists under these arrangements.

Interest Rate Risk

(All Registrants)

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.

Cash Flow Hedges (PPL)

Interest rate risks include exposure to adverse interest rate movements for outstanding variable rate debt and for future anticipated financings. Financial interest rate swap contracts that qualify as cash flow hedges may be entered into to hedge floating interest rate risk associated with both existing and anticipated debt issuances. PPL had no such contracts at March 31, 2025.

Cash flow hedges are discontinued if it is no longer probable that the original forecasted transaction will occur by the end of the originally specified time period and any amounts previously recorded in AOCI are reclassified into earnings once it is determined that the hedged transaction is not probable of occurring.

For the three months ended March 31, 2025 and 2024, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges.

At March 31, 2025, the amount of accumulated net unrecognized after-tax gains (losses) on qualifying derivatives expected to be reclassified into earnings during the next 12 months is insignificant. Amounts are reclassified as the hedged interest expense is recorded.

Economic Activity (PPL and LG&E)

LG&E enters into interest rate swap contracts that economically hedge interest payments. Because realized gains and losses from the swaps, including terminated swap contracts, are recoverable through regulated rates, any subsequent changes in fair value of these derivatives are included in regulatory assets or liabilities until they are realized as interest expense. Realized gains and losses are recognized in "Interest Expense" on the Statements of Income at the time the underlying hedged interest expense is recorded. At March 31, 2025, LG&E held contracts with a notional amount of $64 million that mature in 2033.

Commodity Price Risk (PPL)

Economic Activity

RIE enters into derivative contracts that economically hedge natural gas purchases. Realized gains and losses from the derivatives are recoverable through regulated rates, therefore subsequent changes in fair value are included in regulatory assets or liabilities until they are realized as purchased gas. Realized gains and losses are recognized in "Energy Purchases" on the Statements of Income upon settlement of the contracts. At March 31, 2025, RIE held contracts with notional volumes of 40 Bcf that range in maturity from 2025 through 2029.

Accounting and Reporting

(All Registrants)

All derivative instruments are recorded at fair value on the Balance Sheet as an asset or liability unless the NPNS is elected. NPNS contracts include certain full requirement purchase contracts and other physical purchase contracts. Changes in the fair value of derivatives not designated as NPNS are recognized in earnings unless specific hedge accounting criteria are met and designated as such, except for the changes in fair values of LG&E's interest rate swaps that are recognized as regulatory assets or regulatory liabilities. See Note 6 for amounts recorded in regulatory assets and regulatory liabilities at March 31, 2025 and December 31, 2024.

See Note 1 in each Registrant's 2024 Form 10-K for additional information on accounting policies related to derivative instruments.

(PPL)

The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments.

	March 31, 2025				December 31, 2024
	Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management Assets/Liabilities (a):
Interest rate swaps	$	—	$	1	$	—	$	—
Gas contracts	16		1		7		10
Total current	16		2		7		10
Noncurrent:
Price Risk Management Assets/Liabilities (a):
Interest rate swaps	—		4		—		3
Gas contracts	6		5		2		3
Total noncurrent	6		9		2		6
Total derivatives	$	22	$	11	$	9	$	16

(a)Current portion is included in "Other current assets" and "Other current liabilities" and noncurrent portion is included in "Other noncurrent assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets. Excludes accrued interest, if applicable.

The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities for the period ended March 31, 2025.

		Three Months
Derivative Relationships	Location of Gain (Loss) Recognized in Income on Derivative	Gain (Loss) Reclassified from AOCI into Income
Cash Flow Hedges:
Interest rate swaps	Interest expense	$	(1)

Derivatives Not Designated as Hedging Instruments	Location of Gain (Loss) Recognized in Income on Derivative	Three Months
Gas contracts	Energy purchases	$	(5)
	Total	$	(5)
Derivatives Not Designated as Hedging Instruments	Location of Gain (Loss) Recognized as Regulatory Liabilities/Assets	Three Months
Interest rate swaps	Regulatory assets - noncurrent	$	(1)
Gas contracts	Regulatory liabilities - current	18
	Regulatory liabilities - noncurrent	1
	Total	$	18

The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities for the period ended March 31, 2024.

	Three Months			Three Months
Derivative Relationships	Derivative Gain (Loss) Recognized in OCI		Location of Gain (Loss) Recognized in Income on Derivative	Gain (Loss) Reclassified from AOCI into Income
Cash Flow Hedges:
Interest rate swaps	$	—	Interest expense	$	(1)

Derivatives Not Designated as Hedging Instruments	Location of Gain (Loss) Recognized in Income on Derivative	Three Months
Gas contracts	Energy purchases	$	(16)
	Total	$	(16)
Derivatives Not Designated as Hedging Instruments	Location of Gain (Loss) Recognized as Regulatory Liabilities/Assets	Three Months
Interest rate swaps	Regulatory assets - noncurrent	$	2
Gas contracts	Regulatory assets - current	22
	Regulatory assets - noncurrent	4
	Total	$	28

The following table presents the effect of cash flow hedge activity on the Statement of Income for the period ended March 31, 2025.

	Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships
	Three Months
	Interest Expense
Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded	$	190
The effects of cash flow hedges:
Gain (Loss) on cash flow hedging relationships:
Interest rate swaps:
Amount of gain (loss) reclassified from AOCI to income	(1)

The following table presents the effect of cash flow hedge activity on the Statement of Income for the period ended March 31, 2024.

	Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships
	Three Months
	Interest Expense
Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded	$	179
The effects of cash flow hedges:
Gain (Loss) on cash flow hedging relationships:
Interest rate swaps:
Amount of gain (loss) reclassified from AOCI to income	(1)

(LG&E)

The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments.

	March 31, 2025				December 31, 2024
	Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management Assets/Liabilities:
Interest rate swaps	$	—	$	1	$	—	$	—
Total current	—		1		—		—
Noncurrent:
Price Risk Management Assets/Liabilities:
Interest rate swaps	—		4		—		3
Total noncurrent	—		4		—		3
Total derivatives	$	—	$	5	$	—	$	3

The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets for the period ended March 31, 2025.

	Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months
Interest rate swaps	Interest expense	$	—
	Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months
Interest rate swaps	Regulatory assets - noncurrent	$	(1)

The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets for the period ended March 31, 2024. 

	Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months
Interest rate swaps	Interest expense	$	—
	Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months
Interest rate swaps	Regulatory assets - noncurrent	$	2

(PPL, LG&E and KU)

Offsetting Derivative Instruments

PPL, LG&E and KU or certain of their subsidiaries have master netting arrangements in place and also enter into agreements pursuant to which they purchase or sell certain energy and other products. Under the agreements, upon termination of the agreement as a result of a default or other termination event, the non-defaulting party typically would have a right to set off amounts owed under the agreement against any other obligations arising between the two parties (whether under the agreement or not), whether matured or contingent and irrespective of the currency, place of payment or place of booking of the obligation.

PPL, LG&E and KU have elected not to offset derivative assets and liabilities and not to offset net derivative positions against the right to reclaim cash collateral pledged (an asset) or the obligation to return cash collateral received (a liability) under derivatives agreements. The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged.

	Assets								Liabilities
			Eligible for Offset								Eligible for Offset
	Gross		Derivative Instruments		Cash Collateral Received		Net		Gross		Derivative Instruments		Cash Collateral Pledged		Net
March 31, 2025
Derivatives
PPL	$	22	$	1	$	—	$	21	$	11	$	1	$	—	$	10
LG&E	—		—		—		—		5		—		—		5

	Assets								Liabilities
			Eligible for Offset								Eligible for Offset
	Gross		Derivative Instruments		Cash Collateral Received		Net		Gross		Derivative Instruments		Cash Collateral Pledged		Net
December 31, 2024
Derivatives
PPL	$	9	$	5	$	—	$	4	$	16	$	5	$	—	$	11
LG&E	—		—		—		—		3		—		—		3

Credit Risk-Related Contingent Features

Certain derivative contracts contain credit risk-related contingent features which, when in a net liability position, would permit the counterparties to require the transfer of additional collateral upon a decrease in the credit ratings of PPL, LG&E and KU or certain of their subsidiaries. Most of these features would require the transfer of additional collateral or permit the counterparty to terminate the contract if the applicable credit rating were to fall below investment grade. Some of these features also would allow the counterparty to require additional collateral upon each downgrade in credit rating at levels that remain above investment grade. In either case, if the applicable credit rating were to fall below investment grade, and assuming no assignment to an investment grade affiliate were allowed, most of these credit contingent features require either immediate payment of the net liability as a termination payment or immediate and ongoing full collateralization on derivative instruments in net liability positions.

Additionally, certain derivative contracts contain credit risk-related contingent features that require adequate assurance of performance be provided if the other party has reasonable concerns regarding the performance of PPL's, LG&E's and KU's obligations under the contracts. A counterparty demanding adequate assurance could require a transfer of additional collateral or other security, including letters of credit, cash and guarantees from a creditworthy entity. This would typically involve negotiations among the parties. However, amounts disclosed below represent assumed immediate payment or immediate and ongoing full collateralization for derivative instruments in net liability positions with "adequate assurance" features.

(PPL)

At March 31, 2025, there were no derivative contracts in a net liability position that contain credit risk-related contingent features. At March 31, 2025, there were no additional collateral requirements in the event of a credit downgrade below investment grade.

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Asset Retirement Obligations

3 Months Ended

Mar. 31, 2025

Asset Retirement Obligations [Line Items]

Asset Retirement Obligations

15. Asset Retirement Obligations

(PPL, LG&E and KU)

PPL's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 10 for information on the CCR rule. LG&E and RIE also have AROs related to natural gas mains and wells. LG&E's and KU's transmission and distribution lines largely operate under perpetual property easement agreements, which do not generally require restoration upon removal of the property. Therefore, no material AROs are recorded for transmission and distribution assets. For LG&E, KU and RIE, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal.

The changes in the carrying amounts of AROs were as follows.

	PPL		LG&E		KU
Balance at December 31, 2024	$	157	$	84	$	64
Accretion	2		1		1
Changes in estimated timing or cost	(1)		—		(1)
Obligations settled	(4)		(1)		(3)
Balance at March 31, 2025	$	154	$	84	$	61

Louisville Gas And Electric Co [Member]

Asset Retirement Obligations [Line Items]

Asset Retirement Obligations

15. Asset Retirement Obligations

(PPL, LG&E and KU)

PPL's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 10 for information on the CCR rule. LG&E and RIE also have AROs related to natural gas mains and wells. LG&E's and KU's transmission and distribution lines largely operate under perpetual property easement agreements, which do not generally require restoration upon removal of the property. Therefore, no material AROs are recorded for transmission and distribution assets. For LG&E, KU and RIE, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal.

The changes in the carrying amounts of AROs were as follows.

	PPL		LG&E		KU
Balance at December 31, 2024	$	157	$	84	$	64
Accretion	2		1		1
Changes in estimated timing or cost	(1)		—		(1)
Obligations settled	(4)		(1)		(3)
Balance at March 31, 2025	$	154	$	84	$	61

Kentucky Utilities Co [Member]

Asset Retirement Obligations [Line Items]

Asset Retirement Obligations

15. Asset Retirement Obligations

(PPL, LG&E and KU)

PPL's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 10 for information on the CCR rule. LG&E and RIE also have AROs related to natural gas mains and wells. LG&E's and KU's transmission and distribution lines largely operate under perpetual property easement agreements, which do not generally require restoration upon removal of the property. Therefore, no material AROs are recorded for transmission and distribution assets. For LG&E, KU and RIE, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal.

The changes in the carrying amounts of AROs were as follows.

	PPL		LG&E		KU
Balance at December 31, 2024	$	157	$	84	$	64
Accretion	2		1		1
Changes in estimated timing or cost	(1)		—		(1)
Obligations settled	(4)		(1)		(3)
Balance at March 31, 2025	$	154	$	84	$	61

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Accumulated Other Comprehensive Income (Loss)

3 Months Ended

Mar. 31, 2025

Accumulated Other Comprehensive Income (Loss) [Line Items]

Accumulated Other Comprehensive Income (Loss)

16. Accumulated Other Comprehensive Income (Loss)

(PPL)

The after-tax changes in AOCI by component for the periods ended March 31 were as follows.

	Unrealized gains (losses)  on qualifying derivatives				Defined benefit plans
			Equity investees' AOCI		Prior service costs		Actuarial gain (loss)		Total
PPL
December 31, 2024	$	9	$	4	$	(3)	$	(194)	$	(184)
Reclassifications from AOCI	1		—		—		(1)		—
Net OCI during the period	1		—		—		(1)		—
March 31, 2025	$	10	$	4	$	(3)	$	(195)	$	(184)
December 31, 2023	$	6	$	3	$	(4)	$	(168)	$	(163)
Amounts arising during the period	—		1		—		—		1
Reclassifications from AOCI	1		—		—		—		1
Net OCI during the period	1		1		—		—		2
March 31, 2024	$	7	$	4	$	(4)	$	(168)	$	(161)

The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the periods ended March 31.

	Three Months				Affected Line Item on the
Details about AOCI	2025		2024		Statements of Income
Qualifying derivatives
Interest rate swaps	$	(1)	$	(1)	Interest Expense
Total Pre-tax	(1)		(1)
Income Taxes	—		—
Total After-tax	(1)		(1)
Defined benefit plans
Net actuarial loss (a)	1		—
Total Pre-tax	1		—
Income Taxes	—		—
Total After-tax	1		—
Total reclassifications during the period	$	—	$	(1)

(a)    These AOCI components are included in the computation of net periodic defined benefit cost. See Note 9 for additional information.

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Interim Financial Statements

3 Months Ended

Mar. 31, 2025

Interim Financial Statements [Abstract]

Interim Financial Statements

1. Interim Financial Statements

(All Registrants)

Capitalized terms and abbreviations appearing in the unaudited combined notes to condensed financial statements are defined in the glossary. Dollars are in millions, except per share data, unless otherwise noted. 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 any Registrant when significant.

The accompanying unaudited condensed financial statements have been prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X and, therefore, do not include all of the information and footnote disclosures required by GAAP for complete financial statements. In the opinion of management, all adjustments considered necessary for a fair presentation in accordance with GAAP are reflected in the condensed financial statements. All adjustments are of a normal recurring nature, except as otherwise disclosed. Each Registrant's Balance Sheet at December 31, 2024 is derived from that Registrant's 2024 audited Balance Sheet. The financial statements and notes thereto should be read in conjunction with the financial statements and notes contained in each Registrant's 2024 Form 10-K. The results of operations for the three months ended March 31, 2025 are not necessarily indicative of the results to be expected for the full year ending December 31, 2025 or other future periods, because results for interim periods can be disproportionately influenced by various factors, developments and seasonal variations.

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Summary of Significant Accounting Policies

3 Months Ended

Mar. 31, 2025

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

XX. Summary of Significant Accounting Policies

(All Registrants)

The following accounting policy disclosures represent updates to Note 1 in each Registrant's 2024 Form 10-K and should be read in conjunction with those disclosures.

Restricted Cash and Cash Equivalents (PPL)

Reconciliation of Cash, Cash Equivalents and Restricted Cash

The following provides a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the Balance Sheets that sum to the total of the same amounts shown on the Statements of Cash Flows:

	PPL
	March 31, 2025		December 31, 2024
Cash and cash equivalents	$	312	$	306
Restricted cash - current (a)	42		1
Total Cash, Cash Equivalents and Restricted Cash	$	354	$	307

(a)Bank deposits and other cash equivalents that are restricted by agreement or that have been clearly designated for a specific purpose are classified as restricted cash. On the Balance Sheets, the current portion of restricted cash is included in "Other current assets."

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Revenue from Contracts with Customers

3 Months Ended

Mar. 31, 2025

Revenue from Contract with Customer [Abstract]

Revenue from Contracts with Customers

3. Revenue from Contracts with Customers

(All Registrants)

See Note 3 in the Registrants' 2024 Form 10-K for a discussion of the principal activities from which PPL Electric, LG&E and KU and PPL’s Pennsylvania Regulated, Rhode Island Regulated, and Kentucky Regulated segments generate their revenues. The following tables reconcile "Operating Revenues" included in each Registrant's Statement of Income with revenues generated from contracts with customers for the periods ended March 31.

	2025 Three Months
	PPL		PPL Electric		LG&E		KU
Operating Revenues (a)(b)	$	2,504	$	819	$	505	$	564
Revenues derived from:
Alternative revenue programs (c)	50		(2)		2		4
Other (d)	(9)		(5)		(1)		(2)
Revenues from Contracts with Customers	$	2,545	$	812	$	506	$	566
	2024 Three Months
	PPL		PPL Electric		LG&E		KU
Operating Revenues (a)(b)	$	2,304	$	770	$	476	$	525
Revenues derived from:
Alternative revenue programs (c)	7		(3)		2		5
Other (d)	(8)		(5)		(1)		(1)
Revenues from Contracts with Customers	$	2,303	$	762	$	477	$	529

(a)PPL includes $626 million for the three months ended March 31, 2025 and $549 million for the three months ended March 31, 2024 of revenues from external customers reported by the Rhode Island Regulated segment. PPL Electric represents revenues from external customers reported by the Pennsylvania Regulated segment and LG&E and KU, net of intercompany power sales and transmission revenues, represent revenues from external customers reported by the Kentucky Regulated segment. See Note 2 for additional information.

(b)PPL's transition services agreement associated with the RIE acquisition ended in the third quarter of 2024. In conjunction with the completion of the agreement, PPL conformed the presentation of RIE's and the Rhode Island Regulated segment’s net metering charges with the presentation of the other segments, resulting in an increase in Operating Revenues and a corresponding increase in Energy purchases beginning in the fourth quarter of 2024. For the quarter ended March 31, 2025, net metering of $41 million was included in Energy purchases on PPL's Statement of Income. For the quarter ended March 31, 2024, $32 million of net metering was presented as a reduction of Operating Revenues on PPL's Statement of Income.

(c)This line item shows the over/under collection of rate mechanisms deemed alternative revenue programs with over-collections of revenue shown as positive amounts in the table above and under-collections shown as negative amounts.

(d)Represents additional revenues outside the scope of revenues from contracts with customers, such as lease and other miscellaneous revenues.

The following tables show revenues from contracts with customers disaggregated by customer class for the periods ended March 31.

	Three Months
	Residential		Commercial		Industrial		Other (a)		Wholesale - municipality		Wholesale - other (b)		Transmission		Revenues from Contracts with Customers
PPL
2025
PA Regulated	$	457	$	106	$	13	$	13	$	—	$	—	$	223	$	812
KY Regulated	487		280		154		96		7		38		—		1,062
RI Regulated (c)	441		197		18		(35)		—		—		50		671
Total PPL	$	1,385	$	583	$	185	$	74	$	7	$	38	$	273	$	2,545
2024
PA Regulated	$	426	$	106	$	12	$	13	$	—	$	—	$	205	$	762
KY Regulated	443		267		161		97		6		15		—		989
RI Regulated (c)	261		78		4		161		—		—		47		551
Corp and Other	—		—		—		1		—		—		—		1
Total PPL	$	1,130	$	451	$	177	$	272	$	6	$	15	$	252	$	2,303
PPL Electric
2025	$	457	$	106	$	13	$	13	$	—	$	—	$	223	$	812
2024	$	426	$	106	$	12	$	13	$	—	$	—	$	205	$	762
LG&E
2025	$	239	$	147	$	46	$	54	$	—	$	20	$	—	$	506
2024	$	218	$	138	$	47	$	52	$	—	$	22	$	—	$	477
KU
2025	$	248	$	133	$	108	$	42	$	7	$	28	$	—	$	566
2024	$	225	$	129	$	114	$	46	$	6	$	9	$	—	$	529

(a)Primarily includes revenues from pole attachments, street lighting, other public authorities and other non-core businesses, and for the Rhode Island Regulated Segment certain regulatory deferral mechanisms which could result in a reduction in revenues from over collections. For the period ended 2024, the Rhode Island Regulated segment primarily includes open access tariff revenues, which are calculated on combined customer classes.

(b)Includes wholesale power and transmission revenues. LG&E and KU amounts include intercompany power sales and transmission revenues, which are eliminated upon consolidation at the Kentucky Regulated segment.

(c)PPL's transition services agreement associated with the RIE acquisition ended in the third quarter of 2024. In conjunction with the completion of the agreement, PPL disaggregated the 2024 revenues of the Rhode Island Regulated segment in a manner consistent with that of its other segments. This resulted in certain customer revenues for the Rhode Island Regulated segment, which were previously presented in the "Other" category, being presented in the "Residential", "Commercial" or "Industrial" customer classes beginning in the fourth quarter of 2024. Applying the previous methodology to 2025 revenues would result in $155 million of Residential, $89 million of Commercial and $13 million of Industrial for the Rhode Island Regulated segment being presented as "Other" for the three months ended March 31, 2025.

As discussed in Note 2, PPL segments its business by geographic location. Revenues from external customers for each segment are reconciled to revenues from contracts with customers in the footnotes to the tables above.

Contract receivables from customers are primarily included in "Accounts receivable - Customer", "Unbilled revenues", and "Other noncurrent assets" on the Balance Sheets.

The following table shows the accounts receivable and unbilled revenues balances that were impaired for the periods ended March 31.

	Three Months
	2025		2024
PPL (a)	$	25	$	42
PPL Electric (a)	7		28
LG&E	2		1
KU	1		1

(a)2024 includes amounts impaired related to PPL Electric's billing issues.

Contract liabilities result from recording contractual billings in advance for customer attachments to the Registrants' infrastructure and payments received in excess of revenues earned to date. Advanced billings for customer attachments are generally recognized as revenue ratably over the quarterly billing period. Payments received in excess of revenues earned to date are recognized as revenue as services are delivered in subsequent periods. PPL's contract liabilities are not material at March 31, 2025 and 2024.

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Acquisitions, Development and Divestitures

3 Months Ended

Mar. 31, 2025

Business Combination [Abstract]

Mergers, Acquisitions and Dispositions Disclosures

8. Acquisitions, Developments and Divestitures

Acquisitions (PPL)

Acquisition of Narragansett Electric

On May 25, 2022, PPL Rhode Island Holdings acquired 100% of the outstanding shares of common stock of Narragansett Electric from National Grid USA, a subsidiary of National Grid plc (the Acquisition). Following the closing of the Acquisition, Narragansett Electric provides services doing business under the name Rhode Island Energy (RIE). Please see Note 9 in PPL's 2024 Form 10-K for additional information concerning the Acquisition.

In connection with the Acquisition, National Grid USA Service Company, Inc., National Grid USA and Narragansett Electric entered into a transition services agreement (TSA), pursuant to which the National Grid entities agreed to provide certain transition services to Narragansett Electric to facilitate the transition of the operation of Narragansett Electric to PPL following the Acquisition, as agreed upon in the Narragansett share purchase agreement. The TSA was for an initial two-year term and was completed in the third quarter of 2024. TSA costs were $48 million during the three months ended March 31, 2024.

As a condition to the Acquisition, PPL made certain commitments to the Rhode Island Division of Public Utilities and Carriers and the Attorney General of the State of Rhode Island. See Note 9 in PPL's 2024 Form 10-K for a complete listing of those commitments. Included in these commitments is RIE's commitment to forgo potential recovery of any and all transition costs, which includes (1) the installation of certain information technology systems; (2) modification and enhancements to physical facilities in Rhode Island; and (3) costs related to severance payments, communications and branding changes, and other transition related costs. These costs, which are being expensed as incurred, were $17 million and $81 million for the three months ended March 31, 2025 and 2024.

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Other Income (Expense) - net

3 Months Ended

Mar. 31, 2025

Other Income (Expense) Net [Line Items]

Other Income (Expense) - net

12. Other Income (Expense) - net

(PPL)

The details of "Other Income (Expense) - net" for the periods ended March 31, were:

	Three Months
	2025		2024
Defined benefit plans - non-service credits (Note 9)	$	8	$	8
Interest income	5		9
AFUDC - equity component	16		9
Charitable contributions	(2)		(2)
Miscellaneous	1		(2)
Other Income (Expense) - net	$	28	$	22

(PPL Electric)

The details of "Other Income (Expense) - net" for the periods ended March 31, were:

	Three Months
	2025		2024
Defined benefit plans - non-service credits (Note 9)	$	3	$	4
Interest income	2		1
AFUDC - equity component	7		5
Charitable contributions	(1)		(1)
Other Income (Expense) - net	$	11	$	9

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New Accounting Guidance Pending Adoption

3 Months Ended

Mar. 31, 2025

Accounting Policies [Abstract]

Accounting Standards Update and Change in Accounting Principle

17. New Accounting Guidance Pending Adoption

(All Registrants)

Improvements to Income Tax Disclosures

In December 2023, the FASB issued ASU 2023-09 which requires public business entities to provide additional income tax disclosures, including a disaggregated rate reconciliation as well as information on income taxes paid.

For public business entities, this guidance will be applied on a prospective basis. Retrospective application is permitted. This guidance will be effective for annual periods beginning after December 15, 2024. Early adoption is permitted for annual financial statements that have not yet been issued or made available for issuance.

The Registrants are currently assessing the impact of adopting this guidance.

Disaggregation of Income Statement Expenses

In November 2024, the FASB issued guidance which requires public business entities to provide in the notes to financial statements specified information about certain costs and expenses. This includes the disclosure of amounts of (a) purchases of inventory, (b) employee compensation, (c) depreciation, (d) intangible asset amortization, and (e) depreciation, depletion, and amortization recognized as part of oil and gas-producing activities included in each relevant income statement expense caption. A relevant expense caption is an expense caption included on the face of the income statement within continuing operations that contains any of the specified expense categories (a)-(e). A qualitative description of the amounts remaining in relevant expense captions that are not separately disaggregated must also be disclosed. Additionally, public business entities must disclose the total amount of selling expenses and, in annual reporting periods, the entity’s definition of selling expenses.

For public business entities, this guidance will be applied on a prospective basis. Retrospective application is permitted. This guidance will be effective for annual periods beginning after December 15, 2026, and interim periods beginning after December 15, 2027. Early adoption is permitted.

The Registrants are currently assessing the impact of adopting this guidance.

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Pay vs Performance Disclosure - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2025	Mar. 31, 2024
Pay vs Performance Disclosure
Net income (loss)	$ 414	$ 307

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Insider Trading Arrangements	3 Months Ended
	Mar. 31, 2025
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	true
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

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Derivative Instruments and Hedging Activities (Policies)

3 Months Ended

Mar. 31, 2025

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives, Offsetting Fair Value Amounts, Policy

Net derivative positions on the balance sheets are not offset against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements.

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Adoption of Accounting Guidance (Tables)

3 Months Ended

Mar. 31, 2025

Summary Of Significant Accounting Policies [Line Items]

Financing Receivable, Allowance for Credit Loss [Table Text Block]

Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement

The following provides a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the Balance Sheets that sum to the total of the same amounts shown on the Statements of Cash Flows:

	PPL
	March 31, 2025		December 31, 2024
Cash and cash equivalents	$	312	$	306
Restricted cash - current (a)	42		1
Total Cash, Cash Equivalents and Restricted Cash	$	354	$	307

(a)Bank deposits and other cash equivalents that are restricted by agreement or that have been clearly designated for a specific purpose are classified as restricted cash. On the Balance Sheets, the current portion of restricted cash is included in "Other current assets."

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Segment and Related Information (Tables)

3 Months Ended

Mar. 31, 2025

Segment Reporting [Abstract]

Segment and Related Information

The table below provides information about PPL’s segments and includes the reconciliation to consolidated net income for the three months ended March 31, 2025:

	Kentucky Regulated		Pennsylvania Regulated		Rhode Island Regulated		Total
Operating Revenues from external customers (a)	$	1,059	$	819	$	626	$	2,504
Reconciliation of revenue
Corporate and Other revenues							—
Total consolidated revenues							$	2,504
Less:
Fuel	234		—		—		234
Energy Purchases	96		229		235		560
Other operation and maintenance	200		162		200		562
Depreciation	176		102		42		320
Taxes, other than income	25		41		47		113
Other (income) expense - net	(8)		(11)		(7)		(26)
Interest (income) from affiliate	—		(2)		(2)		(4)
Interest expense	60		60		23		143
Income taxes	53		54		18		125
Segment net income	$	223	$	184	$	70	$	477
Reconciliation of segment profit or loss to consolidated net income
Corporate and Other net loss							(63)
Net Income							$	414

(a)See Note 3 for additional information on Operating Revenues.

Other information for the segments and reconciliation to PPL's Consolidated results for the three months ended March 31, 2025 are as follows:

	Kentucky Regulated		Pennsylvania Regulated		Rhode Island Regulated		Total Segments		Corporate and Other		Consolidated Total
Other Segment Disclosures
Amortization (a)	$	5	$	11	$	—	$	16	$	4	$	20
Deferred income taxes and investment tax credits (b)	8		20		(7)		21		17		38
Expenditures for long lived assets	290		328		172		790		3		793

(a)Represents non-cash expense items that include amortization of operating lease right-of-use assets, regulatory assets and liabilities, debt discounts and premiums and debt issuance costs.

(b)Represents a non-cash expense item that is also included in "Income Taxes."

The table below provides information about PPL’s segments and includes the reconciliation to consolidated net income for the three months ended March 31, 2024:

	Kentucky Regulated		Pennsylvania Regulated		Rhode Island Regulated		Total
Operating Revenues from external customers (a)	$	984	$	770	$	549	$	2,303
Reconciliation of revenue
Corporate and Other revenues							1
Total consolidated revenues							$	2,304
Less:
Fuel	209		—		—		209
Energy Purchases	77		214		229		520
Other operation and maintenance	202		181		156		539
Depreciation	176		99		41		316
Taxes, other than income	25		36		27		88
Other (income) expense - net	(3)		(9)		(7)		(19)
Interest (income) from affiliate	—		(10)		—		(10)
Interest expense	60		62		24		146
Income taxes	48		48		15		111
Segment net income	$	190	$	149	$	64	$	403
Reconciliation of segment profit or loss to consolidated net income
Corporate and Other net loss							(96)
Net Income							$	307

(a)See Note 3 for additional information on Operating Revenues.

Other information for the segments and reconciliation to PPL's Consolidated results for the three months ended March 31, 2024 are as follows:

	Kentucky Regulated		Pennsylvania Regulated		Rhode Island Regulated		Total Segments		Corporate and Other		Consolidated Total
Other Segment Disclosures
Amortization (a)	$	8	$	12	$	—	$	20	$	4	$	24
Deferred income taxes and investment tax credits (b)	4		32		18		54		18		72
Expenditures for long lived assets	241		229		125		595		1		596

(a)Represents non-cash expense items that include amortization of operating lease right-of-use assets, regulatory assets and liabilities, debt discounts and premiums and debt issuance costs.

(b)Represents a non-cash expense item that is also included in "Income Taxes."

The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated Balance Sheets as of:

	March 31, 2025		December 31, 2024
Total Assets
Kentucky Regulated	$	17,789	$	17,626
Pennsylvania Regulated	15,654		15,475
Rhode Island Regulated	7,194		7,055
Corporate and Other (a)	1,172		913
Total	$	41,809	$	41,069

(a)Primarily consists of unallocated items, including cash, PP&E, goodwill and the elimination of inter-segment transactions.

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Revenue from Contracts with Customers (Tables)

3 Months Ended

Mar. 31, 2025

Revenue from Contracts with Customers [Line Items]

Reconciliation of Revenue from Contracts with Customers [Table Text Block]

The following tables reconcile "Operating Revenues" included in each Registrant's Statement of Income with revenues generated from contracts with customers for the periods ended March 31.

	2025 Three Months
	PPL		PPL Electric		LG&E		KU
Operating Revenues (a)(b)	$	2,504	$	819	$	505	$	564
Revenues derived from:
Alternative revenue programs (c)	50		(2)		2		4
Other (d)	(9)		(5)		(1)		(2)
Revenues from Contracts with Customers	$	2,545	$	812	$	506	$	566
	2024 Three Months
	PPL		PPL Electric		LG&E		KU
Operating Revenues (a)(b)	$	2,304	$	770	$	476	$	525
Revenues derived from:
Alternative revenue programs (c)	7		(3)		2		5
Other (d)	(8)		(5)		(1)		(1)
Revenues from Contracts with Customers	$	2,303	$	762	$	477	$	529

(a)PPL includes $626 million for the three months ended March 31, 2025 and $549 million for the three months ended March 31, 2024 of revenues from external customers reported by the Rhode Island Regulated segment. PPL Electric represents revenues from external customers reported by the Pennsylvania Regulated segment and LG&E and KU, net of intercompany power sales and transmission revenues, represent revenues from external customers reported by the Kentucky Regulated segment. See Note 2 for additional information.

(b)PPL's transition services agreement associated with the RIE acquisition ended in the third quarter of 2024. In conjunction with the completion of the agreement, PPL conformed the presentation of RIE's and the Rhode Island Regulated segment’s net metering charges with the presentation of the other segments, resulting in an increase in Operating Revenues and a corresponding increase in Energy purchases beginning in the fourth quarter of 2024. For the quarter ended March 31, 2025, net metering of $41 million was included in Energy purchases on PPL's Statement of Income. For the quarter ended March 31, 2024, $32 million of net metering was presented as a reduction of Operating Revenues on PPL's Statement of Income.

(c)This line item shows the over/under collection of rate mechanisms deemed alternative revenue programs with over-collections of revenue shown as positive amounts in the table above and under-collections shown as negative amounts.

(d)Represents additional revenues outside the scope of revenues from contracts with customers, such as lease and other miscellaneous revenues.

Disaggregation of Revenue [Table Text Block]

The following tables show revenues from contracts with customers disaggregated by customer class for the periods ended March 31.

	Three Months
	Residential		Commercial		Industrial		Other (a)		Wholesale - municipality		Wholesale - other (b)		Transmission		Revenues from Contracts with Customers
PPL
2025
PA Regulated	$	457	$	106	$	13	$	13	$	—	$	—	$	223	$	812
KY Regulated	487		280		154		96		7		38		—		1,062
RI Regulated (c)	441		197		18		(35)		—		—		50		671
Total PPL	$	1,385	$	583	$	185	$	74	$	7	$	38	$	273	$	2,545
2024
PA Regulated	$	426	$	106	$	12	$	13	$	—	$	—	$	205	$	762
KY Regulated	443		267		161		97		6		15		—		989
RI Regulated (c)	261		78		4		161		—		—		47		551
Corp and Other	—		—		—		1		—		—		—		1
Total PPL	$	1,130	$	451	$	177	$	272	$	6	$	15	$	252	$	2,303
PPL Electric
2025	$	457	$	106	$	13	$	13	$	—	$	—	$	223	$	812
2024	$	426	$	106	$	12	$	13	$	—	$	—	$	205	$	762
LG&E
2025	$	239	$	147	$	46	$	54	$	—	$	20	$	—	$	506
2024	$	218	$	138	$	47	$	52	$	—	$	22	$	—	$	477
KU
2025	$	248	$	133	$	108	$	42	$	7	$	28	$	—	$	566
2024	$	225	$	129	$	114	$	46	$	6	$	9	$	—	$	529

(a)Primarily includes revenues from pole attachments, street lighting, other public authorities and other non-core businesses, and for the Rhode Island Regulated Segment certain regulatory deferral mechanisms which could result in a reduction in revenues from over collections. For the period ended 2024, the Rhode Island Regulated segment primarily includes open access tariff revenues, which are calculated on combined customer classes.

(b)Includes wholesale power and transmission revenues. LG&E and KU amounts include intercompany power sales and transmission revenues, which are eliminated upon consolidation at the Kentucky Regulated segment.

(c)PPL's transition services agreement associated with the RIE acquisition ended in the third quarter of 2024. In conjunction with the completion of the agreement, PPL disaggregated the 2024 revenues of the Rhode Island Regulated segment in a manner consistent with that of its other segments. This resulted in certain customer revenues for the Rhode Island Regulated segment, which were previously presented in the "Other" category, being presented in the "Residential", "Commercial" or "Industrial" customer classes beginning in the fourth quarter of 2024. Applying the previous methodology to 2025 revenues would result in $155 million of Residential, $89 million of Commercial and $13 million of Industrial for the Rhode Island Regulated segment being presented as "Other" for the three months ended March 31, 2025.

Credit Loss Recognized from Contracts with Customers [Table Text Block]

The following table shows the accounts receivable and unbilled revenues balances that were impaired for the periods ended March 31.

	Three Months
	2025		2024
PPL (a)	$	25	$	42
PPL Electric (a)	7		28
LG&E	2		1
KU	1		1

(a)2024 includes amounts impaired related to PPL Electric's billing issues.

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Earnings Per Share (Tables)

3 Months Ended

Mar. 31, 2025

Earnings Per Share [Abstract]

Basic and Diluted EPS Computations

Reconciliations of the amounts of income and shares of PPL common stock (in thousands) for the periods ended March 31 used in the EPS calculation are:

	Three Months
	2025		2024
Income (Numerator)
Net income attributable to PPL	$	414	$	307
Less amounts allocated to participating securities	1		—
Net income available to PPL common shareowners - Basic and Diluted	$	413	$	307
Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS	738,691		737,512
Add: Dilutive share-based payment awards (a)	2,709		1,308
Weighted-average shares - Diluted EPS	741,400		738,820
Basic and Diluted EPS
Net Income available to PPL common shareowners	$	0.56	$	0.42

(a)    The Treasury Stock Method was applied to non-participating share-based payment awards.

For the periods ended March 31, PPL issued common stock related to stock-based compensation plans as follows (in thousands):

Common Stock Issuances

	Three Months
	2025	2024
DRIP	200	—

Antidilutive Securities Excluded From Diluted EPS

For the periods ended March 31, the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive.

	Three Months
	2025	2024
Stock-based compensation awards	175	—
Forward sale agreements	2,033	—

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Income Taxes (Tables)

3 Months Ended

Mar. 31, 2025

Income Taxes [Line Items]

Schedule of Effective Income Tax Rate Reconciliation

Reconciliations of income tax expense (benefit) for the periods ended March 31 are as follows.

(PPL)
	Three Months
	2025		2024
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	108	$	81
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	20		17
Utility rate-making tax adjustments (a)	(10)		(5)
Amortization of excess deferred federal and state income taxes	(15)		(13)
Other	(1)		1
Total increase (decrease)	(6)		—
Total income tax expense (benefit)	$	102	$	81

(a)     Primarily consists of tax impacts of AFUDC equity and related depreciation across PPL's regulated utility subsidiaries and flow through tax impacts of Pennsylvania utility ratemaking. Flow through occurs when the regulator excludes deferred tax expense or benefit from recoverable costs when determining income tax expense.

PPL Electric Utilities Corp [Member]

Income Taxes [Line Items]

Schedule of Effective Income Tax Rate Reconciliation

Reconciliations of income tax expense (benefit) for the periods ended March 31 are as follows.

(PPL Electric)
	Three Months
	2025		2024
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	50	$	41
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	15		14
Utility rate-making tax adjustments (a)	(6)		(4)
Amortization of excess deferred federal and state income taxes	(3)		(2)
Other	(2)		(1)
Total increase (decrease)	4		7
Total income tax expense (benefit)	$	54	$	48

(a)     Primarily consists of tax impacts of AFUDC equity and related depreciation and flow through tax impacts of Pennsylvania utility ratemaking. Flow through occurs when the regulator excludes deferred tax expense or benefit from recoverable costs when determining income tax expense.

Louisville Gas And Electric Co [Member]

Income Taxes [Line Items]

Schedule of Effective Income Tax Rate Reconciliation

Reconciliations of income tax expense (benefit) for the periods ended March 31 are as follows.

(LG&E)
	Three Months
	2025		2024
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	27	$	25
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	5		4
Amortization of excess deferred federal and state income taxes	(4)		(3)
Other	(2)		(2)
Total increase (decrease)	(1)		(1)
Total income tax expense (benefit)	$	26	$	24

Kentucky Utilities Co [Member]

Income Taxes [Line Items]

Schedule of Effective Income Tax Rate Reconciliation

Reconciliations of income tax expense (benefit) for the periods ended March 31 are as follows.

(KU)
	Three Months
	2025		2024
Federal income tax on Income Before Income Taxes at statutory tax rate - 21%	$	33	$	28
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	6		5
Amortization of excess deferred federal and state income taxes	(5)		(5)
Other	(3)		(1)
Total increase (decrease)	(2)		(1)
Total income tax expense (benefit)	$	31	$	27

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Utility Rate Regulation (Tables)

3 Months Ended

Mar. 31, 2025

Utility Rate Regulation [Line Items]

Regulatory Assets and Liabilities

The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations.

	PPL				PPL Electric				LG&E				KU
	March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024
Current Regulatory Assets:
Rate adjustment mechanisms	$	74	$	95	$	—	$	—	$	—	$	—	$	—	$	—
Renewable energy certificates	16		14		—		—		—		—		—		—
Storm damage expense rider	46		68		46		68		—		—		—		—
Gas supply clause	23		3		—		—		23		3		—		—
Transmission service charge	35		44		—		27		—		—		—		—
Transmission formula rate	13		14		3		2		—		—		—		—
DSIC	9		8		9		8		—		—		—		—
TCJA customer refund and recovery	28		21		28		21		—		—		—		—
ISR deferral	10		22		—		—		—		—		—		—
Gas line tracker	5		4		—		—		5		4		—		—
Other	15		27		8		7		3		1		—		1
Total current regulatory assets	$	274	$	320	$	94	$	133	$	31	$	8	$	—	$	1

	PPL				PPL Electric				LG&E				KU
	March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024
Noncurrent Regulatory Assets:
Defined benefit plans	$	962	$	967	$	472	$	473	$	223	$	226	$	147	$	149
Plant outage costs	29		30		—		—		7		7		22		23
Net metering	147		147		—		—		—		—		—		—
Environmental cost recovery	96		96		—		—		—		—		—		—
Storm costs	116		113		41		22		22		20		36		29
Unamortized loss on debt	20		20		3		3		9		9		6		6
Terminated interest rate swaps	51		53		—		—		30		31		21		22
Accumulated cost of removal of utility plant	165		173		165		173		—		—		—		—
AROs	278		280		—		—		76		75		202		205
Retired asset recovery	83		83		—		—		83		83		—		—
Gas line inspections	24		24		—		—		22		22		2		2
Advanced metering infrastructure	31		28		—		—		15		14		16		14
Other	47		46		4		2		4		4		8		8
Total noncurrent regulatory assets	$	2,049	$	2,060	$	685	$	673	$	491	$	491	$	460	$	458

	PPL				PPL Electric				LG&E				KU
	March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024
Current Regulatory Liabilities:
Generation supply charge	$	45	$	52	$	45	$	52	$	—	$	—	$	—	$	—
Environmental cost recovery	9		12		—		—		4		6		5		6
Rate adjustment mechanisms	63		71		—		—		—		—		—		—
Energy efficiency	24		25		—		—		—		—		—		—
DSM	24		17		—		—		10		7		14		10
Revenue decoupling mechanism	40		10		—		—		—		—		—		—
Deferred revenue	25		—		—		—		—		—		—		—
Derivative instruments	15		—		—		—		—		—		—		—
Other	29		36		9		5		2		1		7		6
Total current regulatory liabilities	$	274	$	223	$	54	$	57	$	16	$	14	$	26	$	22
Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	1,027	$	1,022	$	—	$	—	$	318	$	314	$	409	$	408
Net deferred taxes	1,875		1,899		729		739		434		439		491		498
Defined benefit plans	296		294		106		100		24		24		66		65
Terminated interest rate swaps	54		54		—		—		27		27		27		27
Energy efficiency	28		16		—		—		—		—		—		—
Other	58		50		—		—		11		11		14		11
Total noncurrent regulatory liabilities	$	3,338	$	3,335	$	835	$	839	$	814	$	815	$	1,007	$	1,009

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Financing Activities (Tables)

3 Months Ended

Mar. 31, 2025

Debt Disclosure [Abstract]

Schedule of Line of Credit Facilities

The following credit facilities were in place at:

	March 31, 2025									December 31, 2024
	Expiration Date	Capacity		Borrowed		Letters of Credit and Commercial Paper Issued (c)		Unused Capacity		Borrowed		Letters of Credit and Commercial Paper Issued (c)
PPL
PPL Capital Funding (a)
Syndicated Credit Facility (b)	Dec. 2029	$	1,500	$	—	$	427	$	1,073	$	—	$	138
Bilateral Credit Facility	Feb. 2026	100		—		—		100		—		—
Bilateral Credit Facility	Feb. 2026	100		—		55		45		—		15
Total PPL Capital Funding Credit Facilities		$	1,700	$	—	$	482	$	1,218	$	—	$	153
PPL Electric
Syndicated Credit Facility	Dec. 2029	$	750	$	—	$	56	$	694	$	—	$	1
Total PPL Electric Credit Facilities		$	750	$	—	$	56	$	694	$	—	$	1
LG&E
Syndicated Credit Facility	Dec. 2029	$	600	$	—	$	89	$	511	$	—	$	25
Total LG&E Credit Facilities		$	600	$	—	$	89	$	511	$	—	$	25
KU
Syndicated Credit Facility	Dec. 2029	$	600	$	—	$	209	$	391	$	—	$	140
Total KU Credit Facilities		$	600	$	—	$	209	$	391	$	—	$	140

(a)PPL Capital Funding's obligations are fully and unconditionally guaranteed by PPL.

(b)In January 2025, PPL Capital Funding increased the borrowing capacity of this facility from $1.25 billion to $1.50 billion. At March 31, 2025, the facility included a $250 million borrowing sublimit for RIE and a $1.25 billion sublimit for PPL Capital Funding. At December 31, 2024, the facility included a $250 million borrowing sublimit for RIE and a $1 billion borrowing sublimit for PPL Capital Funding. RIE’s borrowing sublimit is adjustable, at the borrowers’ option, from $0 to $600 million, with the remaining balance available under the facility allocated to PPL Capital Funding. At March 31, 2025, PPL Capital Funding had $427 million of commercial paper outstanding and RIE had no commercial paper outstanding. At December 31, 2024, PPL Capital Funding had $138 million of commercial paper outstanding and RIE had no commercial paper outstanding. RIE's obligations under the facility are not guaranteed by PPL.

(c)Commercial paper issued reflects the undiscounted face value of the issuance.

Schedule of Short-term Debt

The following commercial paper programs were in place at:

	March 31, 2025							December 31, 2024
	Weighted - Average Interest Rate	Capacity		Commercial Paper Issuances (c)		Unused Capacity		Weighted - Average Interest Rate	Commercial Paper Issuances (c)
PPL Capital Funding (a)(b)	4.71%	$	1,350	$	427	$	923	4.76%	$	138
RIE (b)		250		—		250			—
PPL Electric	4.68%	650		55		595			—
LG&E	4.67%	500		89		411		4.72%	25
KU	4.71%	400		209		191		4.71%	140
Total		$	3,150	$	780	$	2,370		$	303

(a)PPL Capital Funding's obligations are fully and unconditionally guaranteed by PPL.

(b)Issuances under the PPL Capital Funding and RIE commercial paper programs are supported by the PPL Capital Funding syndicated credit facility. At March 31, 2025, the borrowing sublimits were $250 million for RIE and $1.25 billion for PPL Capital Funding. At December 31, 2024, the borrowing sublimits were $250 million for RIE and $1 billion for PPL Capital Funding. PPL Capital Funding’s commercial paper program is also backed by a separate bilateral credit facility for $100 million.

(c)Commercial paper issued reflects the undiscounted face value of the issuance.

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Defined Benefits (Tables)

3 Months Ended

Mar. 31, 2025

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Schedule Of Net Periodic Defined Benefit Costs (Credits)

Following are the net periodic defined benefit costs (credits) of the plans sponsored by PPL and its subsidiaries for the periods ended March 31:

	Pension Benefits
	Three Months
	2025		2024
PPL
Service cost	$	8	$	9
Interest cost	45		46
Expected return on plan assets	(72)		(75)
Amortization of:
Prior service cost	—		1
Actuarial loss	5		2
Net periodic defined benefit costs (credits)	$	(14)	$	(17)

	Other Postretirement Benefits
	Three Months
	2025		2024
PPL
Service cost	$	2	$	1
Interest cost	7		7
Expected return on plan assets	(8)		(7)
Amortization of:
Actuarial loss	(1)		(1)
Net periodic defined benefit costs (credits)	$	—	$	—

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Commitments and Contingencies (Tables)

3 Months Ended

Mar. 31, 2025

Commitments and Contingencies Disclosure [Abstract]

Guarantees

The table below details guarantees provided as of March 31, 2025.

	Exposure at March 31, 2025			Expiration Date
PPL
Indemnifications related to certain tax liabilities related to the sale of the U.K. utility business	£	50	(a)	2028
PPL guarantee of Safari payment obligations under certain sale/leaseback financing transactions related to the sale of Safari Holdings	$	97	(b)	2028
Indemnifications for losses suffered related to items not covered by Aspen Power's representation and warranty insurance associated with the sale of Safari Holdings	140		(c)	2028
LG&E and KU
LG&E and KU obligation of shortfall related to OVEC			(d)

(a)PPL WPD Limited entered into a Tax Deed dated June 9, 2021, in which it agreed to a tax indemnity regarding certain potential tax liabilities of the entities sold with respect to periods prior to the completion of the sale, subject to customary exclusions and limitations. Because National Grid Holdings One plc, the buyer, agreed to purchase indemnity insurance, the amount of the cap on the indemnity for these liabilities is £1, except with respect to certain surrenders of tax losses, for which the amount of the cap on the indemnity is £50 million.

(b)PPL guaranteed the payment obligations of Safari under certain sale/leaseback financing transactions executed by Safari. These guarantees will remain in place until Safari exercises its option to buy-out the projects under the sale/leaseback financings by the year 2028. Safari will indemnify PPL for any payments made by PPL or claims against PPL under the sale/leaseback transaction guarantees up to $25 million.

(c)Aspen Power has obtained representation and warranty insurance, therefore, PPL generally has no liability for its representations and warranties under the agreement except for losses suffered related to items not covered. Expiration of these indemnifications range from 18 months to 6 years from the date of the closing of the transaction, and PPL’s aggregate liability for these claims will not exceed $140 million, subject to certain adjustments.

(d)Pursuant to the OVEC power purchase contract, LG&E and KU are obligated to pay for their share of OVEC's excess debt service, post-retirement, and decommissioning costs, as well as any shortfall from amounts included within a demand charge designed and expected to cover these costs over the term of the contract. PPL's proportionate share of OVEC's outstanding debt was $77 million at March 31, 2025, consisting of LG&E's share of $53 million and KU's share of $24 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchase Commitments" in Note 12 in PPL's, LG&E's and KU's 2024 Form 10-K for additional information on the OVEC power purchase contract.

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Related Party Transactions (Tables)

3 Months Ended

Mar. 31, 2025

PPL Electric Utilities Corp [Member]

Related Party Transactions [Line Items]

Intercompany Support Cost Allocations

PPL Services and LKS charged the following amounts for the periods ended March 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable.

	Three Months
	2025		2024
PPL Electric from PPL Services	$	64	$	56
LG&E from LKS	30		29
LG&E from PPL Services	20		11
KU from LKS	38		38
KU from PPL Services	19		11

Louisville Gas And Electric Co [Member]

Related Party Transactions [Line Items]

Intercompany Support Cost Allocations

PPL Services and LKS charged the following amounts for the periods ended March 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable.

	Three Months
	2025		2024
PPL Electric from PPL Services	$	64	$	56
LG&E from LKS	30		29
LG&E from PPL Services	20		11
KU from LKS	38		38
KU from PPL Services	19		11

Kentucky Utilities Co [Member]

Related Party Transactions [Line Items]

Intercompany Support Cost Allocations

PPL Services and LKS charged the following amounts for the periods ended March 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable.

	Three Months
	2025		2024
PPL Electric from PPL Services	$	64	$	56
LG&E from LKS	30		29
LG&E from PPL Services	20		11
KU from LKS	38		38
KU from PPL Services	19		11

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Other Income (Expense) - net (Tables)

3 Months Ended

Mar. 31, 2025

Other Income (Expense) Net [Line Items]

Schedule of Other Nonoperating Income (Expense)

The details of "Other Income (Expense) - net" for the periods ended March 31, were:

	Three Months
	2025		2024
Defined benefit plans - non-service credits (Note 9)	$	8	$	8
Interest income	5		9
AFUDC - equity component	16		9
Charitable contributions	(2)		(2)
Miscellaneous	1		(2)
Other Income (Expense) - net	$	28	$	22

PPL Electric Utilities Corp [Member]

Other Income (Expense) Net [Line Items]

Schedule of Other Nonoperating Income (Expense)

The details of "Other Income (Expense) - net" for the periods ended March 31, were:

	Three Months
	2025		2024
Defined benefit plans - non-service credits (Note 9)	$	3	$	4
Interest income	2		1
AFUDC - equity component	7		5
Charitable contributions	(1)		(1)
Other Income (Expense) - net	$	11	$	9

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Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2025

Fair Value Disclosures [Abstract]

Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis

The assets and liabilities measured at fair value were:

	March 31, 2025								December 31, 2024
	Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3
PPL
Assets
Cash and cash equivalents	$	312	$	312	$	—	$	—	$	306	$	306	$	—	$	—
Restricted cash and cash equivalents (a)	28		28		—		—		33		33		—		—
Total Cash, Cash Equivalents and Restricted Cash (b)	340		340		—		—		339		339		—		—
Special use funds (a):
Money market fund	1		1		—		—		1		1		—		—
Commingled debt fund measured at NAV (c)	8		—		—		—		10		—		—		—
Commingled equity fund measured at NAV (c)	7		—		—		—		8		—		—		—
Total special use funds	16		1		—		—		19		1		—		—
Price risk management assets (d):
Gas contracts	22		—		22		—		9		—		4		5
Total assets	$	378	$	341	$	22	$	—	$	367	$	340	$	4	$	5
Liabilities
Price risk management liabilities (d):
Interest rate swaps	$	5	$	—	$	5	$	—	$	3	$	—	$	3	$	—
Gas contracts	6		—		—		6		13		—		10		3
Total price risk management liabilities	$	11	$	—	$	5	$	6	$	16	$	—	$	13	$	3
PPL Electric
Assets
Cash and cash equivalents	$	27	$	27	$	—	$	—	$	24	$	24	$	—	$	—
Total assets	$	27	$	27	$	—	$	—	$	24	$	24	$	—	$	—
LG&E
Assets
Cash and cash equivalents	$	10	$	10	$	—	$	—	$	8	$	8	$	—	$	—
Restricted cash and cash equivalents (a)	13		13		—		—		16		16		—		—
Total Cash, Cash Equivalents and Restricted Cash (b)	23		23		—		—		24		24		—		—
Total assets	$	23	$	23	$	—	$	—	$	24	$	24	$	—	$	—
Liabilities
Price risk management liabilities:
Interest rate swaps	$	5	$	—	$	5	$	—	$	3	$	—	$	3	$	—
Total price risk management liabilities	$	5	$	—	$	5	$	—	$	3	$	—	$	3	$	—
KU
Assets
Cash and cash equivalents	$	14	$	14	$	—	$	—	$	13	$	13	$	—	$	—
Restricted cash and cash equivalents (a)	13		13		—		—		16		16		—		—
Total Cash, Cash Equivalents and Restricted Cash (b)	27		27		—		—		29		29		—		—
Total assets	$	27	$	27	$	—	$	—	$	29	$	29	$	—	$	—

(a)Current portion is included in "Other current assets" and noncurrent portion is included in "Other noncurrent assets" on the Balance Sheets.

(b)Total Cash, Cash Equivalents and Restricted Cash provides a reconciliation of these items reported within the Balance Sheets to the sum shown on the Statements of Cash Flows.

(c)In accordance with accounting guidance, certain investments that are measured at fair value using net asset value per share (NAV), or its equivalent, have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the Balance Sheets.

(d)Current portion is included in "Other current assets" and "Other current liabilities" and noncurrent portion is included in "Other noncurrent assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets.

A reconciliation of net liabilities classified as Level 3 for the three months ended March 31 is as follows:

	Gas Contracts
2025
Balance at beginning of period	$	(2)
Total unrealized gains (losses) recognized as Regulatory Assets/Regulatory Liabilities:	8
Settlements	—
Balance at end of period	$	6

Fair Value, by Balance Sheet Grouping

The carrying amounts of long-term debt on the Balance Sheets and their estimated fair values are set forth below.

	March 31, 2025				December 31, 2024
	Carrying Amount (a)		Fair Value		Carrying Amount (a)		Fair Value
PPL	$	16,507	$	15,847	$	16,503	$	15,562
PPL Electric	5,214		4,931		5,214		4,862
LG&E	2,471		2,335		2,471		2,295
KU	3,066		2,804		3,066		2,750

(a)Amounts are net of debt issuance costs.

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Derivative Instruments and Hedging Activities (Tables)

3 Months Ended

Mar. 31, 2025

Mar. 31, 2024

Derivative Instruments And Hedging Activities [Line Items]

Schedule of Derivative Instruments in Statement of Financial Position, Fair Value

The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments.

	March 31, 2025				December 31, 2024
	Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management Assets/Liabilities (a):
Interest rate swaps	$	—	$	1	$	—	$	—
Gas contracts	16		1		7		10
Total current	16		2		7		10
Noncurrent:
Price Risk Management Assets/Liabilities (a):
Interest rate swaps	—		4		—		3
Gas contracts	6		5		2		3
Total noncurrent	6		9		2		6
Total derivatives	$	22	$	11	$	9	$	16

(a)Current portion is included in "Other current assets" and "Other current liabilities" and noncurrent portion is included in "Other noncurrent assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets. Excludes accrued interest, if applicable.

Derivative Instruments, Gain (Loss)

The following table presents the effect of cash flow hedge activity on the Statement of Income for the period ended March 31, 2025.

	Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships
	Three Months
	Interest Expense
Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded	$	190
The effects of cash flow hedges:
Gain (Loss) on cash flow hedging relationships:
Interest rate swaps:
Amount of gain (loss) reclassified from AOCI to income	(1)

The following table presents the effect of cash flow hedge activity on the Statement of Income for the period ended March 31, 2024.

	Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships
	Three Months
	Interest Expense
Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded	$	179
The effects of cash flow hedges:
Gain (Loss) on cash flow hedging relationships:
Interest rate swaps:
Amount of gain (loss) reclassified from AOCI to income	(1)

Derivative Positions Eligible for Offset with Related Cash Collateral

The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged.

	Assets								Liabilities
			Eligible for Offset								Eligible for Offset
	Gross		Derivative Instruments		Cash Collateral Received		Net		Gross		Derivative Instruments		Cash Collateral Pledged		Net
March 31, 2025
Derivatives
PPL	$	22	$	1	$	—	$	21	$	11	$	1	$	—	$	10
LG&E	—		—		—		—		5		—		—		5

	Assets								Liabilities
			Eligible for Offset								Eligible for Offset
	Gross		Derivative Instruments		Cash Collateral Received		Net		Gross		Derivative Instruments		Cash Collateral Pledged		Net
December 31, 2024
Derivatives
PPL	$	9	$	5	$	—	$	4	$	16	$	5	$	—	$	11
LG&E	—		—		—		—		3		—		—		3

Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location

The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities for the period ended March 31, 2025.

		Three Months
Derivative Relationships	Location of Gain (Loss) Recognized in Income on Derivative	Gain (Loss) Reclassified from AOCI into Income
Cash Flow Hedges:
Interest rate swaps	Interest expense	$	(1)

Derivatives Not Designated as Hedging Instruments	Location of Gain (Loss) Recognized in Income on Derivative	Three Months
Gas contracts	Energy purchases	$	(5)
	Total	$	(5)
Derivatives Not Designated as Hedging Instruments	Location of Gain (Loss) Recognized as Regulatory Liabilities/Assets	Three Months
Interest rate swaps	Regulatory assets - noncurrent	$	(1)
Gas contracts	Regulatory liabilities - current	18
	Regulatory liabilities - noncurrent	1
	Total	$	18

The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities for the period ended March 31, 2024.

	Three Months			Three Months
Derivative Relationships	Derivative Gain (Loss) Recognized in OCI		Location of Gain (Loss) Recognized in Income on Derivative	Gain (Loss) Reclassified from AOCI into Income
Cash Flow Hedges:
Interest rate swaps	$	—	Interest expense	$	(1)

Derivatives Not Designated as Hedging Instruments	Location of Gain (Loss) Recognized in Income on Derivative	Three Months
Gas contracts	Energy purchases	$	(16)
	Total	$	(16)
Derivatives Not Designated as Hedging Instruments	Location of Gain (Loss) Recognized as Regulatory Liabilities/Assets	Three Months
Interest rate swaps	Regulatory assets - noncurrent	$	2
Gas contracts	Regulatory assets - current	22
	Regulatory assets - noncurrent	4
	Total	$	28

Louisville Gas And Electric Co [Member]

Derivative Instruments And Hedging Activities [Line Items]

Schedule of Derivative Instruments in Statement of Financial Position, Fair Value

The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments.

	March 31, 2025				December 31, 2024
	Assets		Liabilities		Assets		Liabilities
Current:
Price Risk Management Assets/Liabilities:
Interest rate swaps	$	—	$	1	$	—	$	—
Total current	—		1		—		—
Noncurrent:
Price Risk Management Assets/Liabilities:
Interest rate swaps	—		4		—		3
Total noncurrent	—		4		—		3
Total derivatives	$	—	$	5	$	—	$	3

Derivative Instruments, Gain (Loss)

The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets for the period ended March 31, 2025.

	Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months
Interest rate swaps	Interest expense	$	—
	Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months
Interest rate swaps	Regulatory assets - noncurrent	$	(1)

The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets for the period ended March 31, 2024. 

	Location of Gain (Loss) Recognized in
Derivative Instruments	Income on Derivatives	Three Months
Interest rate swaps	Interest expense	$	—
	Location of Gain (Loss) Recognized in
Derivative Instruments	Regulatory Assets	Three Months
Interest rate swaps	Regulatory assets - noncurrent	$	2

Derivative Positions Eligible for Offset with Related Cash Collateral

The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged.

	Assets								Liabilities
			Eligible for Offset								Eligible for Offset
	Gross		Derivative Instruments		Cash Collateral Received		Net		Gross		Derivative Instruments		Cash Collateral Pledged		Net
March 31, 2025
Derivatives
PPL	$	22	$	1	$	—	$	21	$	11	$	1	$	—	$	10
LG&E	—		—		—		—		5		—		—		5

	Assets								Liabilities
			Eligible for Offset								Eligible for Offset
	Gross		Derivative Instruments		Cash Collateral Received		Net		Gross		Derivative Instruments		Cash Collateral Pledged		Net
December 31, 2024
Derivatives
PPL	$	9	$	5	$	—	$	4	$	16	$	5	$	—	$	11
LG&E	—		—		—		—		3		—		—		3

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Asset Retirement Obligations (Tables)

3 Months Ended

Mar. 31, 2025

Asset Retirement Obligation [Line Items]

Asset Retirement Obligation Roll Forward

The changes in the carrying amounts of AROs were as follows.

	PPL		LG&E		KU
Balance at December 31, 2024	$	157	$	84	$	64
Accretion	2		1		1
Changes in estimated timing or cost	(1)		—		(1)
Obligations settled	(4)		(1)		(3)
Balance at March 31, 2025	$	154	$	84	$	61

Louisville Gas And Electric Co [Member]

Asset Retirement Obligation [Line Items]

Asset Retirement Obligation Roll Forward

The changes in the carrying amounts of AROs were as follows.

	PPL		LG&E		KU
Balance at December 31, 2024	$	157	$	84	$	64
Accretion	2		1		1
Changes in estimated timing or cost	(1)		—		(1)
Obligations settled	(4)		(1)		(3)
Balance at March 31, 2025	$	154	$	84	$	61

Kentucky Utilities Co [Member]

Asset Retirement Obligation [Line Items]

Asset Retirement Obligation Roll Forward

The changes in the carrying amounts of AROs were as follows.

	PPL		LG&E		KU
Balance at December 31, 2024	$	157	$	84	$	64
Accretion	2		1		1
Changes in estimated timing or cost	(1)		—		(1)
Obligations settled	(4)		(1)		(3)
Balance at March 31, 2025	$	154	$	84	$	61

XML

Accumulated Other Comprehensive Income (Loss) (Tables)

3 Months Ended

Mar. 31, 2025

Accumulated Other Comprehensive Income (Loss) [Line Items]

Schedule of Accumulated Other Comprehensive Income (Loss)

The after-tax changes in AOCI by component for the periods ended March 31 were as follows.

	Unrealized gains (losses)  on qualifying derivatives				Defined benefit plans
			Equity investees' AOCI		Prior service costs		Actuarial gain (loss)		Total
PPL
December 31, 2024	$	9	$	4	$	(3)	$	(194)	$	(184)
Reclassifications from AOCI	1		—		—		(1)		—
Net OCI during the period	1		—		—		(1)		—
March 31, 2025	$	10	$	4	$	(3)	$	(195)	$	(184)
December 31, 2023	$	6	$	3	$	(4)	$	(168)	$	(163)
Amounts arising during the period	—		1		—		—		1
Reclassifications from AOCI	1		—		—		—		1
Net OCI during the period	1		1		—		—		2
March 31, 2024	$	7	$	4	$	(4)	$	(168)	$	(161)

Reclassification out of Other Comprehensive Income (Loss)

The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the periods ended March 31.

	Three Months				Affected Line Item on the
Details about AOCI	2025		2024		Statements of Income
Qualifying derivatives
Interest rate swaps	$	(1)	$	(1)	Interest Expense
Total Pre-tax	(1)		(1)
Income Taxes	—		—
Total After-tax	(1)		(1)
Defined benefit plans
Net actuarial loss (a)	1		—
Total Pre-tax	1		—
Income Taxes	—		—
Total After-tax	1		—
Total reclassifications during the period	$	—	$	(1)

(a)    These AOCI components are included in the computation of net periodic defined benefit cost. See Note 9 for additional information.

XML

Summary of Significant Accounting Policies (Details) - USD ($) $ in Millions	Mar. 31, 2025	Dec. 31, 2024
Summary Of Significant Accounting Policies [Line Items]
Goodwill	$ 2,247	$ 2,247
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	312	306
Restricted Cash, Current	42	1
Cash, Cash Equivalents and Restricted Cash	354	307
PPL Electric Utilities Corp [Member]
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	27	24
Louisville Gas And Electric Co [Member]
Summary Of Significant Accounting Policies [Line Items]
Goodwill	389	389
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	10	8
Kentucky Utilities Co [Member]
Summary Of Significant Accounting Policies [Line Items]
Goodwill	607	607
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	$ 14	$ 13

XML

Segment and Related Information (Details) $ in Millions		3 Months Ended
		Mar. 31, 2025 USD ($) Integer		Mar. 31, 2024 USD ($)	Dec. 31, 2024 USD ($)
Income Statement Data [Abstract]
Revenues		$ 2,504		$ 2,304
Fuel		234		209
Energy purchases		559		520
Depreciation		322		316
Taxes, other than income		113		88
Other Income (Expense) - net		(28)		(22)
Interest Expense		190		179
Income Taxes		102		81
Net income (loss)		414		307
Balance Sheet Data [Abstract]
Total Assets		41,809			$ 41,069
Segment (Numeric) [Abstract]
Goodwill		$ 2,247			2,247
Number of Reportable Segments | Integer		3
Segment, Expenditure, Addition to Long-Lived Assets		$ 793		596
Amortization		20		24
Deferred income taxes and investment tax credits		38		72
Total Segments
Income Statement Data [Abstract]
Revenues		2,504		2,303
Fuel		234		209
Energy purchases		560		520
Utilities Operating Expense, Maintenance and Operations		562		539
Depreciation		320		316
Taxes, other than income		113		88
Other Income (Expense) - net		(26)		(19)
Interest Expense		143		146
Income Taxes		125		111
Net income (loss)		477		403
Segment (Numeric) [Abstract]
Segment, Expenditure, Addition to Long-Lived Assets		790		595
Amortization		16		20
Deferred income taxes and investment tax credits		21		54
Total Segments | Related Party
Segment (Numeric) [Abstract]
Interest Income from affiliate		(4)		(10)
Rhode Island Regulated
Income Statement Data [Abstract]
Revenues		626		549
Fuel		0		0
Energy purchases		235		229
Utilities Operating Expense, Maintenance and Operations		200		156
Depreciation		42		41
Taxes, other than income		47		27
Other Income (Expense) - net		(7)		(7)
Interest Expense		23		24
Income Taxes		18		15
Net income (loss)		70		64
Balance Sheet Data [Abstract]
Total Assets		7,194			7,055
Segment (Numeric) [Abstract]
Segment, Expenditure, Addition to Long-Lived Assets		172		125
Amortization		0		0
Deferred income taxes and investment tax credits		(7)		18
Rhode Island Regulated | Related Party
Segment (Numeric) [Abstract]
Interest Income from affiliate		(2)		0
Pennsylvania Regulated [Member]
Income Statement Data [Abstract]
Revenues		819		770
Fuel		0		0
Energy purchases		229		214
Utilities Operating Expense, Maintenance and Operations		162		181
Depreciation		102		99
Taxes, other than income		41		36
Other Income (Expense) - net		(11)		(9)
Interest Expense		60		62
Income Taxes		54		48
Net income (loss)		184		149
Balance Sheet Data [Abstract]
Total Assets		15,654			15,475
Segment (Numeric) [Abstract]
Segment, Expenditure, Addition to Long-Lived Assets		328		229
Amortization		11		12
Deferred income taxes and investment tax credits		20		32
Pennsylvania Regulated [Member] | Related Party
Segment (Numeric) [Abstract]
Interest Income from affiliate		(2)		(10)
Kentucky Regulated [Member]
Income Statement Data [Abstract]
Revenues		1,059		984
Fuel		234		209
Energy purchases		96		77
Utilities Operating Expense, Maintenance and Operations		200		202
Depreciation		176		176
Taxes, other than income		25		25
Other Income (Expense) - net		(8)		(3)
Interest Expense		60		60
Income Taxes		53		48
Net income (loss)		223		190
Balance Sheet Data [Abstract]
Total Assets		17,789			17,626
Segment (Numeric) [Abstract]
Segment, Expenditure, Addition to Long-Lived Assets		290		241
Amortization		5		8
Deferred income taxes and investment tax credits		8		4
Kentucky Regulated [Member] | Related Party
Segment (Numeric) [Abstract]
Interest Income from affiliate		0		0
Corporate and Other [Member]
Income Statement Data [Abstract]
Revenues		0		1
Income Taxes		(23)		(30)
Net income (loss)		(63)		(96)
Balance Sheet Data [Abstract]
Total Assets		1,172			913
Segment (Numeric) [Abstract]
Segment, Expenditure, Addition to Long-Lived Assets		3		1
Amortization		4		4
Deferred income taxes and investment tax credits		17		18
PPL Electric Utilities Corp [Member]
Income Statement Data [Abstract]
Revenues		819		770
Energy purchases		229		214
Depreciation		102		99
Taxes, other than income		41		36
Other Income (Expense) - net		(11)		(9)
Interest Expense		60		62
Income Taxes		54		48
Net income (loss)	[1]	184		149
Balance Sheet Data [Abstract]
Total Assets		$ 15,654			15,475
Segment (Numeric) [Abstract]
Number of Reportable Segments | Integer		1
Number of Operating Segments | Integer		2
Amortization		$ 11		12
Deferred income taxes and investment tax credits		20		32
PPL Electric Utilities Corp [Member] | Related Party
Segment (Numeric) [Abstract]
Interest Income from affiliate		(2)		(10)
Louisville Gas And Electric Co [Member]
Income Statement Data [Abstract]
Revenues		505		476
Fuel		82		86
Energy purchases		88		71
Depreciation		74		76
Taxes, other than income		13		13
Other Income (Expense) - net		(3)		(2)
Interest Expense		26		26
Income Taxes		26		24
Net income (loss)		105	[2]	93
Balance Sheet Data [Abstract]
Total Assets		8,081			7,992
Segment (Numeric) [Abstract]
Goodwill		$ 389			389
Number of Reportable Segments | Integer		1
Number of Operating Segments | Integer		1
Amortization		$ 4		3
Deferred income taxes and investment tax credits		1		2
Kentucky Utilities Co [Member]
Income Statement Data [Abstract]
Revenues		564		525
Fuel		152		123
Energy purchases		7		6
Depreciation		102		99
Taxes, other than income		12		12
Other Income (Expense) - net		(5)		(2)
Interest Expense		35		34
Income Taxes		31		27
Net income (loss)	[3]	125		108
Balance Sheet Data [Abstract]
Total Assets		10,161			10,073
Segment (Numeric) [Abstract]
Goodwill		$ 607			$ 607
Number of Reportable Segments | Integer		1
Number of Operating Segments | Integer		1
Amortization		$ 4		5
Deferred income taxes and investment tax credits		$ 3		$ (1)

[1] Net income equals comprehensive income.

[2] Net income equals comprehensive income.

[3] Net income equals comprehensive income.

XML

Revenue from Contracts with Customers (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2025	Mar. 31, 2024
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	$ 2,504	$ 2,304
Alternative Revenue Programs	50	7
Other Revenue	(9)	(8)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(2,545)	(2,303)
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	25	42
Energy purchases	559	520
Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(1,385)	(1,130)
Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(583)	(451)
Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(185)	(177)
Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(74)	(272)
Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(7)	(6)
Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(38)	(15)
Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(273)	(252)
Pennsylvania Regulated [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	819	770
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(812)	(762)
Contract with Customer, Asset and Liability [Abstract]
Energy purchases	229	214
Pennsylvania Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(457)	(426)
Pennsylvania Regulated [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(106)	(106)
Pennsylvania Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(13)	(12)
Pennsylvania Regulated [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(13)	(13)
Pennsylvania Regulated [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Pennsylvania Regulated [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Pennsylvania Regulated [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(223)	(205)
Kentucky Regulated [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	1,059	984
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(1,062)	(989)
Contract with Customer, Asset and Liability [Abstract]
Energy purchases	96	77
Kentucky Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(487)	(443)
Kentucky Regulated [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(280)	(267)
Kentucky Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(154)	(161)
Kentucky Regulated [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(96)	(97)
Kentucky Regulated [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(7)	(6)
Kentucky Regulated [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(38)	(15)
Kentucky Regulated [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Corporate and Other [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	0	1
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers		(1)
Corporate and Other [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers		0
Corporate and Other [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers		0
Corporate and Other [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers		0
Corporate and Other [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers		(1)
Corporate and Other [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers		0
Corporate and Other [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers		0
Corporate and Other [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers		0
Rhode Island Regulated
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	626	549
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(671)	(551)
Contract with Customer, Asset and Liability [Abstract]
Energy purchases	235	229
Rhode Island Regulated | Net metering
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers		32
Contract with Customer, Asset and Liability [Abstract]
Energy purchases	41
Rhode Island Regulated | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(441)	(261)
Rhode Island Regulated | Residential [Member] | Reclassification, Other
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(155)
Rhode Island Regulated | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(197)	(78)
Rhode Island Regulated | Commercial [Member] | Reclassification, Other
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(89)
Rhode Island Regulated | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(18)	(4)
Rhode Island Regulated | Industrial [Member] | Reclassification, Other
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(13)
Rhode Island Regulated | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	35	(161)
Rhode Island Regulated | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Rhode Island Regulated | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Rhode Island Regulated | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(50)	(47)
PPL Electric Utilities Corp [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	819	770
Alternative Revenue Programs	(2)	(3)
Other Revenue	(5)	(5)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(812)	(762)
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	7	28
Energy purchases	229	214
PPL Electric Utilities Corp [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(457)	(426)
PPL Electric Utilities Corp [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(106)	(106)
PPL Electric Utilities Corp [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(13)	(12)
PPL Electric Utilities Corp [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(13)	(13)
PPL Electric Utilities Corp [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
PPL Electric Utilities Corp [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
PPL Electric Utilities Corp [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(223)	(205)
Louisville Gas And Electric Co [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	505	476
Alternative Revenue Programs	2	2
Other Revenue	(1)	(1)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(506)	(477)
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	2	1
Energy purchases	88	71
Louisville Gas And Electric Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(239)	(218)
Louisville Gas And Electric Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(147)	(138)
Louisville Gas And Electric Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(46)	(47)
Louisville Gas And Electric Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(54)	(52)
Louisville Gas And Electric Co [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Louisville Gas And Electric Co [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(20)	(22)
Louisville Gas And Electric Co [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Kentucky Utilities Co [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	564	525
Alternative Revenue Programs	4	5
Other Revenue	(2)	(1)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(566)	(529)
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	1	1
Energy purchases	7	6
Kentucky Utilities Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(248)	(225)
Kentucky Utilities Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(133)	(129)
Kentucky Utilities Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(108)	(114)
Kentucky Utilities Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(42)	(46)
Kentucky Utilities Co [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(7)	(6)
Kentucky Utilities Co [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	(28)	(9)
Kentucky Utilities Co [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	$ 0	$ 0

XML

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	3 Months Ended
	Mar. 31, 2025	Mar. 31, 2024
Income (Numerator) [Abstract]
Net income (loss)	$ 414	$ 307
Less amounts allocated to participating securities	1	0
Net Income (Loss) Available to Common Stockholders, Basic	413	307
Net income (loss) available to PPL common shareowners - Diluted	$ 413	$ 307
Shares of Common Stock (Denominator) [Abstract]
Weighted-average shares - Basic EPS (in shares)	738,691	737,512
Add incremental non-participating securities: [Abstract]
Share-based payment awards (in shares)	2,709	1,308
Weighted-average shares - Diluted EPS (in shares)	741,400	738,820
Income (Loss) from Continuing Operations after income taxes, Diluted	$ 0.56	$ 0.42
Income (Loss) from Continuing Operations After Income Taxes, Basic	0.56	0.42
Basic EPS - Available to PPL common shareowners: [Abstract]
Net Income Available to PPL common shareowners (in dollars per share)	0.56	0.42
Diluted EPS - Available to PPL common shareowners: [Abstract]
Net Income Available to PPL common shareowners (in dollars per share)	$ 0.56	$ 0.42
Shares Issued (Numeric) [Abstract]
Common stock issued under DRIP (in shares)	200	0
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Forward Sale Agreements, Shares	2,033	0
Income from continuing operations after income taxes available to PPL common shareowners - Basic and Diluted	$ 414
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS	175	0

XML

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2025	Mar. 31, 2024
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	$ 108	$ 81
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	20	17
Depreciation and other items not normalized	(10)	(5)
Amortization of excess deferred income taxes	(15)	(13)
Other	(1)	1
Total increase (decrease)	(6)	0
Total income tax expense (benefit)	102	81
PPL Electric Utilities Corp [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	50	41
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	15	14
Depreciation and other items not normalized	(6)	(4)
Amortization of excess deferred income taxes	(3)	(2)
Other	(2)	(1)
Total increase (decrease)	4	7
Total income tax expense (benefit)	54	48
Louisville Gas And Electric Co [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	27	25
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	5	4
Amortization of excess deferred income taxes	(4)	(3)
Other	(2)	(2)
Total increase (decrease)	(1)	(1)
Total income tax expense (benefit)	26	24
Kentucky Utilities Co [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	33	28
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	6	5
Amortization of excess deferred income taxes	(5)	(5)
Other	(3)	(1)
Total increase (decrease)	(2)	(1)
Total income tax expense (benefit)	$ 31	$ 27

XML

Utility Rate Regulation - Regulatory Assets (Details) - USD ($) $ in Millions	Mar. 31, 2025	Dec. 31, 2024
Regulatory Assets [Line Items]
Current regulatory assets	$ 274	$ 320
Noncurrent regulatory assets	2,049	2,060
Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	29	30
Gas supply clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	23	3
Transmission Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	13	14
Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current regulatory assets	35	44
Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	962	967
Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	116	113
Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	20	20
Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	51	53
Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	165	173
Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	278	280
Storm Damage costs[Member]
Regulatory Assets [Line Items]
Current regulatory assets	46	68
Net metering
Regulatory Assets [Line Items]
Noncurrent regulatory assets	147	147
Rate adjustment mechanism
Regulatory Assets [Line Items]
Current regulatory assets	74	95
Renewable energy certificates
Regulatory Assets [Line Items]
Current regulatory assets	16	14
Distribution System Improvement Charge
Regulatory Assets [Line Items]
Current regulatory assets	9	8
Gas line tracker [Member]
Regulatory Assets [Line Items]
Current regulatory assets	5	4
Other
Regulatory Assets [Line Items]
Current regulatory assets	15	27
Noncurrent regulatory assets	47	46
Environmental cost recovery
Regulatory Assets [Line Items]
Noncurrent regulatory assets	96	96
Tax Cuts and Jobs Act (over/under)
Regulatory Assets [Line Items]
Current regulatory assets	28	21
Gas line Inspections
Regulatory Assets [Line Items]
Noncurrent regulatory assets	24	24
Advance metering Infrastructure
Regulatory Assets [Line Items]
Noncurrent regulatory assets	31	28
ISR deferral
Regulatory Assets [Line Items]
Current regulatory assets	10	22
Retired asset recovery
Regulatory Assets [Line Items]
Noncurrent regulatory assets	83	83
PPL Electric Utilities Corp [Member]
Regulatory Assets [Line Items]
Current regulatory assets	94	133
Noncurrent regulatory assets	685	673
PPL Electric Utilities Corp [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Gas supply clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Transmission Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	3	2
PPL Electric Utilities Corp [Member] | Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	27
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	472	473
PPL Electric Utilities Corp [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	41	22
PPL Electric Utilities Corp [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	3	3
PPL Electric Utilities Corp [Member] | Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	165	173
PPL Electric Utilities Corp [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Storm Damage costs[Member]
Regulatory Assets [Line Items]
Current regulatory assets	46	68
PPL Electric Utilities Corp [Member] | Net metering
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Rate adjustment mechanism
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Renewable energy certificates
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Distribution System Improvement Charge
Regulatory Assets [Line Items]
Current regulatory assets	9	8
PPL Electric Utilities Corp [Member] | Gas line tracker [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Other
Regulatory Assets [Line Items]
Current regulatory assets	8	7
Noncurrent regulatory assets	4	2
PPL Electric Utilities Corp [Member] | Environmental cost recovery
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Tax Cuts and Jobs Act (over/under)
Regulatory Assets [Line Items]
Current regulatory assets	28	21
PPL Electric Utilities Corp [Member] | Gas line Inspections
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Advance metering Infrastructure
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | ISR deferral
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Retired asset recovery
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Louisville Gas And Electric Co [Member]
Regulatory Assets [Line Items]
Current regulatory assets	31	8
Noncurrent regulatory assets	491	491
Louisville Gas And Electric Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	7	7
Louisville Gas And Electric Co [Member] | Gas supply clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	23	3
Louisville Gas And Electric Co [Member] | Transmission Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	223	226
Louisville Gas And Electric Co [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	22	20
Louisville Gas And Electric Co [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	9	9
Louisville Gas And Electric Co [Member] | Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	30	31
Louisville Gas And Electric Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	76	75
Louisville Gas And Electric Co [Member] | Storm Damage costs[Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Net metering
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Rate adjustment mechanism
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Renewable energy certificates
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Distribution System Improvement Charge
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Gas line tracker [Member]
Regulatory Assets [Line Items]
Current regulatory assets	5	4
Louisville Gas And Electric Co [Member] | Other
Regulatory Assets [Line Items]
Current regulatory assets	3	1
Noncurrent regulatory assets	4	4
Louisville Gas And Electric Co [Member] | Environmental cost recovery
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Tax Cuts and Jobs Act (over/under)
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Gas line Inspections
Regulatory Assets [Line Items]
Noncurrent regulatory assets	22	22
Louisville Gas And Electric Co [Member] | Advance metering Infrastructure
Regulatory Assets [Line Items]
Noncurrent regulatory assets	15	14
Louisville Gas And Electric Co [Member] | ISR deferral
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Retired asset recovery
Regulatory Assets [Line Items]
Noncurrent regulatory assets	83	83
Kentucky Utilities Co [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	1
Noncurrent regulatory assets	460	458
Kentucky Utilities Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	22	23
Kentucky Utilities Co [Member] | Gas supply clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Transmission Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	147	149
Kentucky Utilities Co [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	36	29
Kentucky Utilities Co [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	6	6
Kentucky Utilities Co [Member] | Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	21	22
Kentucky Utilities Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Kentucky Utilities Co [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	202	205
Kentucky Utilities Co [Member] | Storm Damage costs[Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Net metering
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Kentucky Utilities Co [Member] | Rate adjustment mechanism
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Renewable energy certificates
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Distribution System Improvement Charge
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Gas line tracker [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Other
Regulatory Assets [Line Items]
Current regulatory assets	0	1
Noncurrent regulatory assets	8	8
Kentucky Utilities Co [Member] | Environmental cost recovery
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Kentucky Utilities Co [Member] | Tax Cuts and Jobs Act (over/under)
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Gas line Inspections
Regulatory Assets [Line Items]
Noncurrent regulatory assets	2	2
Kentucky Utilities Co [Member] | Advance metering Infrastructure
Regulatory Assets [Line Items]
Noncurrent regulatory assets	16	14
Kentucky Utilities Co [Member] | ISR deferral
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Retired asset recovery
Regulatory Assets [Line Items]
Noncurrent regulatory assets	$ 0	$ 0

XML

Utility Rate Regulation - Regulatory Liabilities (Details) - USD ($)
$ in Millions

3 Months Ended

Mar. 31, 2025

Dec. 31, 2024

Regulatory Liabilities [Line Items]

Current regulatory liabilities

$ 274

$ 223

Noncurrent regulatory liabilities

$ 3,338

3,335

Utility Rate Regulation

6. Utility Rate Regulation

(All Registrants)

The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations.

	PPL				PPL Electric				LG&E				KU
	March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024
Current Regulatory Assets:
Rate adjustment mechanisms	$	74	$	95	$	—	$	—	$	—	$	—	$	—	$	—
Renewable energy certificates	16		14		—		—		—		—		—		—
Storm damage expense rider	46		68		46		68		—		—		—		—
Gas supply clause	23		3		—		—		23		3		—		—
Transmission service charge	35		44		—		27		—		—		—		—
Transmission formula rate	13		14		3		2		—		—		—		—
DSIC	9		8		9		8		—		—		—		—
TCJA customer refund and recovery	28		21		28		21		—		—		—		—
ISR deferral	10		22		—		—		—		—		—		—
Gas line tracker	5		4		—		—		5		4		—		—
Other	15		27		8		7		3		1		—		1
Total current regulatory assets	$	274	$	320	$	94	$	133	$	31	$	8	$	—	$	1

	PPL				PPL Electric				LG&E				KU
	March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024
Noncurrent Regulatory Assets:
Defined benefit plans	$	962	$	967	$	472	$	473	$	223	$	226	$	147	$	149
Plant outage costs	29		30		—		—		7		7		22		23
Net metering	147		147		—		—		—		—		—		—
Environmental cost recovery	96		96		—		—		—		—		—		—
Storm costs	116		113		41		22		22		20		36		29
Unamortized loss on debt	20		20		3		3		9		9		6		6
Terminated interest rate swaps	51		53		—		—		30		31		21		22
Accumulated cost of removal of utility plant	165		173		165		173		—		—		—		—
AROs	278		280		—		—		76		75		202		205
Retired asset recovery	83		83		—		—		83		83		—		—
Gas line inspections	24		24		—		—		22		22		2		2
Advanced metering infrastructure	31		28		—		—		15		14		16		14
Other	47		46		4		2		4		4		8		8
Total noncurrent regulatory assets	$	2,049	$	2,060	$	685	$	673	$	491	$	491	$	460	$	458

	PPL				PPL Electric				LG&E				KU
	March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024		March 31, 2025		December 31, 2024
Current Regulatory Liabilities:
Generation supply charge	$	45	$	52	$	45	$	52	$	—	$	—	$	—	$	—
Environmental cost recovery	9		12		—		—		4		6		5		6
Rate adjustment mechanisms	63		71		—		—		—		—		—		—
Energy efficiency	24		25		—		—		—		—		—		—
DSM	24		17		—		—		10		7		14		10
Revenue decoupling mechanism	40		10		—		—		—		—		—		—
Deferred revenue	25		—		—		—		—		—		—		—
Derivative instruments	15		—		—		—		—		—		—		—
Other	29		36		9		5		2		1		7		6
Total current regulatory liabilities	$	274	$	223	$	54	$	57	$	16	$	14	$	26	$	22
Noncurrent Regulatory Liabilities:
Accumulated cost of removal of utility plant	$	1,027	$	1,022	$	—	$	—	$	318	$	314	$	409	$	408
Net deferred taxes	1,875		1,899		729		739		434		439		491		498
Defined benefit plans	296		294		106		100		24		24		66		65
Terminated interest rate swaps	54		54		—		—		27		27		27		27
Energy efficiency	28		16		—		—		—		—		—		—
Other	58		50		—		—		11		11		14		11
Total noncurrent regulatory liabilities	$	3,338	$	3,335	$	835	$	839	$	814	$	815	$	1,007	$	1,009

Regulatory Matters

Rhode Island Activities (PPL)

FY 2026 Gas ISR Plan

On December 31, 2024, RIE filed its FY 2026 Gas ISR Plan with the RIPUC with a budget that included $187 million of capital investment spend and up to $15 million of additional contingency plan spend in connection with the PHMSA's potential

enactment of regulations during FY 2026 that, if enacted, would significantly alter RIE's leak detection and repair obligations under federal regulations. The Plan also included proposed spending on curb-to-curb paving of $22 million. On March 28, 2025, the RIPUC approved a FY 2026 Gas ISR Plan of $165 million of which $147 million is for capital investment spend and $18 million spend for paving costs as operations and maintenance (O&M), plus a potential additional $15 million is available if the above-mentioned regulations are implemented by the PHMSA. On March 31, 2025, the RIPUC approved RIE's compliance filing for rates effective April 1, 2025.

FY 2026 Electric ISR Plan

On December 23, 2024, RIE filed its FY 2026 Electric ISR Plan with the RIPUC with a budget that included $248 million of capital investment spend (including $88 million for Advanced Metering Functionality (AMF)), $14 million of vegetation operation and maintenance (O&M) spend and $1 million of Other O&M spend. On March 28, 2025, the RIPUC approved a FY 2026 Electric ISR Plan of $219 million for capital investment spend (including $88 million for AMF), $14 million for vegetation management O&M spend, and $1 million for Other O&M spend. On March 31, 2025, the RIPUC approved RIE's compliance filing for rates effective April 1, 2025.

Kentucky Activities

(PPL, LG&E and KU)

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 are intended to serve anticipated load growth, including from potential data center demand in LG&E's or KU’s service territory. The proposals do 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 are currently expected to be $3.7 billion over the 2025 to 2031 period. The application includes proposals:

•to build a 645 MW natural gas combined cycle (NGCC) generation unit at KU's E.W. Brown station,

•to build a 645 MW NGCC generation unit at LG&E's Mill Creek station,

•to build a four-hour 400 MW (1,600 MWh total) battery energy storage system (BESS) at LG&E's Cane Run station, and

•to build a selective catalytic reduction (SCR) environmental facility at KU’s Ghent station 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 NGCC unit is in addition to a new NGCC unit currently under construction at that location.

The filing also notes projected in service dates for the projects, including the E.W. Brown NGCC unit in 2030, the Mill Creek NGCC unit in 2031, the Cane Run BESS in 2028 and the Ghent SCR facility in 2028.

LG&E and KU anticipate a ruling from the KPSC during the fourth quarter of 2025. LG&E and KU cannot predict the outcome of the proceedings.

Kentucky January 2025 Storm

In January 2025, LG&E and KU experienced snow, ice, sleet and freezing rain in their service territories, resulting in substantial damage to certain of LG&E's and KU's assets. On January 31, 2025, LG&E and KU submitted a filing with the KPSC requesting regulatory asset treatment of the extraordinary operations and maintenance (O&M) expenses portion of the costs incurred related to the storm. On March 19, 2025, the KPSC issued an order authorizing LG&E and KU to establish, for accounting purposes only, regulatory assets based on the jurisdictional incremental costs of extraordinary O&M expense incurred by LG&E and KU as a result of the 2025 Winter Storm, with recovery amounts and amortization thereof to be determined in subsequent base rate proceedings. LG&E and KU cannot predict the outcome of this matter. As of March 31, 2025, LG&E and KU recorded regulatory assets related to the storm of $2 million and $7 million.

Mill Creek Unit 1 and Unit 2 Retired Asset Recovery (RAR) Application (PPL and LG&E)

In 2023, the KPSC issued an order approving, among other items, the requested retirement of Mill Creek Units 1 and 2.

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 rider. LG&E expects these costs to be approximately $125 million and proposed to begin application of the RAR rider with bills issued in May 2025. On February 24, 2025, the KPSC issued an order approving LG&E’s cost recovery for Mill Creek Unit 1 under the RAR rider.

Mill Creek Unit 2 is expected to be retired in 2027. LG&E anticipates the recovery of associated costs, including the remaining net book value, for Mill Creek Unit 2 through the RAR rider. The remaining net book value of Mill Creek Unit 2 was approximately $215 million at March 31, 2025 and LG&E is continuing to depreciate using the current approved rates through its retirement date in 2027. LG&E expects to reclassify the net book value remaining at retirement, which is expected to total approximately $161 million, to a regulatory asset to be amortized over a period of ten years in accordance with the RAR. There can be no assurance that these costs will be recovered in the amounts or at the time that LG&E expects.

Pennsylvania Activities (PPL and PPL Electric)

DSIC Petition

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%.

Federal Matters

FERC Transmission Rate Filing (PPL, LG&E and KU)

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. Oral argument before the D.C. Circuit Court of Appeals occurred on January 21, 2025. 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 base rates increases, provided, however, that increases associated with the FERC's May 18, 2023 order are expected to be subject to future rate proceedings.

Recovery of Transmission Costs (PPL)

Until December 2022, RIE's transmission facilities were operated in combination with the transmission facilities of National Grid USA's New England affiliates, Massachusetts Electric Company (MECO) and New England Power (NEP), as a single integrated system with NEP designated as the combined operator. As of January 1, 2023, RIE operates its own transmission facilities. NE-ISO allocates RIE's costs among transmission customers in New England, in accordance with the ISO Open Access Transmission Tariff (ISO-NE OATT). According to the FERC orders, RIE is compensated for its actual monthly transmission costs, with its authorized maximum return on equity (ROE) of 11.74% on its transmission assets.

The ROE for transmission rates under the ISO-NE OATT is the subject of four complaints that are pending before the FERC. On October 16, 2014, the FERC issued an order on the first complaint, Opinion No. 531-A, resetting the base ROE applicable to transmission assets under the ISO-NE OATT from 11.14% to 10.57% effective as of October 16, 2014 and establishing a maximum ROE of 11.74%. On April 14, 2017, this order was vacated and remanded by the D. C. Circuit Court of Appeals (Court of Appeals). After the remand, the FERC issued an order on October 16, 2018 applicable to all four pending cases where it proposed a new base ROE methodology that, with subsequent input and support from the New England Transmission Owners (NETO), yielded a base ROE of 10.41%. Subsequent to the FERC's October 2018 order in the New England Transmission Owners cases, the FERC further refined its ROE methodology in another proceeding and has applied that refined methodology to transmission owners’ ROEs in other jurisdictions, and the NETOs filed further information in the New England matters to distinguish their case. Those determinations in other jurisdictions have recently been vacated and remanded back to the FERC for further proceedings by the D.C. Circuit Court of Appeals. The proceeding and the final base rate ROE determination in the New England matters remain open, pending a final order from the FERC. PPL cannot predict the outcome of this matter, and an estimate of the impact cannot be determined.

Other

Purchase of Receivables Program

(PPL and PPL Electric)

In accordance with RIPUC-approved and PAPUC-approved purchase of accounts receivable programs, RIE and PPL Electric purchase certain accounts receivable from alternative electricity suppliers at a discount, which reflects a provision for uncollectible accounts. The alternative electricity suppliers have no continuing involvement or interest in the purchased accounts receivable. Accounts receivable that are acquired are initially recorded at fair value on the date of acquisition.

During the three months ended March 31, 2025 and 2024, RIE purchased $87 million and $51 million of accounts receivable from alternative suppliers.

During the three months ended March 31, 2025 and 2024, PPL Electric purchased $466 million and $419 million of accounts receivable from alternative suppliers.

Generation Supply Charge [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

$ 45

52

Environmental Cost Recovery [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

9

12

Accumulated Cost Of Removal Of Utility Plant [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

1,027

1,022

Net deferred taxes [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

1,875

1,899

Defined Benefit Plans [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

296

294

Terminated interest rate swaps [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

54

54

Energy efficiency charge

Regulatory Liabilities [Line Items]

Current regulatory liabilities

24

25

Noncurrent regulatory liabilities

28

16

Rate adjustment mechanism

Regulatory Liabilities [Line Items]

Current regulatory liabilities

63

71

Derivative Instruments [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

15

0

Demand Side Management [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

24

17

Other

Regulatory Liabilities [Line Items]

Current regulatory liabilities

29

36

Noncurrent regulatory liabilities

58

50

Deferred revenue

Regulatory Liabilities [Line Items]

Current regulatory liabilities

25

0

Revenue decoupling mechanism

Regulatory Liabilities [Line Items]

Current regulatory liabilities

40

10

PPL Electric Utilities Corp [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

54

57

Noncurrent regulatory liabilities

835

839

PPL Electric Utilities Corp [Member] | Generation Supply Charge [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

45

52

PPL Electric Utilities Corp [Member] | Environmental Cost Recovery [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

PPL Electric Utilities Corp [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

0

0

PPL Electric Utilities Corp [Member] | Net deferred taxes [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

729

739

PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

106

100

PPL Electric Utilities Corp [Member] | Terminated interest rate swaps [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

0

0

PPL Electric Utilities Corp [Member] | Energy efficiency charge

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Noncurrent regulatory liabilities

0

0

PPL Electric Utilities Corp [Member] | Rate adjustment mechanism

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

PPL Electric Utilities Corp [Member] | Derivative Instruments [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

PPL Electric Utilities Corp [Member] | Demand Side Management [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

PPL Electric Utilities Corp [Member] | Other

Regulatory Liabilities [Line Items]

Current regulatory liabilities

9

5

Noncurrent regulatory liabilities

0

0

PPL Electric Utilities Corp [Member] | Deferred revenue

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

PPL Electric Utilities Corp [Member] | Revenue decoupling mechanism

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Louisville Gas And Electric Co [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

16

14

Noncurrent regulatory liabilities

814

815

Louisville Gas And Electric Co [Member] | Generation Supply Charge [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Louisville Gas And Electric Co [Member] | Environmental Cost Recovery [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

4

6

Louisville Gas And Electric Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

318

314

Louisville Gas And Electric Co [Member] | Net deferred taxes [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

434

439

Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

24

24

Louisville Gas And Electric Co [Member] | Terminated interest rate swaps [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

27

27

Louisville Gas And Electric Co [Member] | Energy efficiency charge

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Noncurrent regulatory liabilities

0

0

Louisville Gas And Electric Co [Member] | Rate adjustment mechanism

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Louisville Gas And Electric Co [Member] | Derivative Instruments [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Louisville Gas And Electric Co [Member] | Demand Side Management [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

10

7

Louisville Gas And Electric Co [Member] | Other

Regulatory Liabilities [Line Items]

Current regulatory liabilities

2

1

Noncurrent regulatory liabilities

11

11

Louisville Gas And Electric Co [Member] | Deferred revenue

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Louisville Gas And Electric Co [Member] | Revenue decoupling mechanism

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Kentucky Utilities Co [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

26

22

Noncurrent regulatory liabilities

1,007

1,009

Kentucky Utilities Co [Member] | Generation Supply Charge [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Kentucky Utilities Co [Member] | Environmental Cost Recovery [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

5

6

Kentucky Utilities Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

409

408

Kentucky Utilities Co [Member] | Net deferred taxes [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

491

498

Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

66

65

Kentucky Utilities Co [Member] | Terminated interest rate swaps [Member]

Regulatory Liabilities [Line Items]

Noncurrent regulatory liabilities

27

27

Kentucky Utilities Co [Member] | Energy efficiency charge

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Noncurrent regulatory liabilities

0

0

Kentucky Utilities Co [Member] | Rate adjustment mechanism

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Kentucky Utilities Co [Member] | Derivative Instruments [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Kentucky Utilities Co [Member] | Demand Side Management [Member]

Regulatory Liabilities [Line Items]

Current regulatory liabilities

14

10

Kentucky Utilities Co [Member] | Other

Regulatory Liabilities [Line Items]

Current regulatory liabilities

7

6

Noncurrent regulatory liabilities

14

11

Kentucky Utilities Co [Member] | Deferred revenue

Regulatory Liabilities [Line Items]

Current regulatory liabilities

0

0

Kentucky Utilities Co [Member] | Revenue decoupling mechanism

Regulatory Liabilities [Line Items]

Current regulatory liabilities

$ 0

$ 0

XML

Utility Rate Regulation - Regulatory Matters (Details) $ in Millions				1 Months Ended		3 Months Ended
	Feb. 28, 2025 USD ($) MW	Oct. 16, 2018	Oct. 16, 2014	Mar. 31, 2025 USD ($)	Dec. 31, 2024 USD ($)	Mar. 31, 2025 USD ($)	Mar. 31, 2024 USD ($)	Mar. 13, 2025	Oct. 04, 2024 USD ($)	Apr. 26, 2024
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Regulatory assets				$ 2,049	$ 2,060	$ 2,049
aggregate projected capital expenditures	$ 3,700
Storm Costs [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Regulatory assets				116	113	116
PPL Electric [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Distribution System Improvement Charge Cap	5.00%							7.50%		5.00%
PPL Electric [Member] | Unaffiliated Third Party Entity [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Accounts Receivable, Purchase						466	$ 419
PPL Electric [Member] | Pennsylvania Public Utility Commission
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Requested Distribution System Improvement Charge Cap										9.00%
LGE [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
CPCN NGCC Generation Unit | MW	645
CPCN Battery Storage Facility | MW	1,600
LGE [Member] | Mill Creek Unit 2
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Property, Plant and Equipment, Generation or Processing				215		215
Public Utilities, Property, Plant and Equipment, Generation, Expected Remaining Book Value at Retirement				161		161
LGE [Member] | Kentucky Public Service Commission [Member] | Mill Creek Unit 1 retirement
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Amount of Regulatory Costs Not yet Approved									$ 125
LGE [Member] | Kentucky Public Service Commission [Member] | January 2025 KY Storm | Storm Costs [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Regulatory assets				2		2
KU [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
CPCN NGCC Generation Unit | MW	645
KU [Member] | Kentucky Public Service Commission [Member] | January 2025 KY Storm | Storm Costs [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Regulatory assets				7		7
Rhode Island Energy | Unaffiliated Third Party Entity [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Accounts Receivable, Purchase						$ 87	51
Rhode Island Energy | Federal Energy Regulatory Commsion [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
New ROE prosed by NETO and approved by FERC		10.41%
Initial minimum base ROE to be reset by the FERC			11.14%
Minimum base ROE reset by FERC			10.57%
Rhode Island Energy | Federal Energy Regulatory Commsion [Member] | Maximum ROE authorized
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Return on Equity, Percentage			11.74%			11.74%
Rhode Island Energy | Rhode Island Public Utility Commission
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Contingency Plan Spend on FY 2026 Gas ISR Plan					15
Capital Investment Spend on FY 2026 Gas ISR Plan					187
Capital Investment Spend on FY 2026 Electric ISR Plan					248
Total Approved Spend on FY 2026 Gas ISR Plan				165
Rhode Island Energy | Rhode Island Public Utility Commission | Other O&M
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Capital Investment Spend on FY 2026 Electric ISR Plan					1
Approved Capital Investment Spend on FY 2026 Electric ISR Plan				1
Rhode Island Energy | Rhode Island Public Utility Commission | Vegetation management
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Capital Investment Spend on FY 2026 Electric ISR Plan					14
Approved Capital Investment Spend on FY 2026 Electric ISR Plan				14
Rhode Island Energy | Rhode Island Public Utility Commission | AMF Capital Investment
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Approved Capital Investment Spend on FY 2025 Electric ISR Plan					88
Approved Capital Investment Spend on FY 2026 Electric ISR Plan				88
Rhode Island Energy | Rhode Island Public Utility Commission | Capital Investment
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Approved Capital Investment Spend on FY 2026 Electric ISR Plan				219
Rhode Island Energy | Rhode Island Public Utility Commission | Paving Costs
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Capital Investment Spend on FY 2026 Gas ISR Plan					22
Total Approved Spend on FY 2026 Gas ISR Plan				18
Rhode Island Energy | Rhode Island Public Utility Commission | Capital Investment
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Total Approved Spend on FY 2026 Gas ISR Plan				147
Approved Contingency Plan Spend on FY 2026 Gas ISR Plan				15
PPL Electric Utilities Corp [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Distribution System Improvement Charge Cap	5.00%							7.50%		5.00%
Regulatory assets				685	673	$ 685
PPL Electric Utilities Corp [Member] | Storm Costs [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Regulatory assets				41	22	41
PPL Electric Utilities Corp [Member] | Unaffiliated Third Party Entity [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Accounts Receivable, Purchase						466	$ 419
PPL Electric Utilities Corp [Member] | Pennsylvania Public Utility Commission
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Requested Distribution System Improvement Charge Cap										9.00%
Louisville Gas And Electric Co [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Regulatory assets				491	491	491
CPCN NGCC Generation Unit | MW	645
BESS LG&E Planned Ownership Percentage	0.32
CPCN Battery Storage Facility | MW	1,600
Louisville Gas And Electric Co [Member] | Mill Creek Unit 2
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Property, Plant and Equipment, Generation or Processing				215		215
Public Utilities, Property, Plant and Equipment, Generation, Expected Remaining Book Value at Retirement				161		161
Louisville Gas And Electric Co [Member] | Storm Costs [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Regulatory assets				22	20	22
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Mill Creek Unit 1 retirement
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Amount of Regulatory Costs Not yet Approved									$ 125
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | January 2025 KY Storm | Storm Costs [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Regulatory assets				2		2
Kentucky Utilities Co [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Regulatory assets				460	458	460
CPCN NGCC Generation Unit | MW	645
BESS KU Planned Ownership Percentage	0.68
Kentucky Utilities Co [Member] | Storm Costs [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Regulatory assets				36	$ 29	36
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | January 2025 KY Storm | Storm Costs [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Regulatory assets				$ 7		$ 7

XML

Utility Rate Regulation - Other (Details) - Unaffiliated Third Party Entity [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2025	Mar. 31, 2024
PPL Electric [Member]
Purchases Of Accounts Receivable [Line Items]
Accounts Receivable, Purchase	$ 466	$ 419
Rhode Island Energy
Purchases Of Accounts Receivable [Line Items]
Accounts Receivable, Purchase	87	51
PPL Electric Utilities Corp [Member]
Purchases Of Accounts Receivable [Line Items]
Accounts Receivable, Purchase	$ 466	$ 419

XML

Financing Activities - Credit Arrangements (Details) - USD ($) $ in Millions	Mar. 31, 2025	Jan. 01, 2025	Dec. 31, 2024
Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	$ 780		$ 303
PPL Capital Funding [Member]
Line of Credit Facility [Line Items]
Capacity	1,700
Borrowed	0		0
Letters of Credit and Commercial Paper Issued (c)	482		153
Unused Capacity	1,218
PPL Capital Funding [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	427		138
PPL Capital Funding [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	1,500	$ 1,500	1,250
Borrowed	0		0
Letters of Credit and Commercial Paper Issued (c)	427		138
Unused Capacity	1,073
Line of Credit Facility, Borrowing Capacity Sublimit	1,250		1,000
PPL Capital Funding [Member] | Syndicated Credit Facility [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	427		138
PPL Capital Funding [Member] | Bilateral Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	100
Borrowed	0		0
Letters of Credit and Commercial Paper Issued (c)	55		15
Unused Capacity	45
PPL Capital Funding [Member] | Bilateral Credit Facility #2
Line of Credit Facility [Line Items]
Capacity	100
Borrowed	0		0
Letters of Credit and Commercial Paper Issued (c)	0		0
Unused Capacity	100
PPL Electric [Member]
Line of Credit Facility [Line Items]
Capacity	750
Borrowed	0		0
Letters of Credit and Commercial Paper Issued (c)	56		1
Unused Capacity	694
PPL Electric [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	55		0
PPL Electric [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	750	750	650
Borrowed	0		0
Letters of Credit and Commercial Paper Issued (c)	56		1
Unused Capacity	694
LGE [Member]
Line of Credit Facility [Line Items]
Capacity	600
Borrowed	0		0
Letters of Credit and Commercial Paper Issued (c)	89		25
Unused Capacity	511
LGE [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	89		25
LGE [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	600	600	500
Borrowed	0		0
Letters of Credit and Commercial Paper Issued (c)	89		25
Unused Capacity	511
KU [Member]
Line of Credit Facility [Line Items]
Capacity	600
Borrowed	0		0
Letters of Credit and Commercial Paper Issued (c)	209		140
Unused Capacity	391
KU [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	209		140
KU [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	600	600	400
Borrowed	0		0
Letters of Credit and Commercial Paper Issued (c)	209		140
Unused Capacity	391
Rhode Island Energy | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0		0
Rhode Island Energy | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Borrowing Capacity Sublimit	250		250
Line of Credit Facility, Borrowing Capacity Sublimit, Maximum	600
Rhode Island Energy | Syndicated Credit Facility [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0		0
PPL Electric Utilities Corp [Member]
Line of Credit Facility [Line Items]
Capacity	750
Borrowed	0		0
Letters of Credit and Commercial Paper Issued (c)	56		1
Unused Capacity	694
PPL Electric Utilities Corp [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	55		0
PPL Electric Utilities Corp [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	750	750	650
Borrowed	0		0
Letters of Credit and Commercial Paper Issued (c)	56		1
Unused Capacity	694
Louisville Gas And Electric Co [Member]
Line of Credit Facility [Line Items]
Capacity	600
Borrowed	0		0
Letters of Credit and Commercial Paper Issued (c)	89		25
Unused Capacity	511
Louisville Gas And Electric Co [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	89		25
Louisville Gas And Electric Co [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	600	600	500
Borrowed	0		0
Letters of Credit and Commercial Paper Issued (c)	89		25
Unused Capacity	511
Kentucky Utilities Co [Member]
Line of Credit Facility [Line Items]
Capacity	600
Borrowed	0		0
Letters of Credit and Commercial Paper Issued (c)	209		140
Unused Capacity	391
Kentucky Utilities Co [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	209		140
Kentucky Utilities Co [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	600	$ 600	400
Borrowed	0		0
Letters of Credit and Commercial Paper Issued (c)	209		$ 140
Unused Capacity	$ 391

XML

Financing Activities - Short-term Debt (Details) - Commercial Paper [Member] - USD ($) $ in Millions	Mar. 31, 2025	Dec. 31, 2024
Short-term Debt [Line Items]
Capacity	$ 3,150
Commercial Paper Issuances (c)	780	$ 303
Unused Capacity	$ 2,370
PPL Capital Funding [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	4.71%	4.76%
Capacity	$ 1,350
Commercial Paper Issuances (c)	427	$ 138
Unused Capacity	$ 923
PPL Electric [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	4.68%
Capacity	$ 650
Commercial Paper Issuances (c)	55	$ 0
Unused Capacity	$ 595
LGE [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	4.67%	4.72%
Capacity	$ 500
Commercial Paper Issuances (c)	89	$ 25
Unused Capacity	$ 411
KU [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	4.71%	4.71%
Capacity	$ 400
Commercial Paper Issuances (c)	209	$ 140
Unused Capacity	191
Rhode Island Energy
Short-term Debt [Line Items]
Capacity	250
Commercial Paper Issuances (c)	0	0
Unused Capacity	$ 250
PPL Electric Utilities Corp [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	4.68%
Capacity	$ 650
Commercial Paper Issuances (c)	55	$ 0
Unused Capacity	$ 595
Louisville Gas And Electric Co [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	4.67%	4.72%
Capacity	$ 500
Commercial Paper Issuances (c)	89	$ 25
Unused Capacity	$ 411
Kentucky Utilities Co [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	4.71%	4.71%
Capacity	$ 400
Commercial Paper Issuances (c)	209	$ 140
Unused Capacity	$ 191

XML

Financing Activities - Long-term Debt (Details) - USD ($) $ in Millions	Mar. 31, 2025	Dec. 31, 2024
Long-term Debt (Numeric) [Abstract]
Long-term debt due within one year	$ 569	$ 551
Long-term Debt, Excluding Current Maturities	15,938	15,952
PPL Electric [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	750
Borrowed	0	0
PPL Capital Funding [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	1,700
Borrowed	0	0
LGE [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	600
Borrowed	0	0
KU [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	600
Borrowed	0	0
PPL Electric Utilities Corp [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	750
Borrowed	0	0
Long-term Debt, Excluding Current Maturities	5,214	5,214
Louisville Gas And Electric Co [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	600
Borrowed	0	0
Long-term debt due within one year	300	300
Long-term Debt, Excluding Current Maturities	2,171	2,171
Kentucky Utilities Co [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	600
Borrowed	0	0
Long-term debt due within one year	268	250
Long-term Debt, Excluding Current Maturities	$ 2,798	$ 2,816

XML

Financing Activities - Equity Securities (Details) $ / shares in Units, shares in Millions, $ in Millions	1 Months Ended	3 Months Ended
	Apr. 30, 2025 $ / shares shares	Mar. 31, 2025 USD ($) $ / shares shares	Mar. 31, 2024 $ / shares	Feb. 01, 2025 USD ($)
Securities Financing Transaction [Line Items]
Annualized current quarterly common stock dividend (in dollars per share)		$ 1.09
Dividends Declared Per Share of Common Stock (in dollars per share)		$ 0.2725	$ 0.2575
At-The-Market Program
Securities Financing Transaction [Line Items]
Common Stock Aggregate Sales Price | $				$ 2,000
Maximum Selling Agent Compensation, Equity Distribution				0.02
Common Stock Sales, Forward Contract, Shares | shares		2.0
Common Stock Sales, Forward Contract, Initial Forward Price		$ 34.49
Common Stock, Forward Contract, Physical Shares Scenario Settlement Shares | shares		2.0
Common Stock, Forward Contract, Physical Shares Scenario Settlement Proceeds | $		$ 70
Subsequent Event [Member] | At-The-Market Program
Securities Financing Transaction [Line Items]
Common Stock Sales, Forward Contract, Shares | shares	2.8
Common Stock Sales, Forward Contract, Initial Forward Price	$ 35.22

XML

Financing Activities - Distributions (Details) - $ / shares	3 Months Ended
	Mar. 31, 2025	Mar. 31, 2024
Distributions (Numeric) [Abstract]
Current quarterly common stock dividend (in dollars per share)	$ 0.2725	$ 0.2575
Annualized current quarterly common stock dividend (in dollars per share)	$ 1.09

XML

Acquisitions, Development and Divestitures - Development (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2025		Mar. 31, 2024	Dec. 31, 2024
Business Combination [Line Items]
Transition Service Agreement Cost		$ 48
Goodwill		2,247			$ 2,247
Revenues		2,504		$ 2,304
Net income (loss)		414		307
Indemnification for Safari sale/leaseback		25
Louisville Gas And Electric Co [Member]
Business Combination [Line Items]
Goodwill		389			389
Revenues		505		476
Net income (loss)		105	[1]	93
Kentucky Utilities Co [Member]
Business Combination [Line Items]
Goodwill		607			$ 607
Revenues		564		525
Net income (loss)	[2]	125		108
Rhode Island Regulated
Business Combination [Line Items]
Revenues		626		549
Net income (loss)		70		64
Corporate and Other [Member]
Business Combination [Line Items]
Revenues		0		1
Net income (loss)		(63)		(96)
Rhode Island Energy | Rhode Island Energy TSA
Business Combination [Line Items]
Other Nonrecurring (Income) Expense		$ 17		$ 81

[1] Net income equals comprehensive income.

[2] Net income equals comprehensive income.

XML

Defined Benefits (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2025	Mar. 31, 2024
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Defined benefit plans - funding	$ 5	$ 5
Pension Plan [Member] | U.S.
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	8	9
Interest cost	45	46
Expected return on plan assets	(72)	(75)
Amortization of: [Abstract]
Prior service cost	0	1
Actuarial loss	5	2
Net periodic defined benefit costs (credits)	(14)	(17)
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	2	1
Interest cost	7	7
Expected return on plan assets	(8)	(7)
Amortization of: [Abstract]
Actuarial loss	(1)	(1)
Net periodic defined benefit costs (credits)	$ 0	$ 0

XML

Commitments and Contingencies - Legal Matters and Regulatory Issues (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2025	Mar. 04, 2025	Feb. 21, 2025	Dec. 31, 2024
Claim By Former Affiliate [Abstract]
Period Over Which Distribution Adjustment Charge-related Costs Are amortized	10 years
Rhode Island Division Of Public Utilities And Carriers Amount To Be Refunded To The RIE Energy Efficiency Program		$ 10	$ 12
Rhode Island Division Of Public Utilities And Carriers Amount Already Credited To The RIE Energy Efficiency Program		2
Rhode Island Division Of Public Utilities And Carriers Amount To Be Recorded As A Reduction To The Storm Contingency Fund Balance		$ 8
Electric Rates
Claim By Former Affiliate [Abstract]
Environmental Costs Recognized, Recovery Credited to Expense	$ 3
Gas Rates
Claim By Former Affiliate [Abstract]
Environmental Costs Recognized, Recovery Credited to Expense	1
RIE Environmental Remediation
Claim By Former Affiliate [Abstract]
Accrual for Environmental Loss Contingencies, Gross	99			$ 98
PPL Electric [Member] | PPL Electric Additional Sites [Member]
Claim By Former Affiliate [Abstract]
Accrual for Environmental Loss Contingencies, Gross	8			8
PPL Electric Utilities Corp [Member] | PPL Electric Additional Sites [Member]
Claim By Former Affiliate [Abstract]
Accrual for Environmental Loss Contingencies, Gross	$ 8			$ 8

XML

Commitments and Contingencies - Environmental Matters and Other (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2025	Mar. 31, 2024	Dec. 31, 2024
Other - Labor Union Agreements (Numeric) [Abstract]
Amortization of excess deferred income taxes	$ (15)	$ (13)
Period RIE Environmental Remediation Costs To Be Incurred Over	30 years
RIE Environmental Remediation
Other - Labor Union Agreements (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies, Gross	$ 99		$ 98
PPL Electric [Member] | PPL Electric Additional Sites [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies, Gross	8		8
PPL Electric Utilities Corp [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Amortization of excess deferred income taxes	(3)	(2)
PPL Electric Utilities Corp [Member] | PPL Electric Additional Sites [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies, Gross	8		$ 8
Louisville Gas And Electric Co [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Amortization of excess deferred income taxes	(4)	(3)
Kentucky Utilities Co [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Amortization of excess deferred income taxes	$ (5)	$ (5)

XML

Commitments and Contingencies - Guarantees and Other Assurances (Details) - 3 months ended Mar. 31, 2025 £ in Millions, $ in Millions	USD ($)	GBP (£)	USD ($)
Other Guarantee (Numeric) [Abstract]
Maximum aggregate coverage bodily injury and property damage			$ 231
Indemnification Cap, Surrenders of Tax Losses | £		£ 50
Indemnification for Safari sale/leaseback	$ 25
Maximum Aggregate Coverage Bodily Injury And Property Damage, Wildfire			181
Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member] | LGE [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees			53
Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member] | KU [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees			24
PPL Guarantee [Member] | Indemnification Guarantee [Member] | Indemnifications related to certain tax liabilities related to the sale of the U.K. utility business [Domain]
Other Guarantee (Numeric) [Abstract]
Maximum exposure | £		£ 50
PPL Guarantee [Member] | Indemnification Guarantee [Member] | Guarantee of payment obligations under certain sale/leaseback financing transactions related to the sale of Safari Holdings
Other Guarantee (Numeric) [Abstract]
Maximum exposure			97
PPL Guarantee [Member] | Indemnification Guarantee [Member] | Indemnifications for losses suffered related to items not covered by Aspen Power's representation and warranty insurance associated with the sale of Safari Holdings
Other Guarantee (Numeric) [Abstract]
Maximum exposure			140
LKE Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees			77
Maximum exposure is not estimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable.
Louisville Gas And Electric Co [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees			53
Maximum exposure is not estimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable
Kentucky Utilities Co [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees			$ 24
Maximum exposure is not estimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable

XML

Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2025	Mar. 31, 2024	Dec. 31, 2024
PPL Electric Utilities Corp [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Receivable from affiliates			$ 222
Financing Receivable, after Allowance for Credit Loss, Related Party, Type [Extensible Enumeration]			CEP Reserves, Inc
PPL Electric Utilities Corp [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	$ 64	$ 56
Intercompany Borrowings (Numeric) [Abstract]
VEBA Funds Receivable	4		$ 7
PPL Electric Utilities Corp [Member] | CEP Reserves, Inc
Intercompany Borrowings (Numeric) [Abstract]
Intercompany note with affiliate maximum borrowing capacity	800
PPL Electric Utilities Corp [Member] | Accounts receivable from affiliates [Member] | PPL Services [Member]
Intercompany Borrowings (Numeric) [Abstract]
VEBA Funds Receivable			4
PPL Electric Utilities Corp [Member] | Other Noncurrent Assets [Member] | PPL Services [Member]
Intercompany Borrowings (Numeric) [Abstract]
VEBA Funds Receivable			3
Louisville Gas And Electric Co [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Payable to affiliates	$ 0		$ 43
Notes Payable, Related Party, Type [Extensible Enumeration]	Affiliated Entity [Member]		Related Party
Louisville Gas And Electric Co [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	$ 20	11
Louisville Gas And Electric Co [Member] | Parent And Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany Money Pool Agreement Unused Borrowing Capacity	661
Louisville Gas And Electric Co [Member] | LKS [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	30	29
Kentucky Utilities Co [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Payable to affiliates	$ 8		$ 73
Notes Payable, Related Party, Type [Extensible Enumeration]	Affiliated Entity [Member]		Related Party
Kentucky Utilities Co [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	$ 19	11
Kentucky Utilities Co [Member] | Parent And Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany Money Pool Agreement Unused Borrowing Capacity	433
Kentucky Utilities Co [Member] | LKS [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	$ 38	$ 38

XML

Other Income (Expense) - net (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2025	Mar. 31, 2024
Other Income
Defined benefit plans - non-service credits	$ 8	$ 8
AFUDC - equity component	16	9
Miscellaneous	1	(2)
Other Expense
Charitable Contributions	(2)	(2)
Other Income (Expense) - net	28	22
Interest Income (Expense), Nonoperating, Net	5	9
PPL Electric Utilities Corp [Member]
Other Income
Defined benefit plans - non-service credits	3	4
AFUDC - equity component	7	5
Other Expense
Charitable Contributions	(1)	(1)
Other Income (Expense) - net	11	9
Interest Income (Expense), Nonoperating, Net	2	1
Louisville Gas And Electric Co [Member]
Other Expense
Other Income (Expense) - net	3	2
Kentucky Utilities Co [Member]
Other Expense
Other Income (Expense) - net	$ 5	$ 2

XML

Fair Value Measurements - Assets and Liabilities Measured on Recurring Basis Table (Details) - Recurring Fair Value Measurements [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2025	Dec. 31, 2024
Assets
Cash and cash equivalents	$ 312	$ 306
Restricted cash and cash equivalents	28	33
Total Cash, Cash Equivalents and Restricted Cash	340	339
Special Use Funds [Abstract]
Money market fund	1	1
Commingled debt fund measured at NAV	8	10
Commingled equity fund measured at NAV	7	8
Total special use funds	16	19
Gas Contracts	22	9
Price risk management assets:
Total Assets	378	367
Price risk management liabilities:
Interest rate swaps	5	3
Gas Contracts	6	13
Total price risk management liabilities	11	16
Level 1 [Member]
Assets
Cash and cash equivalents	312	306
Restricted cash and cash equivalents	28	33
Total Cash, Cash Equivalents and Restricted Cash	340	339
Special Use Funds [Abstract]
Money market fund	1	1
Total special use funds	1	1
Gas Contracts	0	0
Price risk management assets:
Total Assets	341	340
Price risk management liabilities:
Interest rate swaps	0	0
Gas Contracts	0	0
Total price risk management liabilities	0	0
Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash	0	0
Special Use Funds [Abstract]
Money market fund	0	0
Total special use funds	0	0
Gas Contracts	22	4
Price risk management assets:
Total Assets	22	4
Price risk management liabilities:
Interest rate swaps	5	3
Gas Contracts	0	10
Total price risk management liabilities	5	13
Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash	0	0
Special Use Funds [Abstract]
Money market fund	0	0
Total special use funds	0	0
Gas Contracts	0	5
Price risk management assets:
Total Assets	0	5
Price risk management liabilities:
Interest rate swaps	0	0
Gas Contracts	6	3
Total price risk management liabilities	6	3
Level 3 [Member] | Gas Contracts
Price risk management liabilities:
Gas Contracts, Liability, Settlements	0
Gas Contracts, Asset (Liability), Balance	6	(2)
Total unrealized gains (losses) on Regulatory Asset/Regulatory Liability	8
PPL Electric Utilities Corp [Member]
Assets
Cash and cash equivalents	27	24
Price risk management assets:
Total Assets	27	24
PPL Electric Utilities Corp [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	27	24
Price risk management assets:
Total Assets	27	24
PPL Electric Utilities Corp [Member] | Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Price risk management assets:
Total Assets	0	0
PPL Electric Utilities Corp [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Price risk management assets:
Total Assets	0	0
Louisville Gas And Electric Co [Member]
Assets
Cash and cash equivalents	10	8
Restricted cash and cash equivalents	13	16
Total Cash, Cash Equivalents and Restricted Cash	23	24
Price risk management assets:
Total Assets	23	24
Price risk management liabilities:
Interest rate swaps	5	3
Total price risk management liabilities	5	3
Louisville Gas And Electric Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	10	8
Restricted cash and cash equivalents	13	16
Total Cash, Cash Equivalents and Restricted Cash	23	24
Price risk management assets:
Total Assets	23	24
Price risk management liabilities:
Interest rate swaps	0	0
Total price risk management liabilities	0	0
Louisville Gas And Electric Co [Member] | Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash	0	0
Price risk management assets:
Total Assets	0	0
Price risk management liabilities:
Interest rate swaps	5	3
Total price risk management liabilities	5	3
Louisville Gas And Electric Co [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash	0	0
Price risk management assets:
Total Assets	0	0
Price risk management liabilities:
Interest rate swaps	0	0
Total price risk management liabilities	0	0
Kentucky Utilities Co [Member]
Assets
Cash and cash equivalents	14	13
Restricted cash and cash equivalents	13	16
Total Cash, Cash Equivalents and Restricted Cash	27	29
Price risk management assets:
Total Assets	27	29
Kentucky Utilities Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	14	13
Restricted cash and cash equivalents	13	16
Total Cash, Cash Equivalents and Restricted Cash	27	29
Price risk management assets:
Total Assets	27	29
Kentucky Utilities Co [Member] | Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash	0	0
Price risk management assets:
Total Assets	0	0
Kentucky Utilities Co [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash	0	0
Price risk management assets:
Total Assets	$ 0	$ 0

XML

Fair Value Measurements - Financial Instruments Not Recorded at Fair Value (Details) - USD ($) $ in Millions	Mar. 31, 2025	Dec. 31, 2024
Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	$ 16,507	$ 16,503
Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	15,847	15,562
PPL Electric Utilities Corp [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	5,214	5,214
PPL Electric Utilities Corp [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	4,931	4,862
Louisville Gas And Electric Co [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	2,471	2,471
Louisville Gas And Electric Co [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	2,335	2,295
Kentucky Utilities Co [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	3,066	3,066
Kentucky Utilities Co [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	$ 2,804	$ 2,750

XML

Derivative Instruments and Hedging Activities - Intro (Details) - USD ($) $ in Millions	Mar. 31, 2025	Dec. 31, 2024
Master Netting Arrangements (Numeric) [Line Items]
Cash collateral obligation under master netting arrangements	$ 0	$ 0
Cash collateral posted under master netting arrangements	0	0
Louisville Gas And Electric Co [Member]
Master Netting Arrangements (Numeric) [Line Items]
Cash collateral obligation under master netting arrangements	0	0
Cash collateral posted under master netting arrangements	0	0
Kentucky Utilities Co [Member]
Master Netting Arrangements (Numeric) [Line Items]
Cash collateral obligation under master netting arrangements	0	0
Cash collateral posted under master netting arrangements	$ 0	$ 0

XML

Derivative Instruments and Hedging Activities - Risk Disclosures (Details) $ in Millions	3 Months Ended
	Mar. 31, 2025 USD ($) Bcf	Mar. 31, 2024 USD ($)	Dec. 31, 2024 USD ($)
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Cash collateral obligation under master netting arrangements	$ 0		$ 0
Cash collateral pledged - eligible for offset	0		0
Cash collateral pledged - eligible for offset	0		0
Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	22		9
Liability value	11		16
Other Current Assets | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	16		7
Other Noncurrent Assets [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	6		2
Other Current Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	2		10
Other Noncurrent Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	9		6
Interest Rate Swaps [Member] | Other Current Assets | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0
Interest Rate Swaps [Member] | Other Noncurrent Assets [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0
Interest Rate Swaps [Member] | Other Current Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	1		0
Interest Rate Swaps [Member] | Other Noncurrent Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value			3
Interest Rate Contract
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Gain (Loss) on Discontinuation of Cash Flow Hedge Due to Forecasted Transaction Probable of Not Occurring, Net	0	$ 0
Gas Contract | Other Current Assets | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	16		7
Gas Contract | Other Noncurrent Assets [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	6		2
Gas Contract | Other Current Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	1		10
Gas Contract | Other Noncurrent Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	5		3
LGE [Member] | Economic Hedges [Member] | Interest Rate Swaps [Member]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Derivative, Notional Amount	$ 64
Rhode Island Energy | Economic Hedges [Member] | Gas Contract
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Derivative, Nonmonetary Notional Amount, Volume | Bcf	40
Louisville Gas And Electric Co [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Cash collateral obligation under master netting arrangements	$ 0		0
Cash collateral pledged - eligible for offset	0		0
Cash collateral pledged - eligible for offset	0		0
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0
Liability value	5		3
Louisville Gas And Electric Co [Member] | Other Current Assets | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0
Louisville Gas And Electric Co [Member] | Other Noncurrent Assets [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0
Louisville Gas And Electric Co [Member] | Interest Rate Swaps [Member] | Other Current Assets | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0
Louisville Gas And Electric Co [Member] | Interest Rate Swaps [Member] | Other Noncurrent Assets [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0
Louisville Gas And Electric Co [Member] | Economic Hedges [Member] | Interest Rate Swaps [Member]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Derivative, Notional Amount	64
Kentucky Utilities Co [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Cash collateral obligation under master netting arrangements	0		0
Cash collateral pledged - eligible for offset	0		0
Cash collateral pledged - eligible for offset	$ 0		$ 0

XML

Derivative Instruments and Hedging Activities - Fair Values (Details) - Not Designated As Hedging Instruments [Member] - USD ($) $ in Millions	Mar. 31, 2025	Dec. 31, 2024
Fair Values by Balance Sheet Location [Abstract]
Asset value	$ 22	$ 9
Liability value	11	16
Louisville Gas And Electric Co [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Liability value	$ 5	$ 3

XML

Derivative Instruments and Hedging Activities - Gains and Losses (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2025	Mar. 31, 2024	Dec. 31, 2024
Derivative Instruments, Gain (Loss) [Line Items]
Interest Expense	$ 190	$ 179
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Other Income (Expense) - net	28	22
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Other Comprehensive Income (Loss) [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Derivative Gain (Loss) Recognized in OCI		0
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Interest Expense [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (Loss) Reclassified from AOCI into Income	(1)	(1)
Amount of gain (loss) reclassified from AOCI to income	(1)	(1)
Not Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	(5)	(16)
Gain (loss) recognized as regulatory liabilities/assets	18	28
Asset value	22		$ 9
Liability value	11		16
Not Designated As Hedging Instruments [Member] | Other Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	6		2
Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Other Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0		0
Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	(1)	2
Not Designated As Hedging Instruments [Member] | Gas Contracts
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	$ (5)	$ (16)
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Energy purchases	Energy purchases
Not Designated As Hedging Instruments [Member] | Gas Contracts | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	$ 1
Not Designated As Hedging Instruments [Member] | Gas Contracts | Regulatory Assets, current
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	18
Not Designated As Hedging Instruments [Member] | Gas Contract | Other Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	6		2
Not Designated As Hedging Instruments [Member] | Gas Contract | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets		$ 4
Not Designated As Hedging Instruments [Member] | Gas Contract | Regulatory Assets, current
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets		22
Louisville Gas And Electric Co [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Interest Expense	26	26
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Other Income (Expense) - net	3	2
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0		0
Liability value	5		3
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Other Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0		0
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Price risk management liabilities, current
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	1		0
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Price risk management, liabilities, noncurrent
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	4		3
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	$ 0	$ 0
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Interest Expense	Interest Expense
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Other Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	$ 0		0
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Price risk management liabilities, current
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	1		0
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Price risk management, liabilities, noncurrent
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value			$ 3
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	(1)	$ 2
Kentucky Utilities Co [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Interest Expense	35	34
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Other Income (Expense) - net	$ 5	$ 2

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Derivative Instruments and Hedging Activities - Offsetting Derivative Instruments and Credit Risk-Related Features (Details) - USD ($) $ in Millions	Mar. 31, 2025	Dec. 31, 2024
Assets [Abstract]
Cash collateral received - eligible for offset	$ 0	$ 0
Liabilities [Abstract]
Cash collateral pledged - eligible for offset	0	0
Credit Risk-Related Contingent Features [Abstract]
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	0
Treasury Derivatives [Member]
Assets [Abstract]
Gross	22	9
Derivative instruments - eligible for offset	1	5
Cash collateral received - eligible for offset	0	0
Net	21	4
Liabilities [Abstract]
Gross	11	16
Derivative instruments - eligible for offset	1	5
Cash collateral pledged - eligible for offset	0	0
Net	10	11
Louisville Gas And Electric Co [Member]
Assets [Abstract]
Cash collateral received - eligible for offset	0	0
Liabilities [Abstract]
Cash collateral pledged - eligible for offset	0	0
Louisville Gas And Electric Co [Member] | Treasury Derivatives [Member]
Assets [Abstract]
Gross	0	0
Derivative instruments - eligible for offset	0	0
Cash collateral received - eligible for offset	0	0
Net	0	0
Liabilities [Abstract]
Gross	5	3
Derivative instruments - eligible for offset	0	0
Cash collateral pledged - eligible for offset	0	0
Net	$ 5	$ 3

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Derivative Instruments and Hedging Activities - Commodity Purchases (Details) - USD ($) $ in Millions	Mar. 31, 2025	Dec. 31, 2024
Commodity Purchases [Line Items]
Derivative Net Liability Position Containing Credit Risk Related Contingency Feature	$ 0
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	0
Not Designated As Hedging Instruments [Member]
Commodity Purchases [Line Items]
Liability value	11	$ 16
Asset value	22	9
Other Current Assets | Not Designated As Hedging Instruments [Member]
Commodity Purchases [Line Items]
Asset value	16	7
Other Current Assets | Gas Contract | Not Designated As Hedging Instruments [Member]
Commodity Purchases [Line Items]
Asset value	16	7
Other Current Assets | Interest Rate Swaps [Member] | Not Designated As Hedging Instruments [Member]
Commodity Purchases [Line Items]
Asset value	0	0
Other Current Liabilities | Not Designated As Hedging Instruments [Member]
Commodity Purchases [Line Items]
Liability value	2	10
Other Current Liabilities | Gas Contract | Not Designated As Hedging Instruments [Member]
Commodity Purchases [Line Items]
Liability value	1	10
Other Current Liabilities | Interest Rate Swaps [Member] | Not Designated As Hedging Instruments [Member]
Commodity Purchases [Line Items]
Liability value	1	0
Other Noncurrent Assets [Member] | Not Designated As Hedging Instruments [Member]
Commodity Purchases [Line Items]
Asset value	6	2
Other Noncurrent Assets [Member] | Gas Contract | Not Designated As Hedging Instruments [Member]
Commodity Purchases [Line Items]
Asset value	6	2
Other Noncurrent Assets [Member] | Interest Rate Swaps [Member] | Not Designated As Hedging Instruments [Member]
Commodity Purchases [Line Items]
Asset value	0	0
Other Noncurrent Liabilities | Not Designated As Hedging Instruments [Member]
Commodity Purchases [Line Items]
Liability value	9	6
Other Noncurrent Liabilities | Gas Contract | Not Designated As Hedging Instruments [Member]
Commodity Purchases [Line Items]
Liability value	$ 5	3
Other Noncurrent Liabilities | Interest Rate Swaps [Member] | Not Designated As Hedging Instruments [Member]
Commodity Purchases [Line Items]
Liability value		$ 3

XML

Asset Retirement Obligations (Details) $ in Millions	3 Months Ended
	Mar. 31, 2025 USD ($)
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	$ 157
Accretion	2
Changes in estimated timing or cost	(1)
Obligations settled	(4)
Balance at End of Period	154
Louisville Gas And Electric Co [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	84
Accretion	1
Changes in estimated timing or cost	0
Obligations settled	(1)
Balance at End of Period	84
Kentucky Utilities Co [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	64
Accretion	1
Changes in estimated timing or cost	(1)
Obligations settled	(3)
Balance at End of Period	$ 61

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Accumulated Other Comprehensive Income (Loss) - After-tax Changes by Component (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2025	Mar. 31, 2024
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	$ (184)	$ (163)
Amounts arising during the period		1
Reclassifications from AOCI	0	1
Net OCI during the period	0	2
Balance at end of period	(184)	(161)
Accumulated Defined Benefit Plans Adjustment, Net Prior Service Attributable to Parent
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(3)	(4)
Amounts arising during the period		0
Reclassifications from AOCI	0	0
Net OCI during the period	0	0
Balance at end of period	(3)	(4)
Accumulated Defined Benefit Plans Adjustment, Net Gain (Loss) Attributable to Parent
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(194)	(168)
Amounts arising during the period		0
Reclassifications from AOCI	(1)	0
Net OCI during the period	(1)	0
Balance at end of period	(195)	(168)
Equity Investees' OCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	4	3
Amounts arising during the period		1
Reclassifications from AOCI	0	0
Net OCI during the period	0	1
Balance at end of period	4	4
Unrealized gains (losses) on qualifying derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	9	6
Amounts arising during the period		0
Reclassifications from AOCI	1	1
Net OCI during the period	1	1
Balance at end of period	$ 10	$ 7

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Accumulated Other Comprehensive Income (Loss) - Income (Expense) Effect of Reclassifications (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2025	Mar. 31, 2024
Affected Line Item on the Statements of Income [Line Items]
Interest Expense	$ (190)	$ (179)
Other Income (Expense) - net	28	22
Income Tax Expense (Benefit)	(102)	(81)
Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Total After-tax	0	(1)
Defined Benefit Plans [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Income (Loss) from Continuing Operations before Income Taxes	1	0
Income Tax Expense (Benefit)	0	0
Total After-tax	1	0
Defined Benefit Plans [Member] | Accumulated Defined Benefit Plans Adjustment, Net Gain (Loss) Attributable to Parent | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Income (Loss) from Continuing Operations before Income Taxes	1	0
Unrealized gains (losses) on qualifying derivatives [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Income (Loss) from Continuing Operations before Income Taxes	(1)	(1)
Income Tax Expense (Benefit)	0	0
Total After-tax	(1)	(1)
Unrealized gains (losses) on qualifying derivatives [Member] | Interest Rate Swaps [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Interest Expense	$ (1)	$ (1)